Pao-Yu Oei

CO2 Highways for Europe: Modeling a Carbon Capture, Transport and Storage Infrastructure for Europe

This paper presents a mixed integer, multi-period, cost-minimising model for a carbon capture, transport and storage (CCTS) network in Europe. The model incorporates endogenous decisions about carbon capture, pipeline and storage investments. The capture, flow and injection quantities are based on given costs, certificate prices, storage capacities and point source emissions. The results indicate that CCTS can theoretically contribute to the decarbonisation of Europe’s energy and industrial sectors. This requires a CO2 certificate price rising to €55 per tCO2 in 2050, and sufficient CO2 storage capacity available for both on- and offshore sites. Yet CCTS deployment is highest in CO2-intensive industries where emissions cannot be avoided by fuel switching or alternative production processes. In all scenarios, the importance of the industrial sector as a first-mover to induce the deployment of CCTS is highlighted. By contrast, a decrease in available storage capacity or a more moderate increase in CO2 prices will significantly reduce the role of CCTS as a CO2 mitigation technology, especially in the energy sector. Furthermore, continued public resistance to onshore CO2 storage can only be overcome by constructing expensive offshore storage. Under this restriction, reaching the same levels of CCTS penetration would require a doubling of CO2 certificate prices.

Modeling a Carbon Capture, Transport, and Storage Infrastructure for Europe

In this paper, we develop a model to analyze the economics of carbon capture, transport, and storage (CCTS) in the wake of expected rising CO2 prices. We present a scalable mixed integer, multiperiod, welfare-optimizing network model for Europe, called CCTS-Mod. The model incorporates endogenous decisions on carbon capture, pipeline and storage investments, as well as capture, flow and injection quantities based on given costs, CO2 prices, storage capacities, and point source emissions. Given full information about future costs of CCTS-technology, and CO2 prices, the model determines a cost minimizing strategy on whether to purchase CO2 certificates, or to abate the CO2 through investments into a CCTS-chain on a site by site basis. We apply the model to analyze different scenarios for the deployment of CCTS in Europe, e.g., under high and low CO2 prices, respectively. We find that beyond CO2 prices of €50 per t, CCTS can contribute to the decarbonization of Europe’s industry sectors, as long as one assumes sufficient storage capacities (onshore and/or offshore). We find that CCTS is only viable for the power sector if the CO2 certificate price exceeds €75 per t.

Prospects for steam coal exporters in the era of climate policies: a case study of Colombia

ABSTRACT Continued global action on climate change has major consequences for fossil fuel markets, especially for coal as the most carbon-intensive fuel. This article summarizes current market developments in the most important coal-producing and coal-consuming countries, resulting in a critical qualitative assessment of prospects for future coal exports. Colombia, as the world’s fourth largest exporter, is strongly affected by these global trends, with more than 90% of its production being exported. Market analysis finds Colombia in a strong competitive position, owing to its low production costs and high coal quality. Nevertheless, market trends and enhanced climate policies suggest a gloomy outlook for future exports. Increasing competition on the Atlantic as well as Pacific market will keep coal prices low and continue pressure on mining companies. Increasing numbers of filed bankruptcies and lay-offs might be just the beginning of a carbon bubble devaluing fossil fuel investments and leaving them stranded. Colombia largely supplies European and Mediterranean consumers but also delivers some quantities to the US Gulf Coast, and to Central and South America. Future coal demand in most of these countries will continue to decline in the next decades. Newly constructed power plants in emerging economies (India, China) are unlikely to compensate for this downturn owing to increasing domestic supply and decreasing demand. Therefore, maintaining or even increasing mining volumes in Colombia should be re-evaluated, taking into account new economic realities as well as local externalities. Ignoring these risks could lead to additional stranded investments, aggravating the local resource curse and hampering sustainable economic development. Key policy insights The climate policies of most of Colombia’s traditional trade partners target steam coal as the more emission-intensive fossil fuel, with many countries implementing or considering a coal phase-out. Coal exporters should re-evaluate their operations and new investments taking into account this new policy environment. To prevent a race to the bottom among coal producers that would favour weak regulation, climate policy makers should also consider the local social and external costs of coal mining, including on health and the local environment.

Designing a Global Energy System Based on 100% Renewables for 2050: GENeSYS-MOD: An Application of the Open-Source Energy Modelling System (OSeMOSYS)

This paper develops a path for the global energy system up to 2050, presenting a new application of the open source energy systems model OSeMOSYS to the community. It allows quite disaggregate energy and emission analysis: GENeSYS-MOD (Global Energy System Model) uses a system of linear equations of the energy system to search for lowestcost solutions for a secure energy supply, given externally defined constraints, mainly in terms of CO2-emissions. The General Algebraic Modeling System (GAMS) version of OSeMOSYS is updated to the newest version and, in addition, extended and enhanced to include e.g. a modal split for transport, an improved trading system, and changes to storages. The model can be scaled from small-scale applications, e.g. a company, to cover the global energy system. The paper also includes an application of GENeSYS-MOD to analyze decarbonization scenarios at the global level, broken down into 10 regions. Its main focus is on interdependencies between traditionally segregated sectors: electricity, transportation, and heating. Model calculations suggests that in order to achieve the 1.5°-2° C target, a combination of renewable energy sources provides the lowest-cost solution, solar photovoltaic being the dominant source. Average costs of electricity generation in 2050 are about 4 €cents/kWh (excluding infrastructure and transportation costs).

The Impact of Policy Measures on Future Power Generation Portfolio and Infrastructure: A Combined Electricity and CCTS Investment and Dispatch Model (ELCO)

This paper presents a general electricity-CO2 (ELCO) modeling framework that is able to simulate interactions of the energy-only market with different forms for national policy measures. We set up a two sector model where players can invest into various types of generation technologies including renewables, nuclear and Carbon Capture, Transport, and Storage (CCTS). For a detailed representation of CCTS we also include industry players (iron and steel as well as cement), and CO2 transport and CO2 storage including the option for CO2 enhanced oil recovery (CO2-EOR). The players maximize their expected profits based on variable, fixed and investment costs as well as the price of electricity, CO2 abatement cost and other incentives, subject to technical and environmental constraints. Demand is inelastic and represented via a selection of type hours. The model framework allows for regional disaggregation and features simplified electricity and CO2 pipeline networks. The model is balanced via a market clearing for the electricity as well as CO2 market. The equilibrium solution is subject to constraints on CO2 emissions and renewable generation share. We apply the model to a case study of the UK Electricity Market Reform to illustrate the mechanisms and potential results attained from the model.

Consequences of the UK energy market reform on the development of Carbon Capture, Transport, and Storage

To achieve the three main energy policy priorities of competitiveness, energy security and decarbonization, the UK government has recently undertaken a major “Energy Market Reform” (EMR). This paper presents a modeling framework to analyze how the different policy measures of the EMR will shape the future UK electricity generation mix until 2050. We set up a two-sector model where players can invest in various types of generation technologies including renewables, nuclear, and Carbon Capture, Transport, and Storage (CCTS). For a detailed representation of CCTS we also include industry players (iron/steel as well as cement), CO2 transport, and CO2 storage including the option for CO2-enhanced oil recovery (CO2-EOR). The players maximize their expected profits based on variable, fix and investment costs, as well as the price of electricity, CO2 abatement, and other incentives, subject to technical and environmental constraints. Demand is inelastic and represented via a selection of representative hours. The model framework allows for regional disaggregation and features simplified electricity and CO2 pipeline networks. The model uses a mass balance as market clearing for electricity and CO2. The equilibrium solution is subject to constraints on CO2 emissions. In this paper we present the model formulation and some preliminary results to illustrate the mechanics of the model. The tentative scenario indicates a diversified technology mix for 2050. The CCTS development is purely triggered by CO2-EOR; the EMR does not incentives any additional CCTS investments.

WATER-Model: An Optimal Allocation of Water Resources in Turkey, Syria and Iraq

Political instability of several countries in the Middle East is overshadowing one of the biggest challenges of the upcoming century: Water - a natural resource that is easily taken for granted, but whose scarcity might lead to serious conflicts. This paper investigates an optimal Water Allocation of the Tigris and Euphrates Rivershed by introducing the WATER-Model. A series of scenarios are analyzed to examine the effects of different levels of cooperation for an optimal water allocation. Special emphasize is put on the effects of filling new Turkish reservoirs which can cause additional welfare losses if these actions are not done on a basin-wide coordinated basis. Modeling results show that Turkey is most efficient in its water usage. However, using the water for irrigation purposes in Turkey, instead of the Iraqi or Syrian domestic and industrial sector, decreases the overall welfare. Especially the Euphrates basin might thus encounter losses of up to 33% due to such strategic behaviour. The predicted water demand growth in the region is going to increase this water scarcity further. Minimum flow treaties between riparian countries, however, can help to increase the overall welfare and should therefore be fostered.