Research and development of catalytic processes for petroleum and natural gas conversions in the Dalian Institute of Chemical Physics

The Dalian Institute of Chemical Physics (DICP) of the Chinese Academy of Sciences has a long history in the R&D of catalysts and catalytic processes for petroleum and natural gas conversions in China. In this paper, results and features of some commercialized petrochemical catalysts and processes as well as newly developed processes for natural gas conversion in the pilot-plant stage are described. (C) 1999 Elsevier Science B.V. All rights reserved.

An integrated air-POM syngas/dimethyl ether process from natural gas

A Cu-Zn-Al methanol catalyst combined with HZSM-5 was used for dimethyl ether (DME) synthesis from a syngas containing nitrogen, which was produced by air-partial oxidation of methane (air-POM). Air-POM occurred at 850 degreesC, 0.8 MPa, CH4/air/H2O/CO2 ratio of 1/2.4/0.8/0.4 over a Ni-based catalyst modified by magnesia and lanthanum oxide with 96% CH4 conversion and constantly gave syngas with a H-2/CO ratio of 2/1 during a period of 450 h. The obtained N-2-containing syngas was used directly for DME synthesis. About 90% CO per-pass conversion, 78% DME selectivity and 70% DME yield could be achieved during 450 h stability testing under the pressure of 5.0 MPa. the temperature of 240 degreesC and the space velocity of 1000 h(-1). (C) 2002 Elsevier Science B. V. All rights reserved.

Empirical analysis and improved modelling of natural gas demand in Ireland

Countries across the world are being challenged to decarbonise their energy systems in response to diminishing fossil fuel reserves, rising GHG emissions and the dangerous threat of climate change. There has been a renewed interest in energy efficiency, renewable energy and low carbon energy as policy‐makers seek to identify and put in place the most robust sustainable energy system that can address this challenge. This thesis seeks to improve the evidence base underpinning energy policy decisions in Ireland with a particular focus on natural gas, which in 2011 grew to have a 30% share of Ireland’s TPER. Natural gas is used in all sectors of the Irish economy and is seen by many as a transition fuel to a low-carbon energy system; it is also a uniquely excellent source of data for many aspects of energy consumption. A detailed decomposition analysis of natural gas consumption in the residential sector quantifies many of the structural drives of change, with activity (R2 = 0.97) and intensity (R2 = 0.69) being the best explainers of changing gas demand. The 2002 residential building regulations are subject to an ex-post evaluation, which using empirical data finds a 44 ±9.5% shortfall in expected energy savings as well as a 13±1.6% level of non-compliance. A detailed energy demand model of the entire Irish energy system is presented together with scenario analysis of a large number of energy efficiency policies, which show an aggregate reduction in TFC of 8.9% compared to a reference scenario. The role for natural gas as a transition fuel over a long time horizon (2005-2050) is analysed using an energy systems model and a decomposition analysis, which shows the contribution of fuel switching to natural gas to be worth 12 percentage points of an overall 80% reduction in CO2 emissions. Finally, an analysis of the potential for CCS in Ireland finds gas CCS to be more robust than coal CCS for changes in fuel prices, capital costs and emissions reduction and the cost optimal location for a gas CCS plant in Ireland is found to be in Cork with sequestration in the depleted gas field of Kinsale.

Natural gas as a sustainable transport fuel

Environmental concerns relating to gaseous emissions from transport have led to growth in the use of compressed natural gas vehicles worldwide with an estimated 13 million Natural Gas Vehicles (NGVs) currently in operation. Across Europe, many countries are replacing traditional diesel oil in captive fleets such as buses used for public transport and heavy and light goods vehicles used for freight and logistics with CNG vehicles. Initially this was to reduce localised air pollution in urban environments. However, with the need to reduce greenhouse gas emissions CNG is seen as a cleaner more energy efficient and environmental friendly alternative. This paper briefly examines the growth of NGVs in Europe and worldwide. Then a case study on CNG the introduction in Spain and Italy is presented. As part of the case study, policy interventions are examined. Finally, a statistical analysis of private and public refuelling stations in both countries is also provided. CNG can also be mixed with biogas. This study and the role of CNG is relevant because of the existing European Union Directive 2009/28/EC target, requiring that 10% of transport energy come from renewable sources, not alone biofuels such as biogas. CNG offers another alternative transport fuel.

An ionic liquid process for mercury removal from natural gas

Efficient scrubbing of mercury vapour from natural gas streams has been demonstrated both in the laboratory and on an industrial scale, using chlorocuprate(ii) ionic liquids impregnated on high surface area porous solid supports, resulting in the effective removal of mercury vapour from natural gas streams. This material has been commercialised for use within the petroleum gas production industry, and has currently been running continuously for three years on a natural gas plant in Malaysia. Here we report on the chemistry underlying this process, and demonstrate the transfer of this technology from gram to ton scale.

Dynamic Modeling and Interaction of Hybrid Natural Gas and Electricity Supply System in Microgrid

Natural gas (NG) network and electric network are becoming tightly integrated by microturbines in the microgrid. Interactions between these two networks are not well captured by the traditional microturbine (MT) models. To address this issue, two improved models for single-shaft MT and split-shaft MT are proposed in this paper. In addition, dynamic models of the hybrid natural gas and electricity system (HGES) are developed for the analysis of their interactions. Dynamic behaviors of natural gas in pipes are described by partial differential equations (PDEs), while the electric network is described by differential algebraic equations (DAEs). So the overall network is a typical two-time scale dynamic system. Numerical studies indicate that the two-time scale algorithm is faster and can capture the interactions between the two networks. The results also show the HGES with a single-shaft MT is a weakly coupled system in which disturbances in the two networks mainly influence the dc link voltage of the MT, while the split-shaft MT is a strongly coupled system where the impact of an event will affect both networks.

Integrated techno-economic and environmental assessments of sixty scenarios for co-firing biomass with coal and natural gas

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 CO2 abatement costs of $27.41–$31.15/tCO2. When whole forest chips are co-fired with coal in a fully paid-off plant, the LCOE and CO2 abatement costs range from $54.68 to $56.41/MW h and $35.60 to $41.78/tCO2, respectively. The LCOE and CO2 abatement costs for straw range from $54.62 to $57.35/MW h and $35.07 to $38.48/tCO2, respectively.

Treatment of natural gas streams with ionic liquids

Being of high relevance for many technological applications, the solubility of sour gases in solvents of low volatility is still poorly described and understood. Aiming at purifying natural gas streams, the present work contributes for a more detailed knowledge and better understanding of the solubility of sour gases in these fluids, in particularly on ionic liquids. A new apparatus, developed and validated specially for phase equilibria studies of this type of systems, allowed the study of the solvent basicity, molecular weight and polarity influence on the absorption of carbon dioxide and methane. The non ideality of carbon dioxide solutions in ionic liquids and other low volatile solvents, with which carbon dioxide is known to form electron donor-acceptor complexes, is discussed, allowing the development of a correlation able to describe the carbon dioxide solubility in low volatile solvents. Furthermore, the non ideality of solutions of light compounds, such as SO2, NH3 and H2S, in ionic liquids is also investigated and shown to present negative deviations to the ideality in the liquid phase, that can be predicted by the Flory-Huggins model. For last, the effect of the ionic liquid polarity, described through the Kamlet-Taft parameters, on the CO2/CH4 and H2S/CH4 selectivities is also evaluated and shown to stand as a viable tool for the selection of ionic liquids with enhanced selectivities.

Natural Gas location design and operation

A major determinant of the level of effective natural gas supply is the ease to feed customers, minimizing system total costs. The aim of this work is the study of the right number of Gas Supply Units – GSUs - and their optimal location in a gas network. This paper suggests a GSU location heuristic, based on Lagrangean relaxation techniques. The heuristic is tested on the Iberian natural gas network, a system modelized with 65 demand nodes, linked by physical and virtual pipelines. Lagrangean heuristic results along with the allocation of loads to gas sources are presented, using a 2015 forecast gas demand scenario.

Optimization model for medium term natural gas commitment

In this paper we study the optimal natural gas commitment for a known demand scenario. This study implies the best location of GSUs to supply all demands and the optimal allocation from sources to gas loads, through an appropriate transportation mode, in order to minimize total system costs. Our emphasis is on the formulation and use of a suitable optimization model, reflecting real-world operations and the constraints of natural gas systems. The mathematical model is based on a Lagrangean heuristic, using the Lagrangean relaxation, an efficient approach to solve the problem. Computational results are presented for Iberian and American natural gas systems, geographically organized in 65 and 88 load nodes, respectively. The location model results, supported by the computational application GasView, show the optimal location and allocation solution, system total costs and suggest a suitable gas transportation mode, presented in both numerical and graphic supports.

Estudo da Viabilidade Técnico-Económica de umm Sistema de Cogeração para um Complexo de Piscinas Interiores

A presente dissertação centrou-se no estudo técnico-económico de dois cenários futuros para a continuação de fornecimento de energia térmica a um complexo de piscinas existente na região do vale do Tâmega. Neste momento a central de cogeração existente excedeu a sua licença de utilização e necessita de ser substituída. Os dois cenários em estudo são a compra de uma nova caldeira, a gás natural, para suprir as necessidades térmicas da caldeira existente a fuelóleo, ou o uso de um sistema de cogeração compacto que poderá estar disponível numa empresa do grupo. No primeiro cenário o investimento envolvido é cerca de 456 640 € sem proveitos de outra ordem para além dos requisitos térmicos, mas no segundo cenário os resultados são bem diferentes, mesmo que tenha de ser realizado o investimento de 1 000 000 € na instalação. Para este cenário foi efetuado um levantamento da legislação nacional no que toca à cogeração, recolheram-se dados do edifício como: horas de funcionamento, número de utentes, consumos de energia elétrica, térmica, água, temperatura da água das piscinas, temperatura do ar da nave, assim como as principais características da instalação de cogeração compacta. Com esta informação realizou-se o balanço de massa e energia e criou-se um modelo da nova instalação em software de modelação processual (Aspen Plus® da AspenTech). Os rendimentos térmico e elétrico obtidos da nova central de cogeração compacta foram, respetivamente, de 38,1% e 39,8%, com uma percentagem de perdas de 12,5% o que determinou um rendimento global de 78%. A avaliação da poupança de energia primária para esta instalação de cogeração compacta foi de 19,6 % o que permitiu concluir que é de elevada eficiência. O modelo criado permitiu compreender as necessidades energéticas, determinar alguns custos associados ao processo e simular o funcionamento da unidade com diferentes temperaturas de ar ambiente (cenários de verão e inverno com temperaturas médias de 20ºC e 5ºC). Os resultados revelaram uma diminuição de 1,14 €/h no custo da electricidade e um aumento do consumo de gás natural de 62,47 €/h durante o período mais frio no inverno devido ao aumento das perdas provocadas pela diminuição da temperatura exterior. Com esta nova unidade de cogeração compacta a poupança total anual pode ser, em média, de 267 780 € admitindo um valor para a manutenção de 97 698 €/ano. Se assim for, o projeto apresenta um retorno do investimento ao fim de 5 anos, com um VAL de 1 030 430 € e uma taxa interna de rentabilidade (TIR) de 14% (positiva, se se considerar a taxa de atualização do investimento de 3% para 15 anos de vida). Apesar do custo inicial ser elevado, os parâmetros económicos mostram que o projeto tem viabilidade económica e dará lucro durante cerca de 9 anos.