The post-combustion capture pilot plant Niederaussem–Results of the first half of the testing programme

Moser, Peter; Schmidt, Sandra; Sieder, Georg; García, Hugo; Stoffregen, Torsten; Stamatov, Veselin

doi:10.1016/j.egypro.2011.01.188

Cited by 30 publications

(9 citation statements)

References 3 publications

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“…In connection with the adaptation of the PCC technique to the requirements of a dry-lignite power plant, this offers the unique opportunity to operate the testing facilities in a coupled mode. This configuration allows flue gas from the combustion of dry lignite and from the high performance FGD to be fed to the PCC pilot plant (Moser et al, 2010a). For this reason the flue gas properties are very similar to that of future dry lignite-fired power plants.…”

Section: Pilot Plant At Niederaussem and Testing Programmentioning

confidence: 95%

Performance of MEA in a long-term test at the post-combustion capture pilot plant in Niederaussem

Moser

Schmidt

Sieder

et al. 2011

International Journal of Greenhouse Gas Control

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Section: Pilot Plant At Niederaussem and Testing Programmentioning

confidence: 95%

Performance of MEA in a long-term test at the post-combustion capture pilot plant in Niederaussem

Moser

Schmidt

Sieder

et al. 2011

International Journal of Greenhouse Gas Control

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“…This small PCC pilot plant on coal-derived flue gas was constructed, commissioned, and started-up in 2009. Despite the rather small dimensions and a capacity to capture only 7.2 tonnes of CO 2 per day from a flue gas slipstream of the power plant, several critical issues were successfully tested [1], [2]. In particular, reliable data on energy consumption and long-term stability were generated, which will serve as a basis for the follow-on pilot project funded by the U.S. Department of Energy's National Energy Technology Laboratory (DOE-NETL).…”

Section: Basf-linde Partnershipmentioning

confidence: 99%

Pilot-scale Demonstration of an Advanced Aqueous Amine-based Post-combustion Capture Technology for CO2 Capture from Power Plant Flue Gases

et al. 2014

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Post-combustion CO 2 capture (PCC) technology offers flexibility to treat the flue gas from both existing and new coal-fired power plants and can be applied to treat all or a portion of the flue gas. Solvent-based technologies are today the leading option for PCC from large coal-fired power plants as they have been applied in large-scale in other applications. Linde and BASF are working together to further improve a post-combustion capture technology incorporating BASF's novel aqueous amine-based process based on the results of the joint development of BASF, Linde and RWE at the PCC pilot plant in Niederaussem, Germany. This technology offers significant benefits compared to other solvent-based processes as it aims to reduce the regeneration energy requirements using novel solvents that are very stable under the coal-fired power plant feed gas conditions. BASF has developed the desired solvent based on the evaluation of a large number of candidates and long-term small pilot-scale testing has been performed on a lignite-fired flue gas. Linde has evaluated a number of options for capital cost reduction in large engineered systems for solvent-based PCC technology.Pilot-scale demonstration on a coal-fired power plant flue gas at a 1-1.5 MW e scale is currently planned under a project supported by DOE (project award DE-FE0007453). Mechanical completion of the pilot plant was achieved in July 2014 and the final commissioning activities are being completed to enable start-up of operations in late 2014. The pilot plant incorporates the capability to test a number of unique features of the Linde-BASF technology aimed at lowering the overall energy consumption as well as resulting in capital cost reduction.In this presentation, the details of the fabrication, construction and start-up of the pilot plant will be discussed. The pilot plant incorporates significant instrumentation and control features to enable automated and stable operation, and the ability to reliably

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“…HEIA and 2oxazolidone were detected in the pilot plant samples with the latter being reported as an oxidative degradation product, common with thermal degradation. Moreover, Moser et al (2011) suggest that, even though carbamate polymerisation products were detected in samples from a pilot plant at Niederaussem, oxidative degradation products were detected at higher concentrations after 5000 h of operation. However, in both the aforementioned studies, neither solvent reclaiming units nor oxidation inhibitors were used in the pilot plants described.…”

Section: Introductionmentioning

confidence: 95%

“…Thus, it is considered that it can be readily implemented on a large scale at existing power plants for CO2 removal (Mangalapally et al, 2009). Aqueous solutions of 30% (w/v) monoethanolamine (MEA) are the reference solvents for such processes (Moser et al, 2011). There are numerous technical and environmental challenges that are encountered during the application of MEA in industrial CO2-scrubbing systems.…”

Section: Introductionmentioning

confidence: 99%

Thermal degradation of monoethanolamine and its effect on CO2 capture capacity

Zoannou

Sapsford

Griffiths

2013

International Journal of Greenhouse Gas Control

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Amine scrubbing is a proven technology in the oil and gas industries. Its use in coal fired power plants is not fully understood and the likelihood of solvent degradation is high. Decreased absorption efficiency, undesirable by-products and the environmental impact of their disposal are the main consequences. In the present study, samples of monoethanolamine were thermally degraded, at 160•C for between 2 and 8 weeks, and their CO2 removal capacity deterioration was determined. The findings show that thermal degradation at 160•C for 8 weeks reduced monoethanolamine concentration by 95%, but the remaining solvent still retained 22% of its capacity to remove CO2, probably due to the capacity of some of the degradation products to remove CO2. Therefore, the requirement for monoethanolamine make-up in operational amine scrubbing systems may not be quite as serious as initially believed. A 20% higher MEA loss was determined in the samples with 0.37 initial CO2 loading (mol CO2/mol MEA). 2-Oxazolidone, N-(2-hydroxyethyl)-ethylenediamine and 1-(2-hydroxyethyl)-2-imidazolidinone were identified as the major monoethanolamine degradation products, the latter being indicated as the most stable product with concentrations of up to 17% (v/v). Corrosion (1.95 mm/year) of the stainless steel (type 316) equipment, used during the experiments, was also observed.

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The post-combustion capture pilot plant Niederaussem–Results of the first half of the testing programme

Cited by 30 publications

References 3 publications

Performance of MEA in a long-term test at the post-combustion capture pilot plant in Niederaussem

Performance of MEA in a long-term test at the post-combustion capture pilot plant in Niederaussem

Pilot-scale Demonstration of an Advanced Aqueous Amine-based Post-combustion Capture Technology for CO2 Capture from Power Plant Flue Gases

Thermal degradation of monoethanolamine and its effect on CO2 capture capacity

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