Agency: European Commission | Branch: FP7 | Program: CP | Phase: ENERGY-2007-2.3-06 | Award Amount: 7.61M | Year: 2008
NORSEWInD is a programme designed to provide a wind resource map covering the Baltic, Irish and North Sea areas. The project will acquire highly accurate, cost effective, physical data using a combination of traditional Meteorological masts, ground based remote sensing instruments (LiDAR & SoDAR) and Satellite acquired SAR winds.The vertical resolution of the ground based instruments will be used to calibrate the Satellite data to provide hub height, real world data. The resultant wind map will be the first stop for all potential developers in the regions being examined, and as such represents an important step forward in quantifying the quality of the wind resource available offshore. The techniques employed are fully transferrable, meaning that they can be repeated in any offshore environment. This will be showcased in the NORSEWInD validation task. Remote sensing has a hugely important role to play within the wind industry, and their use within the NORSEWInD programme to reduce the cost and increase the accuracy of offsore wind measurements will increase acceptance and showcase the ability and power of the techniques.
Woods A.W.,University of Cambridge |
Espie T.,BP Alternative Energy
Geophysical Research Letters | Year: 2012
Sequestration of carbon dioxide in deep saline aquifers has been proposed and investigated as a viable solution to help mitigate carbon emissions from fossil fuels. Much research has been directed at understanding the transitions of supercritical CO2 from being a mobile fluid phase to being trapped by capillarity or dissolved in groundwater; such transitions lead to a reduction in mobility of CO2 and hence in the risk of leakage to the surface. Following injection, buoyant plumes of CO2 migrate updip towards structural traps in the geological strata; however, some of this CO 2 may be capillary trapped in pore spaces or dissolved in groundwater en route. Since CO2 saturated groundwater only has a small CO 2 concentration, the dissolution of any large, structurally trapped plumes of CO2 may be controlled by the availability of unsaturated groundwater. In an aquifer of finite vertical extent, this may be rate limited by a combination of (i) the background hydrological flow coupled with (ii) the slow lateral exchange of relatively dense, CO2 saturated groundwater with unsaturated groundwater. In an inclined aquifer, this may be controlled by the slow along-aquifer component of gravity. Structurally trapped plumes of CO2 may therefore persist for many thousands of years, and, since they are potentially highly mobile, may represent an important contribution to the long term risks associated with CO2 sequestration at particular sites. © 2012 by the American Geophysical Union.
BP Alternative Energy | Date: 2011-07-15
A method is described for use in the separation of carbon dioxide from a gas mixture comprising carbon dioxide. The method includes the steps of: (i) compressing and cooling the gas mixture using a compressor to form a two-phase mixture including liquid carbon dioxide (ii) separating a liquid carbon dioxide stream from the two-phase mixture; and (iii) recirculating at least a part of the liquid carbon dioxide stream and introducing the recirculated liquid stream into a process stream by recirculating separated liquid CO_(2 )into an upstream process stream, cooling of the process stream can be obtained. By using the liquid stream, additional cooling is possible as cooling is affected by the evaporation of the liquid CO_(2). Thus the recirculated liquid can be used to reduce the temperature of the process stream.
BP Alternative Energy | Date: 2014-04-23
This invention relates to the separation of components from a gas mixture. Aspects of the invention relate to the separation of components, for example carbon dioxide (CO_(2)) and/or hydrogen sulphide (H_(2)S) from, for example, acid gas, for example natural gas, syngas or process gas although features of the invention may be applied to other source gases. Such a process is sometimes referred to as acid gas removal (AGR). In examples described herein, the source gas mixture contains CO_(2) and/or H_(2)S in addition to other components and in some examples, the CO_(2) and/or H_(2)S components of the gas are referred to as acid gas components. In examples of the invention, some or all of the acid gas component is removed using a solvent absorption method; some examples described use a chemical absorption system (for example including N-Methyl diethanolamine (MDEA)), and others use a physical solvent (for example based on methanol (MeOH)).
BP Alternative Energy | Date: 2013-10-22
This invention relates to the separation of components from a gas mixture. Aspects of the invention relate to the separation of components, for example carbon dioxide (CO_(2)) and/or hydrogen sulphide (H_(2)S) from, for example, acid gas, for example natural gas, syngas or process gas although features of the invention may be applied to other source gases. Such a process is sometimes referred to as acid gas removal (AGR). In examples described herein, the source gas mixture contains CO_(2 )and/or H_(2)S in addition to other components and in some examples, the CO_(2 )and/or H_(2)S components of the gas are referred to as acid gas components. In examples of the invention, some or all of the acid gas component is removed using a solvent absorption method; some examples described use a chemical absorption system (for example including N-Methyl diethanolamine (MDEA)), and others use a physical solvent (for example based on methanol (MeOH)).
BP Alternative Energy | Date: 2010-09-29
A method of injecting CO_(2) into an aquifer or a depleted hydrocarbon reservoir via at least one injection well provided with an injection tubing that is in sealing engagement with the injection well, which method comprises operating an injection facility to inject a CO_(2) stream down the injection tubing of the injection well at above the critical pressure of CO_(2), characterised in that the injection tubing is provided with a fluid injection control valve at or near the bottom thereof which is closed or closes when the pressure above the valve is less than a pre-set pressure value and opens or reopens when the pressure above the valve is at or greater than said pre-set pressure value.
BP Alternative Energy | Date: 2010-09-29
A process for removing carbon dioxide from a synthesis gas feed stream in a cryogenic separation plant that comprises either a single cryogenic separation stage or at least two cryogenic separation stages arranged in series, with the stages in the series being designated stage 1 through stage N, the letter N representing the number of stages in the series, the single stage or each stage of the series comprising the steps of (a) condensing carbon dioxide from the synthesis gas by cooling the synthesis gas by non-contact heat exchange (E-102,E-103,E-104) with an external refrigerant (propane, ethane) to produce liquefied carbon dioxide, and (b) separating the liquefied carbon dioxide from the synthesis gas, with the single separation stage discharging a liquefied carbon dioxide product stream and a hydrogen enriched synthesis gas stream or, with each of the stages in the series cooling the synthesis gas to a successively lower temperature as the synthesis gas progresses from stage 1 to stage N, thereby separately removing a liquefied carbon dioxide product stream (14) from each of the stages, with stage N discharging a hydrogen enriched synthesis gas vapour stream (155), characterized in that:(i) the synthesis gas feed stream comprises 40 to 65 mole % hydrogen and is fed to the single stage or the first stage of the series at a pressure in the range of 46 to 76 bar absolute;(ii) the single stage or stage N of the series is operated at a temperature in the range of -53 to -48C and a pressure in the range of 44 to 74 bar absolute such that the single stage or the combined stages of the series remove 70 to 80% of the total moles of carbon dioxide in the synthesis gas feed stream; and(iii) the liquefied CO_(2) product stream (16) removed from the single stage or the liquefied C02 product streams removed from each stage of the series are sequestrated.
BP Alternative Energy | Date: 2010-02-24
A method of removing nitrogen oxides and sulphur oxides from a flue gas emitted by an oxyfuel combustion process comprises the steps of:(v) supplying a flue gas from an oxyfuel combustion process, the flue gas comprising nitrogen oxides and sulphur oxides contaminants;(vi) oxidising nitric oxide present in the flue gas to form nitrogen dioxide;(vii) contacting the flue gas with a solution comprising water and ammonia to produce ammonium sulphate, ammonium nitrate and an exhaust gas substantially free of nitrogen oxides and sulphur oxides; and(viii) separating the exhaust gas, the ammonium sulphate and the ammonium nitrate produced in step (iii) from the solution comprising water and ammonia.
BP Alternative Energy | Date: 2010-02-03
This invention relates to the recovery of carbon dioxide and hydrogen in a concentrated form from a synthesis gas stream comprising hydrogen and carbon dioxide thereby generating a carbon dioxide stream that may be used in a chemical process, or may be sequestered or used for enhanced oil recovery before being ultimately sequestered, and a hydrogen stream that may be used as fuel for a power plant thereby generating electricity or as fuel for a low pressure burner of a fired heater, or as fuel for a reformer or boiler or as a refinery feed stream for upgrading of one or more refinery streams or as a hydrogen feed to a chemical process.
Beavis R.,BP Alternative Energy
Energy Procedia | Year: 2011
After 3 years and over one thousand person-months of effort, the FP6 CACHET project was successfully concluded in the first half of 2009. CACHET focussed on pre-combustion capture of carbon dioxide (CO2) from natural gas fuelled power generation and hydrogen (H2) production. Through a combination of experimental and paper studies, CACHET developed, optimised and evaluated four promising capture technologies: Advanced steam methane reforming (HyGenSys), Redox technologies (chemical looping), Metal membranes and Sorption enhanced water gas shift (SEWGS). This paper reports the technical and economic conclusions of the project and provides a look ahead to the future for each of the technologies and the challenges for full scale deployment. All technologies showed the potential to reduce CO2 emissions by more than 90% and the opportunity to improve the energy efficiency compared to the state-of-the-art technology. © 2011 Published by Elsevier Ltd.