Patent Application
20090301100
The present invention relates to a method and an apparatus for generating electrical power that is based on the use of coal bed methane gas as a source of energy for driving a gas turbine and a steam turbine for generating the power.
The term “coal bed methane” is understood herein to mean gas that contains at least 75% methane gas on a volume basis obtained from an underground coal source.
International application PCT/AU2004/001339 (WO 2005/5031136) in the name of the applicant describes and claims a method of generating power via a gas turbine and a steam turbine in a power plant which comprises operating in a first mode by:
The International application also discloses operating in a second mode by:
The International application also discloses an apparatus for generating power.
The disclosure in the International application is incorporated herein by cross reference.
One of the features of the method described and claimed in the International application is that it can operate with no CO2 emissions into the atmosphere. By way of example, by operating the first operating mode of the method so that step (d)(ii) supplies all of the flue gas, which inevitably contains substantial amounts of CO2, that is not supplied to the combustor of the gas turbine to the suitable underground storage is an effective option for preventing CO2 emissions into the atmosphere that does not have any adverse environmental consequences.
Another feature of the method described and claimed in the International application is that the use of part of the flue gas stream from the gas turbine in the combustor of the gas turbine in step (d)(i) of the first operating mode of the method makes it possible to reduce, and preferably replace altogether, the use of air in the combustor of the gas turbine. The total replacement of air with oxygen and flue gas, which is predominantly CO2 in this mode of operation, overcomes significant issues in relation to the use of air. For example, the use of air means that the flue gas stream from the gas turbine contains a significant amount (typically at least 70 vol. %) nitrogen, an amount (typically 10 vol. %) oxygen, and an amount (typically 5-10 vol. %) CO2. The mixture of nitrogen, oxygen, and CO2 presents significant gas separation issues in order to process the flue gas stream properly. The replacement of air with oxygen and flue gas in this mode of operation means that the flue gas stream from the heat recovery steam generator is predominantly CO2 and water and greatly simplifies the processing requirements for the flue gas from the gas turbine, with the result that it is a comparatively straightforward exercise to produce a predominately CO2 flue gas stream and supply the stream to the combustor of the gas turbine.
Typically, coal bed methane is extracted from underground coal deposits located in remote areas, i.e. areas that are well away from substantial population centres and, therefore, it is necessary to transport the coal bed methane to the population centres to use the coal bed methane.
Coal bed methane contains water, typically in an atomised form. The current industry practice is to condense water from coal bed methane after extraction from an underground deposit and thereafter transport the dewatered coal bed methane to population centres.
The water in coal bed methane has high salinity and high total dissolved solids and, consequently, has limited (if any) uses at the remote locations from which it is extracted. Purifying the water, for example by reverse osmosis, to make the water potable and thereafter transporting the water to population centres is also not a commercially acceptable option. Accordingly, the current practice is to transfer the water to solar ponds to evaporate in the ponds. This represents a substantial waste of water, typically or the order of millions of litres per day.
The applicant has realised that the method and apparatus described and claimed in the International application and, in particular operation with no CO2 emissions by returning flue gas to an underground storage or recycling CO2 through the process, is a significant driver to locate electrical power stations proximate deposits of coal bed methane.
The applicant has also realised that locating electrical power stations proximate deposits of coal bed methane provides an opportunity to use water separated from coal bed methane beneficially in the power stations, for example as make-up water and/or as cooling water, and thereby reduce the operating costs of the power stations. By way of example, it is relevant to note that substantial volumes of water are separated from coal bed methane and substantial volumes of water are required on a daily basis in power stations. This realisation is the basis of a first aspect of the present invention.
The applicant has also realised that further advantages are possible by modifying the method and the apparatus described and claimed in the International application to include supplying steam to the combustor of the gas turbine. This realisation is the basis of a second aspect of the present invention.
In general terms, according to the first aspect of the present invention there is provided a method of generating power in a power plant which comprises: separating coal bed methane and water extracted from an underground deposit, using the coal bed methane as a source of energy for operating a gas turbine and ultimately generating electricity in the power plant, and using the water in the power plant, for example in a cooling water circuit of the power plant.
In more specific terms, according to the first aspect of the present invention there is provided a method of generating power via a gas turbine and a steam turbine in a power plant which comprises operating in a first mode by:
Preferably the method includes treating the water dewatered from coal bed methane in step (a) to at least partially reduce the salinity and/or total dissolved solids of the water.
Preferably step (f) includes supplying at least a part of the water dewatered from coal bed methane in step (a) for use as make-up water in the heat recovery steam generator.
Preferably the method includes supplying a part of a flue gas produced in the gas turbine, under pressure, to the combustor of the gas turbine in step (b).
Preferably the method includes supplying high pressure steam produced in the steam generator in step (c), under pressure, to the combustor of the gas turbine in step (b).
Preferably the oxygen-containing gas supplied to the combustor of the gas turbine in step (b) is oxygen-enriched air.
More preferably the oxygen-containing gas supplied to the combustor of the gas turbine in step (b) is oxygen.
Preferably the method includes supplying compressed air from an air compressor of the gas turbine to an oxygen plant and producing oxygen gas for step (b).
Preferably the flue gas stream supplied to the combustor of the gas turbine in step (b) is predominantly CO2.
Preferably step (e) includes supplying part of the flue gas stream to the combustor of the gas turbine and the remainder of the flue gas stream to the underground storage.
Preferably step (e) includes supplying the flue gas stream to the underground storage region as a liquid phase.
Preferably the underground storage region is a coal bed seam.
More preferably the underground storage region is the coal bed seam from which coal bed methane to power the gas turbine is extracted. In this context, the existing well structures for extracting coal bed methane can be used to transfer flue gas, in liquid or gas phases, to the underground storage region.
Preferably step (e) includes supplying the flue gas stream to the underground storage region via existing well structures for extracting coal bed methane from the underground storage region.
Preferably step (e) includes separating water from the flue gas.
Step (e) may further include:
Step (e) may further include:
Preferably the method includes operating in a second mode as an alternative to the first mode by:
In general terms, according to the first aspect of the present invention there is also provided an apparatus for generating power in a power plant which comprises: a means for separating coal bed methane and water from an underground deposit, a gas turbine that is operable with coal bed methane produced in the coal bed methane/water separation means, and a cooling water circuit that is operable with water produced in the coal bed methane/water separation means.
In more specific terms, according to the first aspect of the present invention there is also provided an apparatus for generating power which comprises:
According to the second aspect of the present invention there is provided a method of generating power via a gas turbine and a steam turbine which comprises operating in a first mode by:
One advantage of supplying steam to the gas turbine in step (a) is that it reduces the dependency of the method on supplying flue gas to the gas turbine to maintain mass flow rate through the gas turbine.
Another advantage of supplying steam to the combustor of the gas turbine in step (a) is that it reduces power requirements to compress flue gas for the gas turbine.
Preferably the steam supplied to the combustor of the gas turbine in step (a) is at least a part of the steam generated in the heat recovery steam generator in step (b).
Preferably steam supplied to the combustor of the gas turbine in step (a) is at a pressure of 15-30 bar.
Preferably the method includes supplying a part of a flue gas produced in the gas turbine, under pressure, to the combustor of the gas turbine in step (a).
Preferably the oxygen-containing gas supplied to the combustor of the gas turbine in step (a) is oxygen-enriched air.
More preferably the oxygen-containing gas supplied to the combustor of the gas turbine in step (a) is oxygen.
Preferably the flue gas stream supplied to the combustor of the gas turbine in step (a) is predominantly CO2.
Preferably the method includes supplying compressed air from an air compressor of the gas turbine to an oxygen plant and producing oxygen-containing gas for step (a).
Preferably step (d) includes supplying a part of the flue gas stream to the combustor of the gas turbine and the remainder of the flue gas stream to the underground storage.
Preferably step (d) includes supplying the flue gas stream to the underground storage region as a liquid phase.
Preferably the underground storage region is a coal bed seam.
More preferably the underground storage region is the coal bed seam from which coal bed methane to power the gas turbine is extracted. In this context, the existing well structures for extracting coal bed methane can be used to transfer flue gas, in liquid or gas phases, to the underground storage region.
Preferably step (d) includes supplying the flue gas stream to the underground storage region via existing well structures for extracting coal bed methane from the underground storage region.
Preferably step (d) includes separating water from the flue gas.
Step (d) may further include:
Step (d) may further include:
Preferably the method includes operating in a second mode as an alternative to the first mode by:
According to the second aspect of the present invention there is also provided an apparatus for generating power which comprises:
Preferably the apparatus includes a system for supplying a part of the steam generated in the steam generator to the combustor of the gas turbine.
The present invention is described further with reference to the accompanying drawing which is one, although not the only, embodiment of a power generation method and power generation apparatus of the invention.
With reference to the figure, the method includes separating coal bed methane and water that are extracted together from an underground source 3 in a condenser or other suitable separation means 71 into two separate product streams, namely coal bed methane and water.
The water from the condenser 71 is supplied via a line 75 for use in one or more than one unit operation in the power generation apparatus shown in the figure. One application is in a cooling water circuit (not shown) of the apparatus. The cooling water circuits include, by way of example, one or more than one water cooling tower in which the water is used as make-up water. Another application is as make-up water in a heat recovery steam generator 27, described hereinafter.
In situations where the typically high salinity and typically high total dissolved solids of the water is an issue, the method includes treating the water from the condenser 71 to lower the salinity and TDS levels, for example by passing the water through a reverse osmosis unit, before using the water in the cooling water circuit
The method further includes supplying the following gas streams to a combustor 5 of a gas turbine generally identified by the numeral 7:
The streams of oxygen, steam, and flue gas are pre-mixed in a mixer 9 upstream of the combustor 5.
The stream of coal bed methane and the stream of oxygen/steam/flue gas are supplied to the combustor 5 at a preselected pressure of between 15 and 30 bar. It is noted that the combustor 5 may operate with any suitable pressure.
The coal bed methane is combusted in the combustor 5 and the products of combustion and the flue gas supplied to the combustor 5 are delivered to an expander 13 of the turbine 7 and drive the turbine blades (not shown) located in the expander 13.
The output of the turbine 7 is connected to and drives an electrical generator 15 and a multiple stage flue gas compressor train 17.
When the power generation method is operating in the above-described mode, air in the air compressor 21 of the turbine 7 is bled at approximately 5 bar pressure and delivered to the air separation plant and is used to produce oxygen for the combustor 5 of the gas turbine 7.
The output gas stream, ie the flue gas, from the turbine 7 is at atmospheric pressure and typically at a temperature of the order of 540° C.
The flue gas from the turbine 7 is passed through the heat recovery steam generator 27 and is used as a heat source for producing high pressure steam, typically approximately 75 bar or 7.5 Mpa, from a stream of demineralised water and condensate return supplied to the steam generator 27.
A part of the high pressure steam is supplied via the line 63 to the combustor 5 of the gas turbine 7, as described above.
Another part of the high pressure steam is supplied via a line 57 to a steam turbogenerator 29 and is used to run the turbogenerator 29 and generate electrical power.
A further part of the high pressure steam is supplied via a line 61 to the air separation plant 11 to generate oxygen for the combustor 5 of the gas turbine 7.
The flue gas from the heat recovery steam generator 27, which is predominantly CO2 and water, leaves the steam generator as a wet flue gas stream, typically at a temperature of 125° C., via an outlet 19.
The wet flue gas is then passed through a water separator 33 that separates water from the stream and produces a dry flue gas stream.
The dry flue gas stream is then passed through the multiple (in this case two) stage flue gas compressor train 17.
In a first stage of compression, marked “Stage 1” in the figure, the flue gas is compressed to the necessary pressure, namely between 15 and 30 bar, typically 22 bar in the present instance, for the combustor 5 of the turbine 7.
A part of the compressed flue gas from the exit of the first stage is supplied to the combustor 5 of the turbine 7 via the mixer 9, typically a mix valve, and mixes with oxygen from the air separator 11 prior to being supplied to the combustor 5.
The remainder of the compressed flue gas from the first stage, which is predominantly CO2 and water, is supplied to the second compression stage, marked “Stage 2” in the figure, via a condenser 59 and a water separator 61. The flue gas is compressed to a higher pressure, typically above 70 bar, preferably above 73 bar, and the stream of compressed flue gas is then passed through a condenser 35. The condenser 35 cools the temperature of the flue gas stream to below 31° C. and thereby converts the flue gas to a liquid phase.
The liquid flue gas stream leaving the condenser is pressurised (if necessary) and then injected into existing field wells.
When the power generation system is not operating in the above-described mode and, more particularly is not receiving the stream of pre-mixed oxygen and flue gas, the turbine 7 operates on a conventional basis with air being drawn through the turbine air intake (not shown) and compressed in the air compressor 21 and thereafter delivered to the combustor 5 and mixed with coal bed methane and the mixture combusted in the combustor 5.
More particularly, the option of operating on a more conventional basis is available by disconnecting the multiple stage flue gas compressor train 17 from the turbine 7.
The key components of the above-described embodiment of the process and the apparatus of the invention shown in the figure are as follows:
Many modifications may be made to the embodiment of the present invention described above with reference to the figure without departing from the spirit and scope of the invention.
By way of example, in another, although not the only other possible, embodiment of the method and the apparatus of the invention, the flue gas from the steam generator 27 is passed through a recuperator (not shown) and is cooled to a temperature, typically 80° C., before being transferred to the water separator 33. In addition, the dry flue gas is not split into two streams after the first stage in the multiple stage flue gas compressor train 17, as is the case in the embodiment shown in the figure. Rather, the whole of the dry flue gas from the water separator 33 is compressed in the compressor train 17 and then passed through the condenser 35. The liquid stream from the condenser 35 is then split into two streams, with one stream being supplied to the underground storage region and the other stream being passed through the recuperator and being converted into a gas phase via heat exchange with the flue gas stream from the steam generator 27. The reformed flue gas from the recuperator is then supplied to the combustor 5 via the mixer 9.
In addition, whilst the embodiment of the present invention described above with reference to the figure supplies flue gas, which is predominantly CO2 , in a liquid form to an underground coal bed seam, the present invention is not so limited and extends to supplying flue gas to any other suitable underground storage region.
In addition, whilst the embodiment of the present invention described above with reference to the figure supplies flue gas, which is predominantly CO2 , in a liquid form to an underground coal bed seam, the present invention is not so limited and extends to supplying flue gas in a gaseous form to a coal bed seam or any other suitable underground storage region.
| Number | Date | Country | Kind |
|---|---|---|---|
| 2006902956 | Jun 2006 | AU | national |
| 2006902990 | Jun 2006 | AU | national |
| Filing Document | Filing Date | Country | Kind | 371c Date |
|---|---|---|---|---|
| PCT/AU2007/000775 | 6/1/2007 | WO | 00 | 7/8/2009 |
