DECC 2050 Pathways Analysis
Posted by Department of Energy and Climate Change on 17/02/2011 4 comments
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Heating adapted to electricity vs renewable gas
Electrification of Heating
The aim of Pathways 2050 is broadly that heating, roughly 1/3 of energy use, needs to be electrified in order to eliminate its present level of emissions. So far, for domestic use, the most efficient for m of electric heating is the heat pump, but the installations of these so far have had serious problems (EST study of 80 shows 75-80% of systems are defective).
Renewable gas solutions would permit the continued use of the gas distribution grid as well as equipment such as condensing boilers, until heat pump technology can be further investigated and improved.
Embodied energy use to replace existing infrastructure and equipment
If heating could be freed from use of fossil fuels without abandoning the existing plant and installing new equipment, this would be an advantage as it would avoid the embodied energy wasted by abandoning and replacing equiment.
Potential of renewable gas
If renewable gas, eg methane from waste, Bio SNG, Hydrogen, could be produced and injected directly into the natural gas grid, this could allow heating no longer to be dependent on fossil fuels, if enough synthetic gas can be produced. Waste-to-energy systems are increasing in numbers – this is logical because they deal with two problems simultaneously, waste treatment and renewable fuel generation (or heat in the less popular process of incineration). Anaerobic Digestion produces methane which can be injected into the natural gas grid after cleansing. Bio-SNG plants can deal with hard waste such as timber / biomass as well soft organic waste to produce synthetic gas. Lead by Asian enterprises, the production of methane from Municipal Sewage Waste is expected to grow repaidly. Logically, the Waste-To-Energy strategy should be pursued as a priority {there is already cost to treat waste; even more costly processes to produce renewable fuels could fund themselves by rises in the price of the renewable energy produced).
Hydrogen can be made as a bi-product of coal gasification and carbon sequestration and injected into the existing natural gas grid. (Sultan, et al, Chem Engin Dept, Camb Univ, 2011) A hydrogen infrstucture is being created in Germany (H2 Patent) to power rule cell vehicles.
Energy storage for peak demand
Not only do renewable gas solutions by-pass the current problems with heat pump technology, while allowing the continued use of extensive gas-powered infrastructure and equipment, they also highlight another advantage of gas, namely that it can be STORED whereas electricity currently cannot . Storage of potential energy permits the strategic targeting of peak points of demand.
M Reynolds
BA (Harvard), MA MPhil(Cantab), M Arch (MIT)
Synthetic Natural Gas (SNG produced from waste, biomass and coal
The report below identifies some of the practical possibilities of injecting SNG into the gas grid. Far larger quantities of SNG can be produced at significantly lower cost by co-gasfying waste, biomass and coal using industrial scale Oxygen blown slagging co-gasification technology, originally developed to produce pipeline quality SNG from 'clean coal', but proven 20 years ago for the co-gasificaction of mised 80% sustainable and 20% fossil fuels. This overcomes many of the supply chain constraints which apply to biomass and biowaste co-gasification schemes. High temperature and pressure co-gasification destroys Persistant Organic Pollutants, and can thus process hazardous wastes, thereby increasing the available fuel supply and income from waste gate fees.
The UK produces around 250 to 275 million tonnes pa of energy-bearing liquid and solid hazardous and non-hazardous wastes, contaminated and woody biomass, biofuels, energy crops, coal and petcoke. Landfill and coal tip mining could also provide an additional currently unquantified fuel supply. Co-gasifying around 75mtpa of this total will produce around 33% of current UK gas demand, or 33% of 2030 UK electricity demand.
The production of SNG requires the separation of CO2 from Methane, producing a readily available almost pure CO2 stream. SNG schemes are, therefore, inherently Carbon Capture Ready at low additioanl cost, compared with post combustion CCS schemes. A 52.5% biogenic fuel stream converted to clean Syngas, which is in turn split 20% to electricity generation and 80% to SNG production, with 50% post methanation CCS, i.e. 40% total Carbon capture, will produce the same emissions as a 100% fossil fuel with 90% Carbon capture. This dramatically reduces the cost of CCS compared with post combustion CCS on fossil fuels. In addition, the electricity and SNG injected into the grids will receive double ROC's, and RHI's for the biogenic proportion of the input fuel.
Ongoing engineering and cost benefit analyses indicate provisionally the following out-turn costs:
1 52.5% biogenic peak load electricity at a levelised cost of around £35 to £40/MWh unabated, attracting ROC's worth £57.50/MWh.
2 52.5% high pressure SNG at a levelised cost of around 60p/therm unabated, attracting RHI's woth 85p/therm.
3 Marginal ababtement cost of Carbon of around £45/tonne, less Carbon cost savings of £22.50/tonne (based on £30/tonne Carbon floor cost).
Subject to validation, the above costs for energy and CCS are around 50% of those currently published by the EU Zero Emissions Platform.
Tony Day