Publications

authors: Nienke Dhondt, Lieven Vandevelde, Greet Van Eetvelde

Journal: Energy reports

link: http://doi.org/10.1016/j.egyr.2025.10.019

abstract: 

Concerns about the competitiveness of European industry led to the publication of the Draghi report. One of his recommendations is to install regional green industrial clusters around energy-intensive companies. The report identifies three benefit categories, each corresponding to typical industrial symbiosis cases: improved investment cases by shared local low-carbon energy generation, improved investment cases by shared infrastructure, and improved energy flows for increased resource efficiency. Industrial clusters hold untapped potential to advance the energy transition and climate neutrality. However, it is still unknown how and if this potential will ever be reached, nor how scalable and replicable the benefits will be. This review paper aims to take a first step in exploring the potential role of industrial clusters in the energy system by exposing the research state of the art in academic literature. A literature review is performed in line with the three benefit categories according to Draghi to understand the enablers and barriers of potential synergies and their impact on the energy system. Afterwards, the scalability is assessed by positioning the European industrial clusters in the larger renewable energy landscape. To illustrate the global interest, a brief reflection is made on references to industrial clusters in the policy of non-European regions. The work concludes with interesting leads for future research to further advance knowledge on the importance of industrial clusters in the energy system, and to stimulate the implementation of energy synergies.

Authors:  Juan Camilo Castaño ;Hakan Ergun; Dirk Van Hertem

Conference: 2024 IEEE PES Innovative Smart Grid Technologies Europe (ISGT EUROPE)

Link: https://ieeexplore.ieee.org/document/10863325

Abstract: The loss of large power infeeds can lead to significant frequency variations in the power grid, posing a blackout risk and compromising power system resilience. Traditionally, frequency reserve services were provided by generation units. However, the integration of new elements such as battery energy storage systems (BESS) and electrolysers prompts an exploration of their potential benefits in mitigating power imbalances. In this study, a Mixed Integer Second Order Cone economic dispatch model is employed to identify the optimal procurement of frequency reserve from generators, BESS, and electrolysers. A sensitivity analysis of the cost of the procured reserved and deployment time of electrolysers was also carried out. Results indicate that these parameters significantly influence the operational set points, modifying the dimensioning event and the optimal procurement of frequency reserve when it comes to ensuring operational resilience in terms of maximum frequency deviation.

Authors: Negar Namazifard; Pieter Vingerhoets; Erik Delarue

Links: https://www.researchgate.net/publication/369659073_INVESTMENT_AND_OPERATIONAL_OPTIMIZATION_FOR_FUTURE_HYDROGEN_INFRASTRUCTURE_A_BELGIAN_CASE_STUDY

https://lirias.kuleuven.be/retrieve/719471 

Abstract: 

The European Union’s green deal and European Climate law have set a target for the EU to become climate neutral by 2050. The transition to climate neutrality must be balanced with other priorities such as energy security to strengthen the EU’s industry and energy system to create a level playing field in comparison with other countries outside the EU. Following the recent REpowerEU plan, hydrogen is a crucial candidate to reduce the emissions of the so-called hard-to-abate sectors that cannot be easily electrified. In particular, one can think of the industries where hydrogen can be used both as fuel and feedstock such as steel making, green fertilizer production, methanol synthesis and refineries. Belgium, the Netherlands, and North Rhine Westphalen (Germany) are currently the regions with the most concentrated hydrogen demand in Europe. However, the supply of cheap and green electricity for commercially viable production of green hydrogen is scarce in these countries. Therefore, options for large-scale hydrogen import from regions with higher renewable potential or low carbon “blue” hydrogen production are currently being considered. To obtain crucial insights on the required capacities and investments for potential deployment of the hydrogen-related technologies and pipeline networks, one should technically and economically investigate the different processes for renewable hydrogen production, and develop various roadmaps to deliver these renewable molecules to the demand clusters. In this study, an energy system investment and operational optimization model has been developed with high spatial resolution in the industrial clusters to analyze the Fluxys 2030 roadmap in Belgium for connecting the potential hydrogen production and import hubs to the demand nodes. Hypatia as an energy system modelling framework has been used following a linear programming technique with the objective function of minimizing the total discounted system cost to obtain the optimize future capacity of hydrogen network and hydrogen production technologies. In the first case study, the future non-energy hydrogen demand of industries located in the areas of Antwerp, Ghent and Mons has been considered based on the data taken from a project funded by European Commission called AidRES where the demand for hydrogen as potential future feedstock has been calculated in the steel, ammonia, methanol and refinery industries towards 2050. The case study starts from a greenfield in Belgium, i.e., without accounting for existing capacities and it is constrained by the network typology given by Fluxys. The green hydrogen production routes from renewables connected to PEM electrolyzers have been included in all the regions modelled in this case study, considering their resource availability and renewable technology’s (such as PV, onshore and offshore wind turbines) maximum technical potential. On the other hand, blue hydrogen production has only been included in the Antwerp area, where there have been already some steam-methane reforming (SMR) capacities for grey hydrogen production.

Journal: International Journal of Hydrogen Energy, 2024

Authors: Negar Namazifard, Pieter Vingerhoets, Erik Delarue

Link: https://www.sciencedirect.com/science/article/abs/pii/S0360319924007675

Abstract: 

The REpowerEU plan prioritizes combining electrification with low-carbon hydrogen for a green energy shift. However, uncertainties surrounding the future hydrogen market and its supply costs impede the establishment of its value chain. Without definite plans for hydrogen production and infrastructure, investing in low-carbon hydrogen industrial processes is risky. Simultaneously, the absence of solid market interest poses challenges in deploying a hydrogen backbone. In recent years, European gas Transmission System Operators (TSOs) in Belgium, Netherlands, and Germany, have introduced various roadmaps for their prospective national hydrogen network. Despite the infrastructure proposals, detailed quantitative scenario analysis for the future hydrogen supply chain is still missing. This paper presents a hydrogen infrastructure model that employs Mixed Integer Linear Programming (MILP) for investment and operational cost optimization at detailed spatiotemporal resolution. A regionalization method is proposed to allocate the potential hydrogen consumption in different industrial sectors across various clusters within a country, represented as the prospective hydrogen demand nodes. The model assesses extreme supply scenarios to examine the robustness of the resulting network infrastructure and compare the system-levelized cost of hydrogen. A real-life case study focusing on the potential Belgian hydrogen supply chain showcases the model's capabilities and outputs.

Authors: Muhammad Salman ^a, Daniel Flórez-Orrego ^b, Juan Correa-Laguna ^c, François Maréchal ^b,Grégoire Léonard ^a

a - ULiege, b- EPFL, c-VITO

Journal: Computer Aided Chemical Engineering, 2024

Link: https://www.sciencedirect.com/science/article/abs/pii/B9780443288241503641

Abstract:

A systemic methodology was developed, employing key performance indicators (KPIs): specific total annual cost (TAC) (€/t_glass), specific emissions (tCO2/t_glass) and specific energy consumption (MWh/t_glass) to analyse various energy transition routes for flat glass production, such as NG oxy-combustion, H₂ and hybrid furnaces, and full electrification, along with glass recycle and carbon capture (CC). A Blueprint (BP) model, including steady-state values for mass and energy balance, as well as investment and operating costs, is developed. To determine the optimal route, the OSMOSE Lua optimization framework was employed, which solves the mixed integer linear programming (MILP) problem using the TAC as the objective function. Additionally, three scenarios, namely Central, Electrification and Clean Molecules were implemented, influencing costs of natural gas (NG), H₂, electricity, and CO₂ emission, for years 2030, 2040 and 2050. For 2030, the hybrid furnace becomes the most cost-effective route across all scenarios. However, considering a balance between emissions and cost, pathways such as the H₂ furnace, all-electric furnace, or NG furnace with CC suit moderate emissions target. For higher targets, hybrid with CC is the optimal choice, effectively combining cost efficiency with significant emissions reduction. In 2040, electrification with CC dominates in electrification scenario, achieving significant emissions and TAC reductions, while the hybrid with CC prevails in other scenarios, with 93% emission and 15-16% TAC reductions. By 2050, lower commodity costs and higher CO₂ favour CC-equipped routes of all-electric, H₂, and hybrid, reducing TAC by 34-39% and emissions by 93-95%. In conclusion, for the energy transition in glass sector, an excellent trade-off between all KPIs is required, based on future energy perspectives, to make the right investment decisions.

Authors: Muhammad Salman, Daniel Flórez-Orrego, Francois Marechal, Grégoire Léonard

Journal: Journal of Energy Resources Technology

Links: https://www.researchgate.net/publication/382275661_Superstructure-based_Approach_to_Assess_the_Heat_Pumping_and_Renewable_Energy_Integration_Potential_in_the_Sugar_Industry

Abstract: 

The study examines the feasibility of integrating heat pumps (HPs) and renewable energy in the sugar industry to advance decarbonization. It explores different routes for energy supply, contrasting them with a natural gas (NG)-fired base-case route. The alternatives include bio-digestion of beet and pulp waste to produce biomethane (bio-CH4) used in the process, hydrogen boiler, and electric boiler (full electrification using renewable electricity). Each route also incorporates HPs, utilizing waste heat primarily from evaporation and drying processes. Additionally, CO2 capture (CC) units can be optionally installed. Evaluation of the superstructure employs a systemic methodology with total specific cost (€/t sugar) and total specific emissions (tCO2/t sugar) as objective functions for each route. Detailed blueprint (BP) models of sugar production for each route cover mass and energy balances, CAPEX and OPEX, and material and energy resource costs. Optimization is conducted using the OSMOSE Lua framework with a mixed integer linear programming (MILP) approach. Three energy scenarios (2023, 2030, and 2050) are established, influencing prices of NG, hydrogen, electricity, and CO2 emissions. In the 2023 scenario, integrating bio-CH4 with HP emerges as the most cost-effective option, reducing costs by 15% compared to the base-case. However, the optimal solution adds CC and HP to the bio-CH4 route, reducing costs by 9% while achieving a 133% emissions reduction, resulting in net negative emissions. By 2030, routes with HP become more favorable with slightly lower electricity and hydrogen prices. bio-CH4 with HP and CC remains the best choice, cutting costs by 60% and maintaining 133% emissions reduction. In the 2050 scenario, decreased electricity and hydrogen prices, coupled with a higher CO2 emission price, make the base-case the most expensive. Nonetheless, bio-CH4 routes remain viable, with hydrogen and electric boiler-based routes also feasible due to cheaper energy prices.

Authors: Nienke Dhondt, Francisco Mendez Alva, Greet van Eetvelde, UGent

Journal: Sustainability mdpi

Links: https://www.researchgate.net/publication/379167180_Introducing_Industrial_Clusters_in_Multi-Node_Energy_System_Modelling_by_the_Application_of_the_Industry-Infrastructure_Quadrant

https://biblio.ugent.be/publication/01HSV1C57SZC4KWERV7DA3Z24H 

Abstract: 

To reach climate neutrality and circularity targets, industry requires infrastructure guaranteeing available, accessible, affordable, and sustainable supply of renewable energy and resources. The layout and operation of the required grids are a key topic in energy system modelling, a research field under constant development to tackle energy transition challenges. Although industry is a core player, its transformation and related policy initiatives are not yet fully reflected, resulting in a research gap. The industrial cluster concept, stimulating local cross-sectoral co-operation, circularity, and optimisation, offers untapped potential to improve the spatial representation of industry in energy system models and paves the way for cluster transition research. This paper introduces the Industry–Infrastructure Quadrant to visualise the relationship between industry and infrastructure presence by means of five distinct area categories. A complementary methodology integrates industrial clusters for multi-node selection in energy system models, solely relying on open-source data and cluster algorithms (DBSCAN). A case study applied to Belgium results in ten nodes to represent the territory, accurately reflecting crucial infrastructure elements and future needs whilst improving industry representation in terms of space and composition. The work serves as a first step towards a deeper understanding of the prominence of industrial clusters in sustainable energy systems.

Authors: Enya Lenaerts, Negar Namazifard, Nienke Dhondt, Pieter Valkering, Juan Correa Laguna

Journal: IEEE 20th International Conference on the European Energy Market (EEM), 2024

Link: https://ieeexplore.ieee.org/document/10608951

Abstract:

We discuss the development and functionalities of the Regionalization Tool (RT) which presents a user-friendly post-processing procedure of scenario results, provided by a long-term energy system investment planning model, as well as a national industrial database. The tool generates geographically explicit clusters of production or consumption volumes for different commodities, according to a selected pathway towards 2050. Doing so, the tool introduces a spatial component to the otherwise aggregated modeling results, thereby balancing the computational cost of the energy system model with increased geographical detail to be used as input for energy infrastructure investment decision models. We demonstrate this added value of the tool through a case study for a decarbonization scenario towards 2050 for Belgium, selected from the PATHS2050 study. The case study highlights the spatial component to the electrification trend that emerges in the scenario results, as well as a geographically varying volumes of hydrogen consumption and captured CO 2 , thereby providing input to infrastructure investment decision models.

Authors: Nienke Dhondt, Greet Van Eetvelde   

38th INTERNATIONAL CONFERENCE ON EFFICIENCY, COST, OPTIMIZATION, SIMULATION AND ENVIRONMENTAL IMPACT OF ENERGY SYSTEMS, 29 JUNE - 4 JULY 2025, PARIS, FRANCE

Abstract:

The challenges industry faces while transitioning towards climate neutrality are a driving force for researchers to help find suitable pathways and viable technology solutions. Whereas past research used to study industrial sectors separately, the current trend is to leverage the geospatial proximity of companies and optimise the transition on a cluster-level in symbiosis. Policy makers also recognise this trend and started integrating the cluster concept in new regulations and strategies, at national as well as European level. A recent example is the Draghi report, which recommends to establish green regional clusters around European energy-intensive industries. This study explores cluster-level transition pathways, either top-down by disaggregating system models or bottom-up by aggregating individual sector models. The introduction of clean processes and alternatives for fuel and feedstock in a cluster are known to alter supply and demand volumes. When cluster companies collaborate in symbiosis, both the supply and demand side can be mutualised, and together with shared infrastructure, also optimised. This paper presents an overview of electrical power-related symbiosis cases, both existing or projected, and models main trends in cluster transition linked to this case base while identifying high-potential routes. The work continues from the European AIDRES project, which qualitatively assessed the synergy potential in five EU clusters, and adds an additional step by applying game theory to analyse the strategies of individual firms when presented an opportunity to collaborate. Still, implementing industrial symbiosis has many barriers and pitfalls, and through game theory, conflicts of interest like profit and cost distribution, risk spreading, legal constraints, trust, and so on, can be taken into account. To demonstrate the model, the methodology is applied to North Sea Port (NSP). This cross-border industrial cluster has companies in Belgium and the Netherlands and covers a wide scope of sectors, such as steel, refineries, chemicals, paper etc. Currently, the NSP electrification plans undergo a matchmaking procedure to identify industrial symbiosis opportunities, to which game theory is applied. Results from this case study confirm NSP’s needs for additional infrastructure in order to facilitate the implementation of these synergies.

Authors: Nienke Dhondt, Thijs Duvillard, Greet Van Eetvelde

IET POWERING NET ZERO – ENERGY SECURITY FOR THE FUTURE, Glasgow, 25-26 November 2025

Link poster: http://hdl.handle.net/1854/LU-01KBJ2VY81JS54R307ADY907B7

Abstract:

The transition of energy-intensive industries towards climate neutrality requires substantial effort, not only at site level but also for the energy system that needs to adjust in time to conserve adequacy. To maximise system value, investments at both levels should be jointly optimised. Nowadays, EU industry struggles with an unfavourable investment climate due to high energy prices, an unlevel playing field and complex regulatory framework. Despite the uncertain outlook for industry, energy system planning should continue for any required infrastructure adaptations to be ready in time. Here, industrial clustering can be a way forward. Not only does it enhance competitiveness, but it also improves industry representation in energy system models, both in terms of spatial and technology detail. This work introduces industrial clusters in the open-source PyPSA-Eur framework and describes an extension that updates default assumptions on industrial energy demand with detailed, sector-specific transition pathways. To validate the effectiveness of the extension, the updated model is applied to a subset of EU industry-dense countries: Belgium, the Netherlands and Germany. By comparing results the impact of a cluster’s energy transition on the local energy system is illustrated. The extension is useful for strategic energy planning in and across industrial clusters.

Authors: Muhammad Salman ^a, Daniel Flórez-Orrego ^b d, Diederik Coppitters ^c, Rafailia Mitraki ^a, François Maréchal ^b, Grégoire Léonard ^a

a – Chemical Engineering, University of Liège, Liège, Belgium

b – IPESE Group, School of Engineering, Federal Polytechnic School of Lausanne, Sion, Switzerland

c – Institute of Mechanics, Materials and Civil Engineering, Université Catholique de Louvain, Louvain-la-Neuve, Belgium

d – Faculty of Minas, National University of Colombia, Av. 80 #65 - 223 Medellín, Colombia

Abstract:

The glass industry faces critical decarbonisation challenges due to high energy demand and reliance on fossil fuels. This study presents a comprehensive techno-economic analysis of diverse decarbonisation pathways for flat glass production, including electrification, energy efficiency, fuel switching and carbon capture and storage (CCS). A multi-scenario mapping explores sensitivity to future energy and carbon prices, while uncertainty quantification (UQ) assesses economic resilience under market volatility. From the results, a hybrid furnace (Hybfur), combining oxy-combustion and partial electrification, reduces emissions by 33 % compared to conventional gas-fired furnaces (NGfur). All-electric (ELfur) and hydrogen-fired (H2fur) furnaces reduce emissions by 41 % and 50 %, respectively, eliminating combustion emissions. CCS achieves 50–74 % emissions reductions, with a 5–22 % energy demand increase. While NGfur remains cost-effective today, it faces a 57 % total annual cost (TAC) increase in the 2050 scenario (scenario with high-carbon & low-renewable prices). Integrating CCS, though cost-intensive today, moderates the TAC increase in 2050. Hybfur achieves 40 % and 20 % lower TAC with and without CCS, respectively, compared to NGfur. ELfur, though currently expensive, achieves a 25 % TAC reduction by 2050. Multi-scenario mapping shows that hybrid and oxy-fuel CCS configurations dominate across a wide range of future price conditions, whereas full electrification and hydrogen pathways require significant energy price reductions to become viable. Uncertainty analysis confirms that hybrid configurations maintain the highest probability of economic competitiveness under evolving market conditions. These findings highlight partial electrification as a key decarbonisation strategy, with CCS essential for deep emissions cuts and economic resilience under stringent climate policies.

Authors: Muhammad Salman, Brieuc Beguin, Thomas Nyssen, Grégoire Léonard

Chemical Engineering, University of Liège, Liège, Belgium

Abstract:

Compared to conventional monoethanolamine (MEA), alternative solvents are expected to substantially contribute to reduce the energy demand of post-combustion CO₂ capture from flue gases. This study presents a comprehensive techno-economic analysis of a 27 wt% 2-amino-2-methyl-1-propanol (AMP) + 13 wt% piperazine (PZ) aqueous solution for CO₂ capture, compared to a 30 wt% MEA solution. The study addresses the retrofit of a carbon capture unit to a biomass-fired combined heat and power (CHP) plant, effectively making it a bioenergy with a carbon capture and storage (BECCS) system. The treated flue gas has a flow rate of 23 tons/hour (t/h) with 11.54 vol% CO₂ and a 90% capture rate is aimed for. Aspen Plus V14 was employed for process simulations. Initially, binary interaction parameters for AMP/PZ, AMP/H₂O, and PZ/H₂O are regressed using vapor-liquid equilibrium (VLE) data, which were retrieved from literature along with reaction kinetics. Validation of parameters from available experimental literature yields an average absolute relative deviation (AARD) of only 5.9%. Afterwards, a process simulation model is developed and validated against experimental data from a reference pilot plant, using a similar AMP/PZ blend, resulting in 5% AARD. Next, a sensitivity analysis optimizes operating conditions, including solvent rate, absorber/stripper packing heights, and stripper pressure, based on regeneration energy impact. Optimized results, compared to MEA, reveal that AMP/PZ reduces the energy consumption from 3.61 to 2.86 GJ/tCO₂. The retrofitting of the capture unit onto the selected CHP plant is examined through the development of a dedicated model. Two control strategies are compared to address energy unavailability for supplying the capture unit. The analysis spans 4 months, selected to account for seasonal variations. At nominal capacity, CO₂ emissions, rendered negative by biomass combustion and CO₂ capture, reach a maximum of −3.4 tCO₂/h compared to 0.36 tCO₂/h before retrofitting. Depending on the control strategy and CHP plant operating point, the Specific Primary Energy Consumption for CO₂ Avoided (SPECCA) ranges from 4.91 MJ/kgCO₂ to 1.76 MJ/kgCO₂. Finally, an economic comparison based on systematic methodology reveals a 7.87% reduction in capture cost favoring the AMP/PZ blend. Together, these findings highlight AMP/PZ as a highly favorable alternative solvent.