GB2579536A - A design for an efficient symbiotic electricity generation plant - Google Patents

Abstract

A power station fuelled by fossil fuels or biomass may have increased in efficiency and reduced in harmful emissions by adding secondary units to utilise waste gases and recover heat. Electrolysis may separate water into hydrogen and oxygen, with a calcium carbonate (CaCO3) slurry remaining. Renewable energy, such as solar energy, may power the electrolysis. The oxygen may be used to increase combustion efficiency in the power station’s main furnace. The hydrogen may react with the carbon dioxide (CO2) produced by the main furnace, in a Sabatier reaction, to make methane (CH4)​, to provide further fuel for burning. The calcium carbonate may be reacted with sulfur dioxide (SO2) to form calcium sulfate (CaSO4)​, which may be used for cement. The fuel is combusted with Oxygen to redues the production of nitrous oxide.

Description

Description:

Generalities and understanding: To try and describe every detail of complex energy and electrical generation system is difficult, this systems has options and modalities of operation which greatly help to give overall improved efficiencies of any combustion energy generation plant in use at the time of writing.

This system of generating electricity by oxygen fuel combustion in boilers to raise steam for steam turbines or gas turbines or reciprocating engines, where the rotational output power shafts rotate an electrical power generator (or combination of combustion units powering electrical generators) is fairly well developed, but there are inherent inefficiencies such plants leading to fuel energy values conversion to electrical energy values of 30% to 45% ,which in turn means carbon dioxide (CO2) emissions are unnecessarily created due to these inefficiencies.

The general principals and innovative steps used in this patent application combine to give greater electrical outputs per kg of fuel combusted than any power station in use. A simple description is that fuel is combusted with oxygen, negating the need to heat the 78% Nitrogen gas component of air present in traditional air drafting, and have to exhaust the nitrogen/nitrogen oxides gases and the heat that the exhaust gas carries. If you can heat the oxygen supply feed to the combustion using recovered heat you can reduce the fuel required further as you are inputting heat. Not all fuels can be pre heated, but both Hydrogen (112) and Methane (CH4) gases have high auto ignition temperatures, meaning they can be pre heated to high temperatures with recovered heat allowing for heat to be inputted replace combustion/fuel needed. Combining both pre heated oxygen and pre heated fuel and not heating the nitrogen gas constituent of traditional air drafting feeds, gives an immediate thermal and fuel used efficiency, noting also that exhaust volumes are reduced and the related heat/stack losses. This fuel reduction can only be estimated as differing combustion systems exist, but 15% to 25% fuel reduction compared to air drafting combustion seems possible.

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Another innovative step of this application (and previous related ones) is series combustion and conversion of CO2 to CH4 in a Sabatier reaction enabling CO2 emissions to be converted into a fuel. The Sabatier reaction is a gas mixing heating and pressure reaction considered to be 80% efficient in reactants and products, but theoretically quite energy efficient in operation as low heat exchange/heat loss reaction system.0O2 is a gas created from oxygen combining with carbon in a process such as combustion, however efficient combustion is not easy to achieve, and lower combustion temperatures using air drafting can give uncombusted and intermediate combustion products, that have to be extracted as ash or char. Series combustion units that connect the flue of the preceding combustion unit, allowing its combustion products to be introduced into the next combustion unit,to be oxygen combusted with fuel, is possible, enabling heat to be transferred that would normally be lost as exhaust to atmosphere (sometimes referred to as stack losses) and also offering the uncombusted and intermediate combustion products, to be heated and go through combustion again, a secondary oxygen combustion stage enabling more carbon to become CO2.

A further innovative step in this application (and previous related ones) is that CO2 is absorbed by water to produce carbonated water, also making use of the known properties of hydrogen and methane not being soluble in water enabling CO2 to be removed or partially removed to make a carbonated water. This carbonated water is slightly acidic and when Calcium Oxide (CAO) is added (a salt of Calcium) creates an ionic reaction/solution, which when used as an electrolyte in an electrolysis cell, improves ion transfer and improves the efficiency of the electrolysis cell in being able to electrolyse water to elemental hydrogen and oxygen gases at the separate electrodes. When calcium oxide is added to the carbonated water and electrolysed, the calcium oxide becomes calcium carbonate precipitate/solid (CaCO3) which will accumulate on one of the electrodes and will need to be removed from the electrode and electrolysis cell. Calcium carbonate as solid when removed from the electrolysis cell has two routes, the first being to dry it and return it to a Calcium oxide production

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process (a cement kiln for example) and it can be a renewable intermediate material in electrolysis of carbonated water, the second route also shown in this patent application is to use it as flue gas scrubber see drawings figure 3, where an initial combustion stage produces ash/char, , the slurry incorporating the particles and or have sulphur dioxide gas (S02) bubbled through the CaCO3 slurry where a chemical reaction takes place to form Calcium Sulphate (CaSO4) and CO2 gas is made.CaSO4 is a form of cement and a useful building product making for example flame resistant wall boards. There is physical property difference with CaSO4 made from CaCO3 from an electrolysis compared to using CaO from a high temperature cement kiln, in that the CaO from the cement kiln is composed of sintered particles which under the microscope have jagged exteriors, CaCO3 formed in the electrolysis cell has particles which under the microscope appear more rounded and pebble like, this physical difference in particles suggests that CaCO3 formed in the electrolysis cell may not suite some building applications when converted in CaSO4, where the sintered particle enables better binding with some aggregates such as sand.

This patent application sees use in addition of Ca0 to an electrolyte of carbonated water, to aid the electrolysis efficiency and produce a useful building material, however it may be that a user of this design, does not wish to use CaO as electrolyte additive to make CaCO3 (not shown in main drawings) and run the electrolysis cells in a different way. A different salt could be added that makes another use of the carbonated water electrolyte in a different way or the carbonated water produced by the cooling process of component D could be diverted to a different treatment process to precipitate out the CO2 as chemical substance and the electrolysis cells run with a plain non-carbonated, low mineral content water electrolyte. It is felt that running an electrolysis cell with a high carbonated water electrolyte without the addition of Ca0 or suitable similar salt, would cause damage to the electrodes of the electrolysis cell and have detrimental economic efficiencies to the running of efficient electrolysis cells, but they can be run this way if required.

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Water electrolysis, where the water is not saline or of high mineral content or is carbonated can be done and this patent application clarifies this for situations where a hydrogen (and/or oxygen) collection system is required from remote water electrolysis units to supply to the power station oxygen combustion and/or the hydrogen for the Sabatier reaction ( see drawings figure 12). These units do not operate with calcium oxide or other salt added,they are less efficient but where a renewable source of electricity is used to energise the electrolysis cell and water is available to be electrolysed,then such units could supply regular feeds of hydrogen and/or oxygen. A further option for the remote electrolysis units, is for the hydrogen to be piped to the power station/Sabatier reaction and for the oxygen to be bubbled (preferably at depth) into a body of water or ocean. Oxygenating water bodies could be useful in increasing their ability to produce food and deal with some pollutants. A further option (shown in modifications and variations drawings figure 12 ii)) would allow for CO2 to be piped to hydrogen collection stations and the Sabatier reaction and make CH4 conducted at separate sites, if an energy source is available for the process.

A further innovative step of this application (and ones related to it) is the use of temperature and pressure differentials of the process, after exiting the final combustion unit, the flue products flow enters component C which is a heat recovery section (see drawings figure 5). As series connected combustion units are used, the flue products flow continuously and are not put to atmosphere as exhaust. The post combustion flue products flow into component C could contain mostly CO2 and water vapour H2O, the water vapour carrying considerable heat energy enabling a very powerful heat recovery section, which can then and/or power a further steam boiler to power steam turbines and electrical generators, or air/turbine or gas turbine to power electrical generators or reciprocating engine to power electrical generators, or be used to pre heat oxygen and fuels prior to combustion uses in components A or B. It is possible the post combustion flue products entering into component C could be at high pressures giving a flow of velocity, which in its self could power simple turbines utilising the

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pressure and velocity of the flow to give a rotational output shaft,to power electrical generators, however component C is connected to the cooling component D, as the post combustion flue products flow through the component D,they reach a temperature in the DI section (see drawings figure 6) of less than 10oC. Given the large volume of hot gases and water vapour entering into component C and the connection to the low 10oC or less,and low volume of the gases and water vapour in component D, DI section,there is a considerable temperature/pressure gradient which can be taken of advantage of in providing possible quite high velocities of moving,post combustion flue product flows in component C sufficient to power simple flow integral turbines (single rotor similar to wind turbine),with a single rotor and mechanical power linkage to the outside of the flue products containment wall (not affecting the containment integrity),to power an electrical generator,and/or more complex turbines of multiple rotors on a single rotational power transfer shaft that passes through the flue products containment wall (not affecting the containment integrity) to power electrical generators,or possibly something similar to steam turbine or gas turbine arrangement,with a rotational output shaft powering a generator or multiplicity thereof. Current electricity design power stations do not make use of this as they have no requirement to attach a post combustion flue products flow to a cooling system that could make remove water vapour and be connected to a Sabatier reaction to process the cooled remaining CO2, into CH4.lt can be shown therefore that the electricity generation power station, from the series combustion of fuels with oxygen and the cooling of the post combustion products, has the facility to power additional electrical generators, not available on current designs and give a greater electrical output per Kg of fuel combusted,than current designs.

Description as process flow:

1) Fuels for the primary combustion component A (or multiplicities of component A) ideally is biomass or, Bio solids however any combustable fuel (and where allowed pre heated from recovered heat) can be used,

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depending upon what is required, the fuel is combusted stiochmetrically (with the required amount of pre heated oxygen gas and not traditional air drafting) thought to be more efficient where the combustion is used to heats boilers, to raise steam to power steam turbines to power electrical generators. If gas turbines are used in component A then solid fuels (or fuels with solids) cannot be used as turbines work on gas expansion from combustion, to give pressure onto shaped turbine blades causing rotation, and heat is often although not always recovered Sas turbines have advantages in speed of bringing into operation and closing down and can be less complex and less costly than boilers and steam turbines in combusting gases and liquids. Reciprocating engines as component A require a liquid or gaseous fuel, and both gas turbines and reciprocating engines with oxygen combustion will give an exhaust mostly composed of CO2 and H2O,with little ash or char.

2) The post combustion products of component A are contained within a flue or pipe (as flow Gl) that transfer them to the secondary combustion section of component B, where a fuel and pre heated oxygen (preferred as pre heated methane but could also be other fuels or pre heated fuels) are combusted stiochmetrically and not using air drafting, creating heat used to heat boilers, to raise steam to power steam turbines to power electrical generators. If gas turbines are used to power electrical generators in component B then solid fuels (or fuels with solids) cannot be used. Reciprocating engines used to power electrical generators in component B require a liquid or gaseous fuel, and both gas turbines and reciprocating engines with oxygen combustion will give an exhaust mostly composed of CO2 and H2O,with little ash or char.

3) The post combustion products of component B (or multiples of B in series or parallel arrangements) are contained within a flue or pipe (as flow G2) and transferred to component C (or multiples of component C in series or parallel arrangements),which is a main heat recovery section and additional electrical power generation. The series combustion,transferring combustion products to the next combustion section enables,heat normally lost to exhaust to be transferred and allow for lower fuel use, if there are multiple stages of connected combustion

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then post the final stage, considerable quantities of gases and water vapour could be present,the water vapour in particular could be carrying a great deal of heat as water has a high enthalpy value, and removing some of this heat in a heat exchanger, aids the subsequent performance of the cooling section component D. The heat exchanger (or multiple heat exchangers) should take heat from the flue products flow passing through component C, the heat can be used to pre heat fuels and/or oxygen used in the combustion components A and B, and/or provide a source of heat to a boiler to raise steam to power a steam turbine to power an electrical generator (or multiples thereof) , or could heat air/gas to power a turbine (similar to gas turbine) to power an electrical generator (or multiples thereof) . The flue products flow of component C could be under pressure within component C at temperatures of over 100oC,the connection to the cooling section component D is a gradient of pressure, component D causing gas and vapour reduction in volume compared to those entering component C.This pressure gradient can be utilised,in that a continuous velocity is created, which can be engineered to give suitable pressures to power simple single rotor turbines or multiple rotor turbines (more resembling a steam or gas turbine rotor arrangement) , that have rotational power output shafts to the external of the flue containment (without degrading the flue containment functions) that can rotate/power the shaft of electrical generator (or multiples thereof).

4) The flue products flow from component C then enters component D (as flow G3 see drawings figure 6) is the cooled post combustion products flow (from component B or component A if B is absent) and should be composed of mostly CO2 and H20.Component D should be powered by renewable energy sources where possible, but can use energy made on site. It is understood that some sections of component D can be reduced or increased or removed as per operational requirements, e.g. a plant design that only requires water cooling rather than gas cooling sections.

The purpose of component D (or multiples thereof) is to not only cool the post combustion flue products flow but to heat gases used as coolants, to either temperatures suitable for supplying the gas grid network or for the

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higher temperatures of pre heating fuel and/or oxygen to feed components A or B, it is both a cooling system and heat recovery system. Component D has two cycles of cooling which could be made to operate continuously (or separately for better process management, if stores are incorporated, not shown in drawings). The first cycle takes the output flow from component C and has two stages of gas cooling in DG1 and DG2, then a stage of water cooling DW and then introduction to an water ice column section, DI where water ice either crushed, flaked or cube ice is introduced into the top of the vessel (in a way that does not affect the containment of the flow within the vessel), where the water vapour should condense out to be removed from the vessel (as flow W02) and can be used as a coolant (as flow WI, in the DW water cooling unit) before being fed to the water electrolysis bank, or other process or treatment. The DICO flow of the DI section is a controllable cool CO2 gas flow, enabling CO2 to be drawn off where balances of CO2 are required to be removed as it cannot be processed in the Sabatier process, for example because hydrogen is limited or the Sabatier process is unavailable. This CO2 from the DICO flow of the DI unit can be itself cryogenically treated (separate unit not shown in drawings), to produce solid CO2, or stored or released to atmosphere, it could be a regular operation or one only used in emergency situations.

This should then leave a flow of cooled CO2 gas. The CO2 gas is then mixed with hydrogen in Sabatier reaction vessel SAB at a ratio of 1 volume of CO2 to 4 volumes of hydrogen (and or mixing volumes as required) and taken up to temperature and pressure thought to be around 300-400oC and SOpsi 345 kilopascals (or whatever temperature and pressure combination is required) , forming Methane in the following chemical formulae CO2+4H2-------->CH4 +2H20, and also water as vapour. Post the Sabatier reaction pressure should be maintained to below 200oC (or what temperature/pressure combination is required to stop the reaction of CH4 reforming back to CO2) whilst cooling the flow. This could be achieved using a heat exchanger device where outgoing products post Sabatier reaction, heat incoming CO2 and hydrogen gases,helping to give thermal efficiencies.Heat energy may be required in the Sabatier reaction, a renewable source of energy is useful for this as is a renewable source providing energy for

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component D. The second cycle is to process the post Sabatier products of gaseous CH4 and unreacted CO2 and H2 and water vapour, which again passes through two gas cooling stages DGPS1 and DGPS2 and a water cooling unit DWPS2 and a final direct contact with water ice in DIPS2 where water ice either crushed, flaked or cube ice is introduced into the top of the vessel,in a way that does not affect the containment of the flow within the vessel, (the outflow of which WO2PS can be used as water coolant inflow WIPS for section DWPS2) which may be capable of removing all of the CO2 by absorbing the CO2 into the water/ice, before flowing on to the Cryogenic freezing /cooling unit CRYO,any remaining CO2 should be removed first from the post DIPS2 flow, leaving only H2 and CH4 gases to be reduced to very low temperatures (or process temperatures and method as required) to liquefy the CH4 gas, which is thought to be around -160oC. This temperature whilst very low is not sufficient to cause H2 gas to liquefy which should remain as gas. Other methods of lowering pressure are used in creating liquefied CH4 and if suitable these may be used, molecular filters can be used to remove CO2 and separate mixed gas streams if this is suitable for the process. The products from the CRY() section of liquefied CH4 (and or solid/liquid CO2) then going to store, the cooled H2 gas can be used as electrical generator coolant, and or can be returned to be used as the H2 feed for the Sabatier reaction, enabling some economy in H2 usage. The heat extracted from the CRYO section process may be substantial and can be used as recovered heat to pre heat oxygen or fuels in the combustion components A or B or elsewhere.

Liquefied CH4 gas from the store (or Natural gas or Methane or Bio gas from external sources) can be used in combustion components A and B and pre heated by becoming coolant feeds in the gas cooling heat exchanger sections of component D.The liquefied CH4 can be used from store as it is, to fuel for example transport vehicles, or if requiring to return the liquefied CH4 gas to input in gas grid network, can again be used as a coolant feed in the gas cooling heat exchanger sections of component D. This concludes the description of the basic and innovative steps of the patent application; further description follows to explain the important modalities of

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operation and the larger energy system making use of the innovative steps defined in the application are in the expanded modifications and variations.

Modality and system features description

An alternative, external source of CO2 (and/or other heat source of substances that are not harmful to the processes and equipment of the system) can be introduced (see drawings figure 8 i) and ii)) e.g. the exhaust from a cement kiln or rotary kiln. This can be introduced at any point prior to the flow from component B to C (combustion to heat recovery) , the drawings suggesting, it is introduced between component A and component B and or B to C,the effects would be different,if introducing between component A to B (or pre to A combustion) if a hot source of CO2 this may act to reduce the fuel requiring to be combusted in B components, if introducing the external source of CO2 from B to C, it would enable greater heat recovery,however in both examples the CO2 in the system may be increased and therefore CH4 outputs from the cooling and cryogenic separation component D, as well as other parameters changing. This external CO2 source should be consistent as it will affect the running of the system and ideally be hot or heated, as a cool or cold source of CO2 will cause more fuel to be combusted in the system to gain temperatures, cold or cool external CO2 feed could however work in a gas turbine arrangement where gaseous expansion plays a greater role in determining power outputs.

The pre heating of fuel and oxygen feeds is envisaged to utilise as much recovered heat as possible, from combustion/heat recovery sections, coolant sections, water ice making and cryogenic sections. It is expected that 200oC is a reasonable temperature to pre heat fuels and oxygen to and gives good thermal efficiency; however 400oC and higher where safe to do gives improved thermal efficiency. A modality could be that some combustion processes have fuel and/or oxygen heated to different temperatures e.g. higher temperatures for a biomass or tyre crumb combustion section oxygen/and or gas fuel feed to assist combustion.

Modality and system features description continued: Where water supplies may be a problem fuels such as alcohol offer a great production of water from combustion, and oxygen combustion does offer the opportunity to use free water/higher moisture content fuels such as bio solids,at the time of writing it is unknown what the maximum free moisture content,of fuels could be considered, and is thought to be around 30%, the free water being of use in thermal performance of the series combustion A and B components and component C heat recovery sections due to its enthalpy value, as well as providing water for the electrolysis bank and/or for steam circuits use. It is possible that in some modes of operation that an excess of water could be produced, giving this system the potential to provide a source of water for example to use in irrigation or agriculture, some configurations may require that water may have to be drawn /consumed rather than in the balances from combustion derived water. The high temperatures of oxygen combustion and co firing of fuels stiochmetrically (with Oxygen) bringing into range of use previously difficult combustion fuels that gave emission problems due to low temperature combustion, and may offer a route for number of previously more difficult fuels to combust such as tyre crumb or powder.

The water electrolysis bank F, splits the water molecule into its component elemental gases of Hydrogen and Oxygen (which if in excess can be diverted for other uses/processes shown in drawings figure 8), electrolysis cell efficiency can be improved by adding a salt to the electrolyte, as water can absorb CO2, this can be used, by adding to this CO2 saturated water, Calcium oxide which in the electrolysis cell creates Calcium Carbonate as a solid deposited on one of the electrodes, which can be removed from the electrolysis cell as a solid, and further processed as slurry through which SO2 (and/or other products/substances) can be bubbled through to create CaSO4 or Calcium Sulphate solids which is form of cement and used in the building industry. The outputs of this material may not be high, but may well offer a small economic benefit in making a by-product that can be used. If the water electrolysis bank F does not want to use a salt in electrolysis, it can still operate, so the use of CaO is a choice to make use of the CO2 saturated water and a small improvement in water electrolysis cell Modality and system features description continued: efficiency, and ability to run in the absence of CaO. It is however preferred to operate the electrolysis cell using a suitable salt and Ca0 is a good and plentiful choice to improve the electrolysis cell efficiency and remove carbonates from the electrolyte undergoing electrolysis, to give some renewal of the electrolyte by incoming fresh electrolyte with a salt preferred as CaO. The system in this patent application (and others related to it) offers modality and flexibility of operation and design possibility to give further fuel efficiencies, variations in electrical output and production of CH4 from the Sabatier reaction which may help with demand patterns and seasonal variations which in the UK are quite marked, mid-winter using double the amount of electricity than in mid-summer, so in a UK summer a system of these energy plants can be run to lower electrical outputs and burning of fuel or some shut down completely, in a UK winter the plants can be run to full electrical output and fuel use, which nuclear and conventional combustion technology designed plants are unable to do.

By being able to remove CO2 as a gas (see drawings figure 6 DICO flow) enables, CO2 to be balanced, should hydrogen for the Sabatier reaction be unavailable or other problem/requirement of the process. As the CO2 being processed in a large electrical power generation plant could be considerable, it is thought that tempory storage would quickly become impractical and release to atmosphere may be the only option. A further modality is to use the flow G4CF (see drawings figure 6) and use the mixed gas stream with the water condensed out, as a gas coolant and then and/or as a fuel/co firing the combustion sections components A and B. This would save energy on removing the CO2 gas and subsequent cryogenic cooling to make liquid methane and super cool hydrogen gas, and gives further flexibility of the energy plant as a whole unit.

Modifications and variations: 1) Additional component B secondary combustion sections can be added in series or in parallel to increase electrical outputs and optimise the efficiency of secondary combustion and hot oxygen and Methane feeds to the combustion, creating a high efficiency, high electrical output system. Secondary combustion units may also allow for particles from component A that were incompletely combusted to be combusted again more completely,in some cases removing the need for any pre component B ash or char separation. Making this patent application a low ash/char combustion system.

2) The making of CaCO3 in the water electrolysis cells/bank is an option and need not be done, removing the energy requirement of making the CaO, however it is felt that electrolysing carbonated water without a salt may damage one or more cell electrodes. It is also possible that carbonated water produced by component D be treated in different way, and that water for the water electrolysis units be from a source that is not carbonated, and CaO need not be used/added to the electrolyte of non-carbonated water.

3) Turbines utilising the pressure and velocity of post combustion product flows can be utilised to power electricity generators to give additional electrical power outputs at other points in the system other than in component C, for example in post combustion flows between component A or B. 4) Gas turbines or reciprocating engines powering electricity generators can be used in place of boilers powering steam turbines that power electrical generators in components A or B; however it is felt that boilers, raising steam to power steam turbines to power electrical generators, will offer greater efficiencies, in continuous operation.

5) Alcohol or other fuel can be used in the secondary combustion component B; however it is felt that Methane will offer a better efficiency as Methane is also being made in the Sabatier process and this can be returned to be used as fuel.

6) Secondary combustion component B can be removed to have a simplified single combustion system and connected flue products flow, component A, and then to heat recovery component C and Modifications and variations continued: then to component D containing the Sabatier process and cryogenic separation.

7) By using multiple, component A and B combustion sections and components C and D, some flexibility can be designed into operation of the plant as a whole, to enable larger or reduced electrical power generation outputs to be controlled. These plants are designed to run at high outputs for long time periods, as they are series combustion and cooling systems,they cannot be turned off and on in short time periods (unless designed as small fuel input/small electrical output systems) ,by arranging the combustion components A and B to come in and out of use,e.g. from component A the flow 61 is split into flows to feed units of component B,similar to a manifold, flow G1 being sent to e.g. four component B units when high electrical loads are required, and flow 61 being sent to only 2 component B units when low electrical outputs are needed, enabling the plant to have some adjustments to what may be seasonal variations of electricity demand e.g. more electrical lighting being on during months of less sunlight. Suggested combinations of components A, B, C and D are difficult to define as they are details of engineering,however having two component A units feeding separate component B units as separate lines enables one line to be operational in low electrical demand and both lines in operation when electrical demand is higher. Placing component A and sequential series component B units will be limited by the engineered design as the outflow of post combustion products from the final component B, could be considerable in the order of 10s of thousands M3 per hour and subsequent heat recovery component C and cooling component D have to be designed to process the final combustion products stream, and it may be that the post combustion B component,flue products streams, require multiple component C and component D lines, this patent application is unable to show these possibilities of engineering requirement and constraint, but conveys that arrangements of the components A,B,C and D can be used to meet requirements of low Modifications and variations continued: or high electricity generation and/or some adjustment for the production of CH4 to liquid and store.

8) By having sections for post combustion product flows in section C, heat recovery sections/turbine electricity generators can be closed or opened to match, post combustion product flows, giving system flexibility.

9) The use of gas cooling heat exchangers, in component D to cool post combustion product flows, heats the gases used for cooling and can work as heat recovery to pre heat gaseous fuel or Oxygen, expanding these gases. The pressure of these cooling gas flows (or of the pre heated fuel gases or oxygen flows from component C) could be used to power smaller turbines that may generate electricity or turbines with mechanical outputs or have another use such as powering pumping water (not shown in drawings).

10) Hot Methane and Oxygen feeds to combustion units can increase thermal efficiency and reduce fuel use compared to systems that do not pre heat fuel or oxygen, by introducing heat into the combustion components. As air drafting is not used it is possible to pressurise some combustion sections which would require injecting pre heated fuels and pre heated oxygen, which may be possible in combustion components A and B in component B that is also receiving a post combustion flow of component A (flow G1), this post combustion flow of component A would also have to be pressurised and introduced into the combustion chamber, systems where a gaseous or liquid fuel is used, it is relatively straight forward to design as engineering.

11) An additional source of CO2 (see drawings figure 8) from an external source such as the exhaust from a cement making kiln or rotary kiln,can be introduced to the post A combustion unit flow or post B combustion unit flow, (or pre A combustion feeds not shown in drawings figure 8) .The CO2 enabling potential CH4 production to increase from the Sabatier process and add some thermal efficiency/input to boilers (of component A or B) to raise steam or to recover heat (in component C) and assist in controlling oxygen Modifications and variations continued: combustion temperatures where said fuels used may generate very high temperatures when combusted such as alcohol or CH4.This would also enable CO2 to be reduced emissions from the cement plant,by converting them to CH4 noting that cement production emissions are thought to account for nearly 10% of all global CO2 emissions.

12) That this device is primarily for large electrical output generation and making CH4 as an energy source/fuel to use and store, but could be of a size as to power ships efficiently and if safe could power smaller uses such as road transport or stationary engines. Rotational power output shafts that would power electrical generators in the patent application could be used to power mechanical drives, such as rope, chain, belt,pulley or hydraulic to rotate machines or gearbox inputs or propulsion devices such as a ships propeller or railway locomotive wheel.

13) That a reciprocating engine or rotary wankel engine such as an internal combustion piston/rotor engine (or multiplicity thereof) could be substituted instead of a combustion unit or boiler its best location being component A of drawings figure 1.Using oxygen/fuel combustion could enable a piston reciprocating,or rotary wankel engine to be used as a secondary combustion unit,however there may be some difficulties in this and such secondary sequential piston reciprocating,or rotary wankel engines would require to make combustion in a mixed (post combustion products) gaseous flow as cylinder inlet. Sizing of the engines would increase with each sequential combustion unit and it is felt that such a system could not produce the high electrical outputs of a boiler to raise steam, to drive steam turbines, to power electrical generators.

14) The gas turbine as single stage gas turbine or two stage gas turbine does offer some use in the system of this patent application, as it use oxygen /fuel combustion, however generally speaking gas turbines run efficiently and safely, on gaseous or liquid fuels and if a gas turbine is used as component A combustion unit,the heat/post combustion flow,being transferred would become the intake of the Modifications and variations continued: next gas turbine, such gas turbines usually preferring cool air/gases as intake as they are more dense when compressed, which poses a few problems at the intake design aspect of gas turbines being used as a secondary combustion system, there is also the problem of hard particulates of ash/char of incomplete combustion, or other substances from a post combustion unit damaging turbine blades, causing mechanical failure or impairment. The actual combustion within the single stage or two stage gas turbine is not a problem, pre heated fuel and oxygen combusted at high pressure could certainly, power the gas turbine very well, but gas turbines as used in most applications including aircraft propulsion, can develop high temperature exit flows or thrust, which could be difficult to transfer to a subsequent intake of a sequential combustion unit, giving difficult heat loads. It may be possible to arrange gas turbines in a semi-circle (as component A) and collect there exhausts to heat a boiler/heat exchanger (as component B) to raise steam to power steam turbines to power electrical generators (see drawings figure 11).

15) That excess oxygen and/or hydrogen from the water electrolysis can be diverted and used for other processes if appropriate.

16) Internal flue/pipe restriction devices (e.g. a mechanical iris) to restrict post combustion flows and other flows in A, B, C and D (not shown in drawings) may help to manage pressures and velocities of materials to enable plant operational efficiencies.

17) The system of combustion of oxygen/fuel and use of the Sabatier reaction to convert CO2 to CH4, is designed to not emit/or emit low amounts of CO2 (and also Nitrogen oxides as air drafting is not used).To achieve this hydrogen and oxygen gases need to be in plentiful supply when the combustion and Sabatier reactions are in operation. 1kg of water electrolysed should create 800g of oxygen and 200g of hydrogen and current data suggests 44kw of electricity would be required in current design electrolysis cells. In certain sizes of electrical output and if burning a high carbon content fuel this may Modifications and variations continued: create imbalances in the hydrogen and oxygen use rates, and in this application (drawings figure 1) it is suggested that a device SSO for separating oxygen from air is used as an oxygen supply/store, and a hydrogen store SSH that can accept external hydrogen supplies (whether from electrolysis or another process) to supplement whatever oxygen and hydrogen supplies are being gained from on site or remote water electrolysis product sites. If possible the products in 550 and SSH stores should be powered by renewable electricity. Where oxygen and hydrogen gases are difficult to produce and/or balance, this patent application explains,that CO2 could be released from the cooling component D from the DI section (see drawings figure 6) using the DICO outflow thereby reducing the amount of CO2 processed through the Sabatier reaction to make CH4. This cooled gas, mostly CO2, can go onto further cryogenic processing to make solid CO2 (or liquid is possible), which could have uses for cooling processes or use in market garden greenhouses in the growing season to provide/enrich the CO2 atmosphere to increase photosynthesis, or other use, or be released to atmosphere on site as a gas via an exhaust.

18) From modification and variation item 17, it is also possible that a system of cooling, cryogenic freezing could be used that does not use a Sabatier reaction, but makes solid CO2 (liquid CO2 is also possible) from the flow in component D, post DI section (see drawings figure 14) a cryogenic section becoming the final stage after the DI section, and the Sabatier and subsequent cooling processes removed. The quantities of solid CO2 produced could be considerable and would need a use and transport. Not requiring a Sabatier reaction means that hydrogen is not required, thereby the system described in this patent application, would be oxygen series combustion, with oxygen separated from air or remote electrolysis sites/other sources (see drawings figure 1 unit SSO and drawings figure 15i), as no CH4 is being synthesised on site, all fuel Z feeds of combustion components A and B would be fed from external sources and not utilise the methane synthesised on site. It is assumed that heat recovered would Modifications and variations continued: still be used to pre heat oxygen and gaseous fuels to gain the combustion efficiencies and efficiencies of a series combustion system with pre heated fuels and oxygen. An air drafted system of the design using the efficiencies of series combustion in this application is possible, but control over combustion would be lost, which is important in difficult fuels to combust such as tyre waste, as well as the major combustion efficiency of not heating the none oxygen constituents of air, it would also be as polluting as current power station designs in use at the time of writing.

19) Remote water electrolysis sites using renewable electricity (or supplied with excess electricity when available) need not supply oxygen via pipe to the combustion/electricity generation plant (see drawings figure 12 i)) and could instead send the oxygen gas to be bubbled into a river or body of water such as an ocean (preferably at depth), the oxygenated water being able to sustain more life than low oxygen content water and help to deal with some organic pollutants. Hydrogen could be piped to the combustion/electricity generation plant, also saving on the pipe network cost required.

20) Remote water electrolysis sites using renewable electricity (or supplied with excess electricity when available) need not supply oxygen via pipe to the combustion/electricity generation plant (see drawings figure 12 ii)) but could be fed by CO2 piped in from a CO2 production site e.g. combustion power station, being combined with H2 gas produced by the water electrolysis unit,in a Sabatier reaction,powered by the remote site renewable electricity (or supplied with excess electricity when available), the CH4,H2 and CO2 going through a simplified cooling device to be further processed, to make liquefied CH4 or to be processed for release to the gas grid.

21) Drawings figure 6 show units or stages of an efficient cooling system to help with the thermal energy balances and losses in processing post combustion product flows, potentially of considerable volume and heat content, water can be recovered, some CO2 absorbed into water to make carbonated water which can be used as an electrolyte in the water electrolysis process and can Modifications and variations continued: also enable post Sabatier process gases to be separated to produce a cooled flow for Cryogenic liquefication of CH4 gas. These units can be rearranged, removed or repeated/additional to give a different performance dependent upon the engineering required. The basic function of the patent application (and previous relevant applications) process and products keeping integrity, these being cooling of the post combustion product flows to condense and extract water vapour produced in combustion, to remove any ash and char and provide a concentrated flow of CO2 for use in the Sabatier reaction, to cool the post Sabatier reaction products to condense and extract water vapour, and remove any or all unreacted CO2 in the post Sabatier product flow and then process the CH4 and unreacted H2 via a process that creates liquefied CH4 and H2 as a gas suggested in the patent application as cryogenic freezing system labelled as CRYO (noting some systems lower temperatures to liquefy gases with a series of pressure changes or powerful magnets,which this application could also use).

22) The drying of gases may be required in some flows (not shown in drawings).

23) There is speculation in energy thinking of taking CO2 gas produced from fuel combustion power stations and pumping it into underground rock strata or spent natural gas wells. This design in the patent application can produce large quantities of CO2 gas, however there are problems with the procedure of underground sequestration of CO2 in that eventually the rock strata or spent gas well will become full, and that all small experimental systems pumping CO2 to rock strata store have underestimated the energy required to pump at pressure and typically 15% more fuel has to be burnt to do this, and it is not a variation the patent application inventor thinks is/or can be suitable.

24) A post Sabatier products flow (as in drawings figure 6 flow G4CF) consisting of cooled gases CO2,CH4 and H2 can be used as fuel/co firing in the combustion sections components A and B. Advantages of the invention: 1) High amounts of electrical energy production are possible as well as improved Kw of electrical energy per Kg of fuel as additional sources of electrical generation are possible.

2) Carbon dioxide from combustion can be converted into Methane via the Sabatier process, creating a low or zero CO2 emission fuel combustion electrical energy generation system.

3) Current thermal and energy efficiency of current technology combustion electricity production power plants can be greatly improved, as thermal energy losses of traditional power station designs, can be recovered and used to pre heat fuels and oxygen efficiently, to be reintroduced as heat directly into the combustion units enabling fuel use to be reduced.

4) Biomass fuels can be combusted in these plants as well as fuels previous unused that only combust cleanly in the high combustion temperatures of oxygen fuel combustion, such as tyre waste or oil sludge's.

5) The higher energy efficiency means less fuel needs to be combusted enabling limited resource fuels such as Biomass fuels and recycled fuels to be more widely used.

6) By using the post combustion products flow from the primary combustion component A to heat a secondary combustion component B, large amounts of heat energy can be transferred/used to reduce the fuel consumption of the secondary combustion component B or multiples thereof.

7) By direct transfer of post combustion products flow from the primary combustion component A, to a secondary combustion unit B (or multiples thereof) if combusting a solid fuel or problem fuel that creates ash and char and/or incomplete combustion particulates, secondary combustion can combust these particulates further to create a low or zero ash/char combustion system and a final post all combustion units flow, mostly composed of CO2 and water vapour. The flame temperature of an oxygen and methane combustion unit could be 2000oC or higher, giving very high combustion temperatures.

8) Dissolved CO2 in water from the process used by the water electrolysis bank can be made into CaCO3, by adding Ca0 to make a salt electrolyte that can improve electrolysis cell efficiency. Further processing of the Advantages of the invention continued: CaCO3 by bubbling sulphur dioxide through the CaCO3 slurry can produce a building material form of cement Ca504.

9) Methane gas can be synthesised from CO2 making electricity power generation by combustion of biomass /bio solids/waste rubber latex fuels with oxygen,low or zero CO2, and providing methane source not from fossil fuel production systems directly.

10) Using biomass fuels can help to reduce the atmospheric CO2 by utilising plant photosynthesis to use atmospheric CO2 and store Carbon as plant sugars and structures and release 02.

11) Oxygen combustion offers more efficiency than using air to supply the oxygen for combustion as the other components of air do not have to be heated nitrogen gas comprising 78% of air, and this reduces Nitrogen oxide emissions.

12) Oxygen combustion means higher combustion temperatures can be attained, bringing previously difficult fuels into use such as low grade biomass of paper and cardboard, tyre crumb and can use higher moisture fuels.The higher temperatures also help with emissions from the combustion of oils and fats and other complex combustion substances/molecules.

13) Hot Methane and Oxygen feeds to combustion centres can increase thermal efficiency and reduce fuel use compared to systems that do not pre heat fuel or oxygen and/or use current/traditional design air drafting.

14) In remote satellite water electrolysis units or where stores have an excess of Oxygen gas, the excess of Oxygen gas can be used to oxygenate rivers or oceans by supplying via a pipe, a bubble dispersion unit and Increase river and marine life and deal with problem organic pollution compounds present in the water, or the excess oxygen could be collected and used to power more efficient internal combustion engines or small boilers or some other use.

15) External CO2 and CO2/water vapour sources from other processes can be used to help with the thermal and fuel efficiencies of the design as well as increase CH4 outputs e.g. the exhaust from a cement kiln or rotary cement kiln.

Advantages of the invention continued: Excess Oxygen and Hydrogen from the electrolysis bank/system (and/or other parts of the system) can be diverted from the system flows to be used in external processes or equipment.

16) Early calculations suggest 10000kg per hour of biomass at heating value of 16000 KJ/KG could generate 600MW per hour of electrical energy where the CO2 is converted into CH4 and combusted in a series combustion system as described in this patent application, more than double current combustion power station outputs.

17) Though designed as a power station to make CH4 and electrical energy, by replacing reciprocating engine, steam and gas turbine shaft outputs with mechanical drives such as chain, pulley or rope, mechanical outputs such as a ships propeller, can also take advantage of this system of improved combustion efficiency.

18) As a device smaller than a large power station this patent application design could make a fuel efficient type of engine for some transport or other functions requiring mechanical power such as milling of foods or rock crushing sorting.

19) In certain configurations of modality e.g. using a high moisture content fuel such as bio solids, it is possible that the system produces an excess of water, which may be used to irrigate agriculture or if processed as potable water.

20) There is a large temperature gradient between the final post combustion stage flue products flow and the cooling component section DI (see drawings figure 6) and the further cryogenic cooling section which produces liquefied CH4 (thought to be at -160oC) .As the post combustion products flow is continuously cooled it reduces in volume,creating a pressure difference and velocity, which can be used to power simple or complex turbines with a rotational power output shaft to rotate a generator to make additional electrical power.

21) (In drawings figure 1 key S1 and S2 flows) steam drum blow down or steam releases of the system are introduced to the post combustion products flow, this enables the heat losses of steam release to be used to assist the thermal efficiency of the combustion sections and also assist with water recovery.

Title: A design for an efficient symbiotic electricity power generation plant with improved modality and flexibility.

By John Jackson date February/ 20 /2018 (filing in March 2018) Background: A design for a electricity power generation plant was filed in June 2016, this utilised oxygen combustion of a fuel to produce steam to power turbines, to generate electricity, CO2 from the combustion was converted into CH4 (Methane) in a Sabatier process.The Hydrogen and Oxygen required was generated from onsite, or piped in from remote electrolysis of H2O (water), using either a renewable electrical power source, or electrical power generated from the power station. Some CO2 would be dissolved into H2O in the cooling process making a carbonated water which could be used as the water electrolysis electrolyte, facilitating a useful process of making CaCO3 (Calcium Carbonate) in the electrolysis cell when energised, by addition of CaO (Calcium Oxide) to the water, before/during use, in the electrolysis process, the CaCo3 could be further converted into a form of cement CaSO4, reducing emissions from cement production and giving a further economic ability. This design in this patent application (and others related to it) is a low or even zero CO2 emission power generation plant, primarily for the burning/combustion of Bio mass /Bio fuels/CH4, but fossil fuels could be used also. The design can produced CH4 via the Sabatier process for further use in combustion units of the power station enabling CO2 from combustion of a fuel, to be converted into a fuel via a chemical reaction in the Sabatier reaction,but with a Hydrogen supply made from water as the electrolyte, using electrolysis, energised using electricity, which can be supplied by a renewable electricity generation supply, thereby enabling a low or variable renewable electrical output system, to make, a fuel for a high output and managed electrical generation system to supply an electrical grid.CH4 can be made for distribution to the Gas grid as well as electricity to the electrical grid by electricity generation from boilers steam turbines and generators or gas turbines and generators,. This design became patent application GB1613728.3 and has gone through the search process The design noted that these power stations could be arranged in a symbiotic way to gain further efficiencies.Patent application GB1613728.3 as improved design, became GB1714707.5 which is going through the search process. This application has much of the technical and design script and

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drawing of GB1714707.5 and GB1801061.1 s as well as some better description but gives some useful further efficiencies both thermally and in electrical power outputs and in CH4 outputs, which this patent application would like to apply for,using the same basis of symbiotic and series combustion as GB1613728.3,but more refined in design thinking from engineering and modality and with an explanation of the efficiency possible for difficult fuels if arranged in a symbiotic arrangement using series connected combustion units,placing the components to improve methane production, and to explain the modality better than was envisaged when filing the initial design (unpublished) that led to the patent application GB1613728.3 and GB1714707.5.Since filing GB1613728.3 I have filed a patent for an electrolysis device which I hope will improve Hydrogen and Oxygen production from the splitting of the water molecule, as in application GB1613728.3 I was conscious that water electrolysis has a number of competing of designs,so referring to it as an electrolysis bank,was a less complicated way of trying to describe the various competing water electrolysis systems, and in this application as in GB1613728.3, GB1714707.5 and GB1801061.1 reference is "electrolysis bank" meaning a device that can split and separate the water molecule, into its component elements of Oxygen and Hydrogen gases by passing an electrical current between electrodes through the electrolyte (water).The best electrolysis cell for water electrolysis, has so far achieved a 60% efficiency of electrical input into creating elemental Hydrogen and Oxygen gases,small gains are important and adding a salt can improve electrolysis cell efficiency,in this example Calcium Oxide can be used and/or other salts if suitable. The system could be run without the Calcium Oxide salt being added as in GB1613728.3, noting a way of removing any dissolved CO2 in the carbonate water electrolyte, would not occur which may create a build-up of solids on the electrode or electrode erosion unless a way of removing the dissolved CO2 could be achieved prior to said carbonated water being used as electrolyte in the electrolysis cell. In GB1613728.3 it was envisaged that renewable electricity would be mostly used to power the electrolysis bank, allowing for electricity from the energy plant to be used when renewables are not available, since then, with application GB1714707.5 and GB1801061.1 it may be possible for the electricity generated by the power plant (combustion) could

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supply enough electricity for electrolysis, however leaving the option may allow these power plants to choose and have operational flexibility, where a plentiful renewable energy such as hydro, wind or solar electricity supply is available. The energy used to make the Calcium Oxide should ideally be a renewable, however Calcium Carbonate is the basic material to make Calcium Oxide, so it could be used as a recyclable product in that CaCo3 is formed (when CaO is added to the carbonated water electrolyte in the electrolysis cell), rather than the CaCo3 being processed/converted by bubbling 502 through a CaCO3 slurry (as used in some high Sulphur content coal burning power station scrubbers)to create Calcium Sulphate Ca504 as a useful building material.A further application was submitted GB1801061.1 showing a further efficiency is available from the kiln/rotary kiln method of making calcium oxide (which also be used as a salt in the water electrolysis bank) ,which is the widely used way of taking calcium carbonate/other carbonate type material, mostly as quarried rock and as a fine powder, which is heated to very high temperatures to drive off water and carbon dioxide, giving a sintered powder mostly of calcium oxide,which is the basic cement product as common building material. It is thought that cement making in the kiln or rotary kiln method is responsible for an estimated 10% of global carbon dioxide emissions, and it is an energy intensive process, using a lot of heat in combustion of fuels to gain the high sintering temperatures required. In the kiln and rotary kiln method of cement making, attempts have been made to recover heat, to keep energy costs down and in this application and G131801061.1, the heat as hot carbon dioxide and water can be used much better (as would be exiting a kiln or rotary kiln process, heating calcium carbonate, or carbonate source) by introducing the cement kiln/rotary kiln exhaust to flue products flow/stream of the series combustion units of the combustion/electricity power generation plant of this patent application and those applications related to it. To remove/reduce these carbon dioxide emissions would be helpful to climate change, carbon dioxide and/or any combustion process that emits carbon dioxide and water, could be used in GB1613728.3, GB1714707.5and GB1801061.1. Patent application GB1801061.1 sought to clarify that indirect combustion/non combustion sources of CO2 or CO (carbon monoxide) could also be sources to introduce to

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the electricity generation post combustion (or pre combustion) feed or flue products flows of the combustion electricity generation plant e.g. brewing, chemical sources and bio digestion and bio methantion sources.

This application is related to the original design filed in June 2016 as well as GB1613728.3, GB1714707.5 and GB1801061.1 as it has an improvement and clearer explanation of some of the system possibilities/performance and refinement of operational explanation, utilising the same inventive steps of series combustion, heated oxygen and gaseous fuel inputs and use of a salt (in this example CaO) to improve water electrolysis cell efficiency and make a useful by-product CaCO3, and also the step of absorption of CO2 into water to produce a carbonated water,separating out CO2 where required from mixed gas flows, the CH4 and hydrogen separating in a simple and known process, in that H2 and CH4 gases are not soluble in water. Also cooling system patent application GB1711686.4 is related. This application further shows a modality in the variations and modifications section, which whilst not preferred as CO2 is created as an end product, (in that it is hoped biomass or bio solids or bio methane or synthesised methane will be used as fuels as they are Carbon neutral fuels and not fossil fuels) ,offers the efficiency of series combustion with heat recovery and heated gaseous fuel/oxygen to reduce fuel use, and an alternative to converting the CO2 to CH4 via the Sabatier process,by making cooled or even solid CO2, which can be used in other ways.11 the Sabatier process is not used then hydrogen would not be required for the Sabatier reaction and water electrolysis would not be required,the carbonated water produced in component D would therefor need treatment to reduce acidity, by using an alkali for example,or another method of CO2 removal from the water, prior to use or release to water courses. Water electrolysis may still be conducted, however the economics would then favour the Hydrogen being exported (it can be used as electrical generator coolant) for other uses.

This application also seeks to clarify the sources of Oxygen used for combustion and/or cooling as there are choices, and the electrolysis of water produces a ratio of elemental Hydrogen and Oxygen gases, that do not always fit easily with certain plant operation modalities, as well the safety aspect of keeping combustion processes fed with Oxygen should any water

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electrolysis cells be subject to failure, such as electrolysis being conducted some distance from site and a pipe rupture. There is also the potential of the plant to burn problem wastes,(which could be very useful in dealing with substances that become toxic pollutants in current disposal methods) at high temperature in series combustion units to create flue products low in the toxic chemicals (that lower temperature combustion systems create), fuels such as tyre crumb or powder, waste oil sludge's, tar residues, which are very high in actual carbon content and do not immediately form into CO2 in a single combustion process (rather than series combustion process), such fuels in oxygen combustion processes,create high volumes of CO2 per MW of electrical energy and put considerable demands on any post combustion Sabatier process in terms of Hydrogen required. This application also has further thinking of how the heat recovery section,component C could work to give quite high heat recovery to heat fuels or oxygen,an/or power a further steam circuit or turbine as well as flue integral flow powered turbines. The energy outputs from component C could be considerable as they are cumulative from the series combustion process of components A and B and will also be carrying considerable amounts of water vapour. Component D offers a thermodynamic relationship to component C,in that as the flue products of gases/water vapour are cooled in component D they reduce in volume,creating a lowering pressure gradient from component C to D, and a possible increase in velocity of certain flue gas product flows in component C If flue products in component C are at high temperatures and component D pre Sabatier flows at 0oC or lower then quite powerful turbines with some principals of steam turbine engineering could be used in component C as well as the more simple internal flue products stream turbines powering electrical generators shown in GB1613728.3, GB1714707.5 and GB1801061.1.

In the larger discussion about fossil fuel use and so called greenhouse gas emissions it is clear that the main way these plants could run is to make CH4 and none or very little CO2 (unless variation in this application is used as where CO2 is produced and exhausted to atmosphere), the CH4 produced is then combusted either in the electricity generation system of the plant or exported off site. Whilst requiring energy to make 02 and 112 gases and energy for other

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operations, if a renewable/surplus electrical source and the fuel is biomass or bio methane, then the CH4 is carbon neutral and the system can therefore be seen as sequestering some CO2 (as CH4) as well as fuel extension of biofuel resources and combustion fuel quantity use, giving energy resource benefits, as liquefied CH4 can be used as a transport fossil fuel replacement. This further means that photosynthetic fixed carbon when converted into a fuel CH4 utilising renewable energy and/or surplus energy to provide hydrogen for the Sabatier reaction, that a useful high energy fuel, CH4 can be made from the carbon utilised in photosynthesis, as well as generating electricity when combusted, to make the CO2 gas used in the Sabatier reaction. By using series connected combustion units transferring post combustion products contained within a flue, to the next combustion unit,and oxygen /fuel combustion, pre heated with recovered heat, a much more efficient power station and use of fuels can be gained and this brings CO2 outputs down if this CO2 is converted into CH4 via a Sabatier reaction,then some of this CH4 can be fed back to secondary combustion units (or primary combustion co firing), giving a high electrical output electricity generation system capable of supplying an electrical grid,from a low energy photosynthesis derived fuel source, and also renewable/surplus electricity in patterns that enable hydrogen to be made for the Sabatier reaction process. The modality enhanced in this patent application attempts to show remote water electrolysis that may be necessary in the larger system, and modality where CO2 is produced due to the limited operation or removal of the Sabatier process. This would create direct CO2 products or emissions from combustion which is not preferred, but shows that a hybrid system may be possible where electricity demands can be switched to electrolysis, when the demands are available, or even offer seasonal operations. It should also be noted, that solar energy, wind energy, hydro energy and nuclear energy do not dispose of waste materials, which combustion can do, this patent application making use of quantities of waste that would otherwise go to landfill, therefore enabling an efficient low CO2 emission combustion system to still have an important part to play in the overall energy systems we use.The combustion of Biomass or other fuels in Oxygen, (rather than traditional air draughting), offers an immediate thermal efficiency improvement, in that energy is not wasted in heating the 78% of the

Introduction and brief description:

Nitrogen (and other none oxygen gases) present in air. Oxygen combustion also gives elevated combustion temperatures and higher velocity post combustion gaseous flue speeds, where more compact combustion areas/boilers can be used.This poses a possibility that when higher electrical output power stations 500MW and over are required, that higher flue product stream velocities and/or higher internal flue pressures, which can utilise additional turbine placements of post combustion product flows (thought about in the first design), to generate electricity. In Oxygen/ fuel combustion of organic fuels mostly composed of Carbon and Hydrogen and Oxygen, the majority of the post combustion flue products stream would be CO2 and H20, which in a traditional power station would be cooled with some heat recovery, and released to atmosphere, which is in effect an energy loss (sometimes referred to as stack losses which can be about 16% of Kj of the fuel combusted) and such excess heat is rarely utilised except in urban heating systems, which are suitable for places where long cold weather periods are found. In this patent application (and related ones) ,these same flue products are cooled,the water vapour condensed out, and the CO2 separated out and processed through a Sabatier reaction, to give a post Sabatier stream of CH4,H20 and some CO2 and H2 unreacted,the water being condensed out and the residual CO2 removed, the CH4 produced could then be used as fuel or co firing fuel, for the concurrent series combustion sections of the power generation station, or the CH4 can be put to store or grid, the separated H2 gas being fed back to the Sabatier reaction, or used for cooling, or as a combustion fuel source. The CO2 produced (and water vapour), (post all combustion sections) if converted into CH4 could provide fuel to facilitate groupings of series combustion units to give higher electrical power outputs and also improved energy and thermal efficiencies compared to conventional designs, by making use of the stack losses and transferring otherwise waste heat, to enable lower fuel quantities to be used in the next combustion stage. It may be possible to pressurise some gas combustion sections by restricting the flue products flow, as fuel and oxygen can be introduced into the combustion chamber/furnace, not only at pressure but pre heated by recovered heat, methane having a high auto

Introduction and brief description continued:

ignition temperature enabling said methane and oxygen to be pre heated to high temperatures of 400oC perhaps higher, giving a cycling of recovered heat back into the combustion furnace/boilers reducing fuel and oxygen requirements.

A heat recovery section would be receiving the cumulative combustion flue flow containing mostly CO2 and water vapour, the water vapour providing the property of waters specific heat capacity, enabling considerable heat to be given up in, heat recovery, and potentially giving an overall efficiency in terms of electrical output, not available in current single furnace/boiler/gas turbine designs, as stack losses can be made better use of. A cooling section, which may also provide recoverable heat sources,also creates a reducing in volume of gases and water vapour, and it is possible that as a continuous process flow that velocities and pressures of internal flue product flows could be seen as gradient of high pressure going to the lower pressure of the cooling section, giving a useful flow pressure which can be utilised to directly power additional turbines and or indirectly power steam turbines from heat recovered, giving additional electrical power outputs not seen in current power station designs.

The power stations in this design would be more efficient and give greater electrical outputs than current air drafted designs, utilising the pre heated oxygen/fuel combustion plant/design without the making of CH4 through a Sabatier process and processing the CO2 to use or atmosphere. The use of the Sabatier process enables CH4 to be made from CO2 and H2, therefore emissions of CO2 that would in current power station design, go to atmosphere, in the design are made into CH4, which is a fuel, effectively giving the initial fuel combusted a second life. The Sabatier reaction is heat and pressure reaction so can run in an energy efficient way. The making of elemental Hydrogen and Oxygen, from the electrolysis of water is not energy efficient requiring electrical power sources, and this poses a number of problems in balancing how much CH4 can be made and how much CO2 will be not converted and need to find another route/use.

Utilising an external stream of CO2/water vapour is of use in this system and cement production is identified as being a suitable source as the CaCO3/CaO

Introduction and brief description continued:

cement sintering gives very high flue/exhaust temperatures, and contributes to thermal efficiency and combustion section fuel reduction, as well as containing CO2 for conversion to CH4.These plants can theoretically reduce cement emission by converting CO2 into CH4 and have a further use in the overall emission picture. Other external sources of heat would need consideration if they detrimentally affected equipment or process of the design.

It is understood that this design does offer higher electrical outputs and better thermal efficiency, a current modern design air drafted single 600MW coal (fuel rated at 20000Kj/Kg) burning plant using air drafting uses 350,000 kg an hour at full load or 583kg of coal per MW/ per hour,putting out 444,756 kgs/per hour of CO2 or 763Kg of CO2 per MW/per hour, other electricity production plants in current use will be less fuel efficient and produce more CO2 per MW, and it is obvious that in using fossil fuels, the additions of CO2 to the atmospheric gaseous balances is considerable, and having a way of converting CO2 to CH4 offers not only a product that can replace fossil fuel natural gas use, but ads as a buffer/store of CO2, as CH4.1f using a biomass fuel i.e. made by plants from the current living biosphere, or bio gas/methane fuel,then the CO2 absorbed by photosynthesis in the plants life, to make the basis carbon content is termed carbon neutral and combusting it does not increase CO2 levels, in the way that fossil fuels when combusted,containing carbon sequestered/ by photosynthesis from ancient life cycles, behaves.

It is difficult to be precise on what the electricity power plants of this patent application could achieve, as other factors affect performance, but using sequential series combustion, with heated oxygen/fuel enables less fuel to be burnt and lower CO2 outputs. There are also the higher combustion temperatures of oxygen/fuel combustion which enables some previous difficult initial stage combustion fuels, such as tyre crumb/powder to be sequentially combusted to more clean flue gases of mostly CO2 and H2O, it is thought that flame temperatures in a Methane/Oxygen combustion could be 2500oC or higher, adequate for complete combustion of most fuels. Being able to use more difficult fuels that may be wastes, eases the pressures of needing biomass sources and enables such electrical power stations to not use fossil fuels as well as giving an alternative to forests being used as primary

Introduction and brief description continued:

biomass fuel sources. Because the water molecule splits into 02 and H2, the ratio of Oxygen required for combustion, to the ratio of Hydrogen to be used in the Sabatier reaction has a number of factors in fuel and plant efficiency. These sources require managing to balance the modality of the plant unit operation and this is more difficult on the size of electrical outputs and ability and fuel choices in the combustion sections, in order to process CO2 to CH4 via the Sabatier reaction. It is hoped that Oxygen and Hydrogen production from water electrolysis can be done/managed on site using available imported renewable electricity resources and/or electrical outputs from the electrical generators of the plant, and or spare or surplus grid electricity. Water consumption on the plant site, can come from the water condensed out of the combustion flue product flow, and certain high moisture content fuels, that can be combusted in oxygen rather than normal air drafting, such as bio solids, offering additional water to be recovered, and it is possible that actual water requirements may be met without much on site water abstraction. Remote water electrolysis sites will need a supply of water, which may need pretreatment prior to use as electrolyte for e.g. mineral content and may be a little less efficient without the addition of a salt to the electrolyte, but could operate in some situations reasonably autonomously and in one example route excess oxygen to feed to water bodies to dissolve into the water to oxygenate it and give a positive environmental effect to said body of water.

Continuity of combustion and flue product flows (from component A to component B to component C and to component D or multiples thereof) is envisaged to be continuous, as would be heat recovery and cooling sections, although the Sabatier process flows and cryogenic separation and CH4 liquefication may need some separate management/buffers/stores.

In the cooling section, cold and or liquefied /gases are used for initial cooling, and then a water cooled stage and a direct contact with water ice stage, the outflow of the ice cooling stage as liquid water could be used as the coolant in the water cooling stage before being routed to the water electrolysis bank to become the electrolyte. It is thought the cooling section (component D) should be powered from a renewable, dependent upon what is available or specified for operation requirements.

Introduction and brief description continued:

Overall the thermal efficiencies, fuel/Oxygen pre heating and heat recovery and additional electrical generation turbines can give this plant much lowered/improved CO2 outputs per MW as well as making CH4 as a fuel, however the water electrolysis does consume electrical energy and this affects calculations around sizing of electrical outputs to grid, CH4 production, CO2 emissions to atmosphere and use of renewables.

This application does give an electrical power station that can produce CH4 from CO2, but this arrangement may need external supplies of Hydrogen and/or Oxygen using spare or renewable electricity and this requires a larger energy system conceptualisation, which is outlined in this application.

It is also possible that the post Sabatier products with the water condensed out, of CH4 and unreacted CO2 and H2 gases could be separated and liquefied into, but this cool stream of mixed gases could be used as a gas coolant and then become a fuel which (see flow G4CF key in drawings figure 6) may give reduced energy use for liquefying and cooling post Sabatier gaseous flows as well as some modality flexibility, any CO2 excess from cycling can be released through a post combustion flow cooling/water condensing flow (DICO key on drawings figure 6) to further processing as CO2 or release to atmosphere.

Introduction to drawings:

Drawings and keys are referred to as components or units, as they can best be described without confusion and complexity, beginning as basic framework of the whole system or in sections which will be further described in the description. Intermediate storage of electricity or vessels to contain of hold flows of vapours/gases or other products as well as valves and reciprocating engines, boilers turbines/electricity generators, are not generally shown throughout the drawings, to make the drawings less complicated. It is assumed that heat exchangers/waste/recovered heat will pre heat Oxygen and Methane/fuel supplies to the combustion units, using recovered heat from component C and cooling heat exchangers, and/or recovered heat from ice water making and/or cryogenic processing within component D, and /or other source of heat e.g. Solar thermal, to improve the thermal efficiency of the series combustion/larger system. Drawings are also included for modifications and variations to help clarify the larger energy system explanation, supporting the patent application.

Drawings Figure 1: A schematic view of flows of materials and energy in the power/energy generation system. There are 5 main sections key as A,B,C,D and F.Component A (or multiples thereof) is the initial combustion power plant generating electricity, Component B (or multiples thereof) is the secondary combustion plant generating electricity,Component C is heat exchange plant that may also generate electricity indirectly, removing heat from the flue gas from component B (or component A if component B is not present see variations and modifications),component D is the continuous consequential heat exchanger, cooling process, to separate out the water vapour of the combustion processes, to liquid to give a mostly CO2 gas stream and then mix and react this CO2, with 112 in a Sabatier process and a subsequent cooling process, to condense/remove the liquid water of the products from the Sabatier process, the remaining gases mostly of CH4, unreacted CO2 and I-12 then going to the cryogenic section to remove any remaining CO2 and liquefy the Methane by cryogenic cooling,whilst leaving the hydrogen as a super cooled gas. Component F is the "electrolysis bank" where water is split and separated into its elemental gases Hydrogen and Oxygen, using electricity either from a renewable source or from the electrical

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power generation of components A, B or heat recovery component C. The flow of combustion products between the furnaces/boiler of A and B is shown are flows Gl, G2, and flow G3 is from the heat recovery/heat exchanger component C, to the component D cooling section, to remove the water, then the CO2 flow and a supply of Hydrogen are mixed and processed in the Sabatier reaction, and then secondary cooling to remove the water as liquid and final cryogenic cooling section to separate post Sabatier products to make liquid CH4, gaseous H2.

To take each main component in turn Component A key is the primary combustion plant, it is fed with fuel Z or combination of fuels, this fuel is primarily envisaged as Biomass, Bio solids or recycled wood/paper/cardboard, however fuels such as Ethanol, plant and animal oils/fats, shredded or powdered tyres, waste mineral oil, or fossil fuels, or synthesised methane or natural gas or bio methane or bio gas. The products are combusted using oxygen to heat a boiler to provide steam for steam turbines or multiplicity of steam turbines to generate electricity, or if liquid or gaseous fuels can be combusted in gas turbines or multiplicity of gas turbines should steam turbines not be used, however it is envisaged that boiler and steam turbines will be a preferable energy conversion of heat to electrical energy (reciprocating engines are also possible if liquid or gaseous fuels are used in components A and B). From component F (The water electrolysis bank) we have flow Fl which is the 02 (elemental oxygen) flow to the burners /furnace/grate/boiler. Flow Fl can be used to assist fuel supply Z to the point of combustion e.g. blowing biomass or other fuel into the combustion zone, it can also be pre heated from recovered heat (not shown in drawings but preferred use) to improve thermal efficiency, noting also that such 02 may have to be dried (water removed)prior to use (drying not shown in drawings),Input Dl is Methane (CH4) and/or mixed gas stream which could be from the Sabatier reaction within component D or another gaseous fuel source as co firing, D1 can be pre heated using recovered heat to improve thermal efficiency (not shown in drawings) and may need to be dried (water removed) prior to use (not shown in drawings).Flow Al is electrical flow, from electricity generated via electrical generators powered by a rotating shaft from gas or

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steam turbines or multiplicity of gas or steam turbines,or reciprocating engines as part of component A. Flow G1 may contain internal pipe turbines that use the pressure and velocity of the G1 flow to generate electricity (see Drawings figure 5 ii and iii) although it is expected that this when engineered should be a short connected flue containment section, to retain heat.

Pipe or flue gas transfer system G1 should contain a hot stream of high velocity post combustion products mostly of CO2 (Carbon Dioxide) and H2O (as water vapour), some ash char and unburnt products may also be present as well as some other oxides or gases. This pipe or flue post combustion transfer should be designed to cope with high temperatures and pressures, as should the construction of the furnace chamber and boilers and designed for long running time periods, it may be above ground or underground and should be well insulated to keep heat loss down.

Component B (see drawings figurel and figure 2) receives the post combustion flue gas products of component A via connected flue pipe/conduit, of the post combustion transfer system G1 where it is distributed to the combustion chambers/furnaces and/or gas turbines of component B (noting that reciprocating engines may possibly be used). As it is hot this aids thermal efficiency for steam production/boilers and steam turbines and may give some assistance to gas turbines. Oxygen is supplied via flow Fl (this may be pre dried and pre heated using recovered heat not shown in drawings).Flow D1 is Methane which may be from the Sabatier process of component D or natural gas/methane (this may be pre dried and pre heated using recovered heat not shown in drawings) to improve overall thermal efficiency. Feed Z is alternative fuel source if required. The natural gas/ Methane CH4/fuel Z is combusted with Oxygen 02, (and the flue products of component A), as either in gas turbine or multiplicity of gas turbines system to make electricity or a boiler or multiplicity of boilers to make steam, to power steam turbines or multiplicity of steam turbines to make electricity from electrical generators powered by a rotating output shaft of said steam turbine or gas turbine (turbines and electrical generators not shown in drawings noting also that reciprocating engines may possibly be used).

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The post combustion products from either gas turbine or furnace/boiler flue products are symbolised as flow G2 which is a pipe transfer system containing post combustion flue products, consisting mainly of CO2 (Carbon dioxide) and H2O (water vapour) and some ash/ char and unburnt products may be present as well as other gases or products. Flow G2 may contain internal pipe turbines that use the pressure/ velocity of the G2 flow to generate electricity (see Drawings figure 5 ii and iii) although it is expected that this when engineered should be a short section to retain heat. This pipe or flue post combustion transfer should be designed to cope with high temperatures and pressures, as should the construction of the furnace chamber and boilers and designed for long running time periods, it may be above ground or underground and should be well insulated to keep heat loss down.

Flow B1 represents the flow of electricity from either gas turbine or multiplicity of gas turbines or boiler steam powered turbines or multiplicity of steam powered turbines with a rotating output shaft, to power electrical generators to make electricity (noting also that reciprocating engines may be possible).

Component C and Drawings Figure 5 Section i) shows a schematic flow of flow G2 (post combustion flue products stream from component B or component A if B is absent) into component C or multiple units or subdivisions of component C,which is a heat exchanger or multiplicity of heat exchangers, to remove heat from the flow G2 and/or an internal turbine or multiplicity of turbines to use the pressure velocity/velocity of the post combustion products of flow G2 from component B (and/or flow 61 from component A if component B is absent).The heat extracted/recovered being used to either power a further gas/air turbine or multiplicity of gas/air turbines or heat water in a boiler or multiplicity of boilers to raise steam to power a further steam turbine or multiplicity of steam turbines (not shown in drawings) or to be used as recovered heat elsewhere in the full system e.g. pre heating Oxygen or Synthesised Methane or natural gas/methane,prior to combustion in components A or B or multiples of A or B (not shown in drawings). Key CW is the pipe wall containing the post combustion flue

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products G2 (or G1 if component B is absent and component A is connected to component C), a counter current internal heat exchanger in series as key CE1,CE2,CE3 and CE4 (more or less heat exchangers may be used) , flow G2 (or 51 if component B is absent and component A is connected to component C) passing through or around, heating the external surface of the heat exchanger, transferring heat to a flowing internal material, in a counter current manner, and separate from (perhaps pressurised) the post combustion flue products flow G2 (or 51 if component B is absent and component A is connected to component C).By using a counter current heat exchanger should enable higher heating of the coolant material shown exiting the combustion flow products pipe wall as key CO, flow CO then going on to power either a gas/air turbine or multiplicity of gas/air turbines with a rotational output shaft to power generators to make electricity or heat a boiler/s to make steam to power a steam turbine or multiplicity of steam turbines with a rotational output shaft to make electricity, or reciprocating engine or multiples of reciprocating engines, with an rotational output shaft to power an electrical generator or to pre heat fuel and oxygen supplies for components A and B or multiples thereof (not shown in drawings).Flow CO once its heat is transferred returning to the heat exchanger system as key CI flow.

Figure 5 ii) cross section shows a single turbine key as T (overhead and side view) within the post combustion flow G2 (or 51 if component B is absent and component A is connected to component C) very similar to a wind turbine. Key CW is the pipe wall containing the post combustion products, the gases and vapours strike the turbine blade surface, so designed to rotate in one direction, to drive a belt/rope/chain or hydraulic pump key PT, to transfer the rotational power through the combustion flue products wall (but keeping internal pressures/products within the post combustion flue gas pipe/transfer system) , to drive an electricity generator key GN to make electricity flow E1.

Drawings Figure 5 iii) cross section shows a more complex multiple section turbine, key T, which would look like a multiple blade, gas or steam turbine, which may make better use of the pressure, this taking the rotational power of the turbine T, through a shaft (but keeping internal pressures/products within the post

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combustion flue gas pipe/transfer system), key PT, to drive an electricity generator key GN to make electricity output shown as flow El.

Component D and Drawings figure 6 receives the post combustion flue gas products flow from component C (see drawings figure 1) as flow G3, which having some heat removed in component C, should be ready for cooling to remove the water vapour.Drawings figure 6 show stages within component D, starting with post combustion flow G3, entering heat exchanger DG1, which is cooled by gas (either CH4, 02, H2 or CO2) the coolant gases entering into the heat exchanger DG1 as flow Gil and exiting the heat exchanger as G01.

Flow G31 then exits DG1 and passes through heat exchanger DG2 which is cooled by gas (0-14, 02, H2 or CO2), the coolant gases entering into the heat exchanger as flow GI2 and exiting the heat exchanger as flow G02.

Flow G32 then exits DG2 and enters heat exchanger DW, which is water cooled heat exchanger which should cool flow G32 to around 10oC.The coolant water (or chilled water not shown in drawings) enters into the heat exchanger as flow WI and exiting the heat exchanger as flow WO which may then flow to the water electrolysis bank component F (not shown in drawings figure 6).

Flow G33 then exits DW and enters a further cooling stage DI where water Ice (formed from demineralised water if required) is introduced as input DMII, as cube or flake or crushed or other physical form, in the top of vessel, in a way that keeps pressure integrities of the containment walls of flow G33, flow G33 coming into direct contact with the ice allowing for the water vapour to condense out and become liquid water, and exit the vessel as output WO2,and absorb some of the CO2in flow G33, to create carbonated liquid water which then may be used, either as a direct feed to the water electrolysis bank component F (not shown in drawings figure 6) , or used as cooling water for the DW heat exchanger as coolant feed flow WI, the water may contain some combustion products e.g. flecks of char/ash or molecules of other substances which may require removal (not shown in drawings figure 6).The mostly CO2 vapour that now composes flow G34 (as the water has been removed) exiting section DI is cool at around 0-10oC.The option to remove CO2 at the DI section is shown by output key DICO,which enables CO2 gas to be managed,which

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could be to atmosphere or to go onto further processing to be made into low temperature solid CO2 or other use. The flow G34 now mostly composed of CO2 gas and a little water vapour and other combustion flue products, is cool at 0-10oC, and can be stored (not shown in drawings figure 6) , and then moves into a Sabatier process section key SAB where it is mixed with hydrogen gas fed by flow I-12 at a ratio 1volume of CO2 gas to 4 volumes of Hydrogen/H2 gas (or whatever volumetric ratio is required mixing at same temperature and pressure), pressurised and heated (to 50psi /345kilopascals and 300-400oC or other pressure temperature combination as required) to facilitate the Sabatier reaction, where CO2+H2 is converted into CH4 gas and H2O water vapour, and some unreacted Hydrogen gas and CO2 gas, as the process is not 100% efficient. The heat from the Sabatier reaction can be recovered in a heat exchanger process (not shown in drawings figure 6), but may also require additional heat inputs key EN, which may come by electrical heating from on site or renewable electricity supplies to site, or from steam or heat recovered in components A,B,C or D (not shown in drawings figure 6) or other source of heating.The post Sabatier reaction products flow becomes flow G41 should be cooled to less than 200oC whilst at pressure(to 50psi /345kilopascals or other pressure temperature combination as required) and it is hoped the process will have a incorporated heat exchanger process where the exit flow of the Sabatier reaction heats the incoming flows of H2 and CO2 to get reactants exit flow G41, to below 100oC The post Sabatier reaction flow G41 consisting of CH4 gas,H2O vapour and some unreacted CO2 gas and H2 gas, must now go through another cooling stage similar to that as described above (although some stages can be removed if required for process operational efficiency as the volumes to be cooled are smaller, not shown in drawings figure 6). Key DGSP1 which is a gas cooled heat exchanger (cooled by either CO2,CH4,H2 or 02 gases), gas coolant input being via GIPS1 and exiting the heat exchanger by GOPS1.Flow G42 then flows to a second gas cooled heat exchanger DGPS2 (cooled by either CO2,CH4,H2 or 02 gases) ,gas coolant input being via GIPS2 and exiting the heat exchanger via GOPS2.Flow G43 then flows to a water cooling section heat exchanger DWPS2 which aims to bring the flow G43 to below 10oC to bring

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any water vapour to condensing to a liquid, coolant water input is via WIPS and exits the heat exchanger via WOPS. Flow G44 then continues to a water ice cooling section where water ice (preferably demineralised water), is introduced as input DIPS either as crushed, flaked or cubed ice, in a way so as to keep the pressure integrities of flow G44, flow G44 coming into direct contact with the ice. In this section of ice cooling, water vapour in flow G44 should be condensed out into liquid water.0O2 is absorbed by the water creating a carbonated water, which exits the section DIPS2 as flow WO2PS and can be used as either coolant water for water heat exchanger feeds WIPS or WI or as feed to the water electrolysis section F of drawings figure 7.1t is possible that dependent upon size of section DIPS2 and throughput,that all CO2 gas present In G44 entering this section can be removed by absorption into the ice and iced/condensed water, leaving as exit flow G4C of DIPS2 composed of CH4 and unreacted H2 gases, which are not absorbed by water and pass through as molecular and elemental gases respectively. However it may be that not all the CO2 can be absorbed into the water, water ice melt and this CO2 may require removal before or during the cryogenic freezing section.

Flow G4C being composed of CH4 and H2 gases and the water vapour condensed out (if the water vapour is not condensed out some drying may be required not shown in the drawings), then flow into a cryogenic freezing/cooling section key CRY() which is powered by energy input EN1 (most likely electrical energy, powering gas or refrigerant compressors and should be renewable such as e.g. solar or wind power collected on site), with a coolant circulation as NC as the coolant inflow and HO as the coolant outflow, HO having a heat exchanger (not shown in drawings) to extract heat that can be used elsewhere in the system e.g. for pre heating fuels or Oxygen. The cooling of flow G4C to very low temperatures (-160oC or lower or whatever temperature pressure combination is required) to liquefy the CI-14 gas, is a way of separating the H2 gas from the CH4 gas,the H2 gas requiring a lower temperature to liquefy and it should be possible to remove as super cooled H2 gas into flow/store output key H, and remove liquefied 0-14 into flow store output key CH. Flow output CO from the CRYO section is an option to remove CO2 (equipment to remove the CO2 not shown in drawings figure 6,which

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may be as gas,liquid or solid) should it not be possible to remove all of the CO2 in the DIPS2 section, and could be used as gaseous coolant in component D or reused in the Sabatier reaction section SAB, or released to atmosphere (not shown in drawings). Output H from the CRYO section as super cooled gaseous hydrogen (it could be a liquid if equipment will allow the super low temperatures), this could be used (not shown in drawings) as coolant for the electrical power generators, or coolant in sections of component D and then be reused, in the in feed H2 of the SAB section, or it could be used as fuel for the combustion sections A and B or as a coolant for the electrical generators,it is however felt,that as fuel for combustion this in overall energy efficiency of the whole process, may not be useful, flow H could need additional drying for some applications (not shown in drawings).

The CH outflow from the CRYO section as a super cool liquid CH4 can go to store, which may be useful for some modes of operation, where the storage of liquid CH4 is required; however a portion can be used to fuel the combustion sections A and B,and dependent upon the CO2 outputs entering component D via flow G3 and the scope of the Sabatier requirements and dependent upon the engineering design requirements,can enable some flexibility as to how much CH4 is required to go to store versus how much is required for combustion as fuel in components A and B.Flow CH from the CRYO section can also be used as coolant in component D, and then be processed to standards (which may involve drying and addition of products such as an odour) ,to input into any gas grid network (not shown in drawings), this makes use of the heat removed by cooling to a liquid,by using the CH4 gas as a coolant to sections of component D where heat exchange can then bring it to heat levels for export via the grid network, or higher heating, as pre heated fuel for components A and B. Component D can offer continuous cooling of post combustion products (and pre heating of CH4 and 02 as combustion units inputs), to a continuous Sabatier reaction, to further cooling and removal of any unused CO2, before continuous cryogenic cooling to separate the CH4 as a liquid and H2 as a super cooled gas. It may be that some intermediate stores are required (not shown in drawings) in certain sections of component D or of certain product outflows or

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coolant in feeds to achieve the balances of continuous flow, however this way of processing attempts to make use of thermal energy of cooled gases, to cool the incoming post combustion flow of G3,as well as using water ice cooling sections to condense out water vapour, the said cool or chilled water from the water ice cooling sections can be used in the water cooling sections of component D giving further thermal efficiency,noting that the heat contained in flow G3 as it enters component D could be considerable due to the water vapour present in the post combustion flows, it is believed that as a cooling component overall,component D will have to be capable of cooling large volumes of vapours and gases and offer high heat efficiency/thermal efficiency due to these large volumes requiring cooling. Heat recovery from component D to pre heat fuels and/or Oxygen feeds for combustion, adds an important and innovative dimension to thermal efficiency, making use of heat losses in conventional power stations to directly heat the combustion sections A and B and in particular with boilers raising steam for steam turbines, offers an improved fuel combusted reduction, not available in current conventional power station/engine designs. This concludes the drawings to show the main components and process flow and the application will now show the introduction to drawings as figures 1 to 14.

Drawings figure 1 schematic diagram of whole system Key A=primary combustion section fed by fuel Z and or combination of fuels and/or Dried Methane fuel supply D1, oxygen supply Fl possibly at High internal pressures and feed temperatures, and post combustion flue product flow G1. Heat recovered or steam from A shown as S1 (which could be steam drum blow down from steam turbine circuits), and be used as waste/recovered heat or introduced into flow G1 to aid thermal efficiency.

B=secondary combustion section fed by fuel Z and/or D1 (preferred dried methane/CH4 gas), oxygen supply Fl and post combustion stream G1 from primary combustion component A possibly at high internal temperatures and pressures. Heat recovered or steam from B shown as S2 (which could be steam drum blow down from steam turbine circuits), and be used as waste/recovered

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heat or introduced into flow G2 to aid thermal efficiency. The post-secondary combustion products stream from B is G2.Or multiplicity of B components.

C= Heat exchanger or multiplicity of heat exchangers to recover heat to give flow S3,and/or integral flue turbine or multiplicity of integral flue turbines (not shown in drawings figure 1)powered by the velocity/pressure of the direct flow of products, to power electrical generators to give electrical flow C1.Flow S3 is recovered heat which can be used for Oxygen and fuel pre heating or to power external turbines as air flow turbines or to raise steam for a steam turbine, to power electrical generators to then produce electrical flow C1. G2 inflow to component C becoming outflow G3 D=Cooling of post combustion product flow G3 to remove water, then to process in a Sabatier reaction, fed by Hydrogen supply F2, flow D2 is hydrogen recovered from the final cryogenic process, if re used back into the Sabatier process or as flow D02 to other routes/uses for recovered Hydrogen gas such as electrical generator cooling.Flow W4 is water in feed of filtered, demineralised water for ice making and cooling, Flow W1 is carbonated water from the water/ ice cooling sections to flow to the electrolysis bank. Flow D4 is the CH4 gas/liquid from the Cryogenic separation process for use as fuel or to store or any other use e. g. cooling. Flow D1 is the direct flow of dried Methane/CH4 for use in component B secondary combustion as flow Dl and/or component A primary combustion as flow 01. Flow key CO2 is any CO2 as gas/solid/liquid that can be separated and re used in Sabatier process or other use. Flow A4D is electricity input preferred to be from a renewable source.

Al=flow of electricity from component A produced by combustion of fuel Z with Oxygen flow Fl, by either reciprocating engine, with rotational output to rotate an electricity generator, gas turbine or multiplicity of gas turbines to power electricity generators or boilers, to make steam to power steam turbines or multiplicity of boilers and steam turbines to power electricity generators (not shown in drawings).Electrical flow A2 to supply electricity to

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the water electrolysis bank, or to flow A3 to the electricity distribution grid system. Flow A4 is electricity from a renewable source such as solar energy, wind energy or hydro energy if required.

B1=flow of electricity from component B (produced by combustion of fuel D1 or fuel Z, with Oxygen flow Fl, by either reciprocating engine powering electrical generators, gas turbine or multiplicity of gas turbines to power electricity generators or boilers, to make steam to power steam turbines or multiplicity of boilers and steam turbines to power electricity generators not shown in drawings).Flow B2 to supply electricity to the water electrolysis bank within component F, flow B3 to the electricity distribution grid system.

C1=flow of electricity from flue integral turbine or multiplicity of turbines powered by pressure/velocity of post combustion stream G2, to power an electricity generator or multiplicity of generators and/or external turbines as air flow turbines or to raise steam for a steam turbine, to power electrical generators to then produce electrical give additional electrical power to give electrical flow C1. (Boilers and turbines and electricity generators not shown in drawings figure 1).

Component F= the electrolysis bank, powered by electricity sources flows,A2,A4 and B2.electricty flows, electrical flow C1 could also be used to power the water electrolysis bank (not shown in drawings) .Flow Fl is the oxygen produced from the electrolysis splitting of water into its component elemental gases,this flow should be pre heated from recovered heat or by using the Oxygen as coolant in component D (not shown in drawings figure 1 Hydrogen the oxygen may also be dried if required).Flow F3 is Calcium Carbonate CaCO3 removed from one of the electrodes within the electrolysis cells, created by Calcium Oxide (feed CA) reacting with CO2 dissolved in water to give electrolysis cell electrical efficiency improvement, and precipitate out the dissolved CO2 in the water electrolyte if required. Flow F4 is Calcium Sulphate CaSO4 (the Calcium Carbonate treated with Sulphur dioxide gas) if required. Flow CA is Calcium Oxide added to water in feed W1/W2 to be used in the water electrolysis bank. Flow C031 is CO2 gas from making the Calcium Sulphate Ca504 slurry; the CO2 can be cooled and used for cooling and/or sent

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to component D for use in the Sabatier process for conversion into CH4 (not shown in drawings).

Supply flow AS = gaseous air to supply separator/store for oxygen, separated from air, stored as gas and/or liquid. Key SSO (or piped Oxygen flow from offsite electrolysis units or other method of producing Oxygen).Unit SSO then feeding flow Fl (requiring pre heating from recovered or waste heat not shown in drawings).

Supply F2 is Hydrogen gas from the water electrolysis within component F.Key SSH is supplementary Hydrogen supply (or process) from offsite electrolysis units or other method of producing hydrogen gas. Flow F2 then supplying the hydrogen for the Sabatier reaction contained within component D. Flows Gl, G2 and G3 will be in contained pipes or transfer system capable of withstanding high pressures and temperatures and be insulated.

Drawings Figure 2 simplified Schematic flow showing combustion components A and B: Key (see also above Drawings figure 1 for detailed explanation of key labels)Component A or multiplicities thereof fed by fuel Z and/or combination of fuels and Methane fuel flow D1 (if required), oxygen supply Fl, electricity output Al.Post combustion flue products flow G1 to secondary combustion component B or multiplicities thereof, where fuel D1 and/or fuel Z (preferred as pre heated from waste/recovered heat sources,Methane /CH4/natural gas but could be co fired with other fuels) is combusted with oxygen from flow F1(which is also preferred as preheated from waste/recovered heat sources).Post combustion flue products from B forming flow G2.Electricty produced as described in previously in drawings Figure 1 as electrical flows Al and 81.

Drawings Figure 3 showing a schematic flow of a variation of component A discussed further in modifications and variations section. Key

Z= fuel source D1= Methane supply, possibly dried and heated using recovered heat.

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Z1= fuel source and/or mixed with pre heated oxygen or methane F1=pre heated oxygen supply (from water electrolysis bank component F not shown) A=combustion chamber to provide heat energy for boilers or multiplicity of boilers to raise steam.

51= steam from boiler to power steam turbines section T or multiplicity of steam turbines.

52= steam return from steam turbine or multiplicity of steam turbines section T back to boiler to be re heated.

T=Steam turbine and electricity generator or multiplicity of turbines and electricity generators.

A1=electricity flow from generators to further use or to electricity grid.

G1A=outflow of post combustion stream from combustion section A, with ash/char other particulates.

A2=Sepa ration system to remove, ash/char or other particulates.

G1=post combustion flue gas flow from section A2 (to section B or C) WS=Flow of ash/char other particulates to slurry tank SL.

SL=Is slurry tank containing particulates from combustion and CaCo3 from electrolysis bank as flow F3,flow 522 adding sulphur dioxide gas, to create CaSO4 exiting the slurry tank as flow F4.0O2 produced in the process exiting the slurry tank via flow C031.

522= Sulphur dioxide gas supply to be bubbled through the CaCO3/ash/char/particulates slurry.

F4=Ca504 outflow from slurry tank C031=CO2 outflow from reaction of 502 with CaCO3 in the slurry tank.

F3= CaCO3 slurry input to the slurry reaction tank from the water electrolysis bank.

Drawings Figure 4 showing schematic division of flows to provide even flows and facilitate plant modality, to secondary combustion component 3, bank of electricity generators and heat recovery section C. Key G1=combustion products flow from primary combustion component A

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B= component B with manifold to create multiple streams in this example 6, but more or less units could be used.

Bl=lst boiler, steam turbine and electricity generator or gas turbine and electricity generator feed and combustion unit.

B2=2nd boiler, steam turbine and electricity generator or gas turbine and electricity generator feed and combustion unit.

B3=3rd boiler, steam turbine and electricity generator or gas turbine and electricity generator feed and combustion unit.

B4=4th boiler, steam turbine and electricity generator or gas turbine and electricity generator feed and combustion unit.

B5=5th boiler, steam turbine and electricity generator or gas turbine and electricity generator feed and combustion unit.

B6=6th boiler, steam turbine and electricity generator or gas turbine and electricity generator feed and combustion unit.

G2=collected post combustion flue gas flows from Bl, B2, B3, B4, B5 and 86. El =Electricity flow from electrical generators of component B. C=component C with manifold to create multiple streams in this example 3, but more or less units could be used.

C1=section of heat exchanger and /or additional turbine/s powered by the pressure/velocity of post combustion flow, receiving part of the divided post combustion flow from G2.

C2=section of heat exchanger and /or additional turbine/s powered by the pressure/velocity of post combustion flow, receiving part of the divided post combustion flow from G2.

C3=section of heat exchanger and /or additional turbine/s powered by the pressure/velocity of post combustion flow, receiving part of the divided post combustion flow from G2.

E2=electricity generation from turbines powering electricity generators.

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G3=post component C1, C2 and C3 sections manifold, to collect the post combustion flue gas flow exiting from C1, C2 and C3.

Drawings Figure 5 Cross section through sections of C showing i)simple heat exchanger and ii) and iii) turbine powered by the flow /velocity of the post combustion flue gas products from component B.

Key (see also description of component C above)

1) Counter current heat exchanger to extract heat for e.g. pre heating of Oxygen or fuel feeds, and/or to provide steam for a separate steam turbine, the rotational output shaft turning an electrical generator to make electrical power.

G2=post combustion flow/flue products of B or sections of B or flow G1 post component A if B components are not used.

CW=wall of containment Flue CI= external heat exchange input flow suggested as being steam, but could be other substances.

CO=external heat exchange output flow suggested as being steam, but could be other substances.

CE1-CE2-CE3-CE4=heat exchanger surfaces through which flow CI takes heat from flow G2 to exit as flow CO.

ii) Turbine design (overhead and cross sectional views) as similar to single rotor with mechanical power output to power an electrical generator whilst keeping the flue products flow G2 at pressure.

G2= post combustion flow/flue products of B or sections of B or post component A if B components are not used.

CW=wall of containment Flue. T=single rotor turbine.

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PT=power transfer, chain, rope, pulley or hydraulic drive, transferring power through the flue wall containment to create a rotational output at the end.

GN=electricity generator powered by the rotational output shaft of PT. E1= electrical output of electricity generator.

Ili) velocity/pressure multiple rotor turbine internal to flue products flow, to power an electricity generator external to the flue products containment.

G2= post combustion flow/flue products of B or sections of B or post component A if B components are not used.

CW=wall of containment Flue.

T=multiple rotor turbine (similar to gas or steam turbine arrangement).

PT=power transfer, shaft carrying rotational output, transferring power through the flue wall containment to create a rotational output at the end.

GN=electricity generator powered by the rotational output shaft of PT. El= electrical output of electricity generator.

Drawings Figure 6 showing product flows,i) of post combustion flue products in a cooling stage prior to the Sabatier process to remove water and repeated ii) after the Sabatier process to remove water and CO2 (as required) to the final cryogenic stage to separate out the Hydrogen and Methane.

Key see also component D section above, in introduction to drawings. i)From component C to Sabatier reaction Flow section G3=post combustion/post heat recovery component C products flow.

DG1=gas cooled heat exchanger with coolant inflow Gil and coolant outflow G01.

G31=Post DG1 section product flow

Introduction to drawings continued:

DG2=gas cooled heat exchanger with coolant inflow GI2 and coolant outflow G02.

G32=post DG2 section product flow.

DW=water or chilled water heat exchanger with coolant inflow WI and coolant outflow WO.

G33=post DW section product flow.

Dl=water ice cooling section, where water ice input DMII is introduced into a vessel in a way that maintains any pressure integrities of the G33 containment flow/products.The ice coming into direct contact with the products of flow G33 to condense any water vapour to a liquid, this liquid then exiting through outflow W02, to be used as coolant and/or a feed to the electrolysis section. To cool outflow G34 to below 10oC (some CO2 in G33 may also be absorbed into the water/ice) Heat from making the water ice may be recovered to use elsewhere in the process e.g. to pre heat fuel or oxygen feeds used in the combustion sections. It is thought that this water ice section can be short as it is trying to condense water, and not remove much CO2 other than that already absorbed by the condensing water. The DICO flow is the option to remove cooled CO2 gas from the DI vessel, either for operational reasons or, to release the CO2 to atmosphere or further processing /other use.

G34=post DI flow consisting of post combustion products, mostly gaseous CO2.

SAB=The Sabatier reaction section where CO2 gas is mixed with Hydrogen H2 gas, taken up to the temperatures and pressures necessary for CO2 +H2 to react to form CH4 and H2O.Having hydrogen feed H2 and energy feed EN, said energy being either heat source such as steam or electricity for heating to provide the desired reaction temperatures of 300-400oC or whatever temperature and pressure may be required to facilitate the reaction. The post Sabatier reaction flow having to be kept at pressure as required while cooling to stop steam reformation of CH4 back to CO2.

G41=Post Sabatier reaction product flow which may be a mixture or CH4 and H2O and unreacted H2 and CO2.

Introduction to drawings continued:

ii)Flow from Sabatier process to cryogenic cooling and separation section.

G41=Post Sabatier reaction product flow which may be a mixture or CH4 and H2O and unreacted H2 and CO2.

DGPS1= gas cooled heat exchanger with coolant inflow GIPS1 and coolant outflow GOPS1.

G42=Post DGPS1 product flow.

DGPS2= gas cooled heat exchanger with coolant inflow GIPS2 and coolant outflow GOPS2.

G43=post DGPS2 product flow.

DWPS2= water or chilled water heat exchanger with coolant inflow WIPS and coolant outflow WOPS.

G44=post DWPS2 product flow.

DIPS2= water ice cooling section, where water ice is introduced through inflow DIPS in a way that maintains any pressure integrities of the G44 containment flow/products.The ice coming into direct contact with the products of flow G44 to condense any water vapour to a liquid, this liquid then exiting through outflow WO2PS, to be used as coolant and/or a feed to the electrolysis section. To cool outflow G44 to below 10oC (some, preferably all the CO2 in G44 may also be absorbed into the water/ice).Heat from making the water ice may be recovered to use elsewhere in the process e.g. to pre heat fuel or oxygen feeds used in the combustion sections. If it is better to remove the CO2 via a cryogenic separation method then this direct contact water ice section can be short in duration.

G4C=post DIPS2 flow with the water condensed out and consisting mostly of CH4 gas and unreacted hydrogen H2 and possibly some unreacted CO2 although it is preferable that it contains no CO2.

G4CF=post DIPS2 flow with the water condensed out, consisting mostly of CH4 and unreacted 1-12 and CO2 (CO2 present if water inDIPS2 section cannot absorb it), routed to fuel/co fire combustion sections of component A and B.

Introduction to drawings continued:

CRYO=Cryogenic cooling/freezing section to take flow G4C down to very low temperatures expected to -150oC to -180oC to enable the CH4 to become liquid and the hydrogen gas to remain a gas that is super cooled.

EN1=energy supply most likely electrical to power Cryogenic plant. HC=coolant inflow (in circulation circuit i.e. with HO) HO=coolant outflow (in circulation circuit i.e. with HC) that could contain heat which can be removed to be used elsewhere for e.g. the pre heating of fuel or oxygen feeds for combustion.

CH=Methane /CH4 as a super cooled liquid (which may need drying not shown in drawings) , to either go to store or to be used in cooling sections of component D and/or be heated back to a gaseous state to use as a fuel in the combustion components A and B or to be treated to be of a quality to be fed to a gas network grid.

CO=Outflow of any CO2 that may or may not be removed depending upon the CO2 removed by section DIPS2.This can be used as a coolant gas in component D and/or re used in the Sabatier process (or released to atmosphere not shown in drawings) H=Hydrogen gas super cooled, which can be stored, used as a coolant in electrical generators, re used in the Sabatier process to economise on hydrogen from the electrolysis bank, or combusted in components A or B.it is believed that the efficiency is better is using it to cool the electrical generators and then using it in the Sabatier hydrogen feed.

Drawings Figure 7: Schematic view of electrolysis bank F showing Key F=component F,the electrolysis bank, where water is split into its component elements of Hydrogen and Oxygen gases, by passing an electric current between electrodes suspended in an electrolyte (water or water and a salt).Or other water electrolysis process.

H2=Hydrogen gas separated from electrolysis cell reaction.

Introduction to drawings continued:

H3=Route for excess Hydrogen gas to exit from design for other uses which may need drying prior to export.

02= Oxygen gas separated from electrolysis cell reaction,(preferred to be pre heated using waste or recovered heat not shown in drawings) 03=Route for excess Oxygen gas to exit from design for other uses which may need drying prior to export. It may be used as gas coolant substance if first liquefied (not shown in drawings).

SLO=CaCo3 (calcium carbonate solids) removed from the electrolysis cells as part of reaction in energised electrolysis process, will be a slurry containing CaCO3 and water.

WIS=Store of water (from component D with CO2 absorbed to create a carbonated water) or water from external supply (not necessarily carbonated and if the making of CaCO3 in the electrolysis cells is not required, could be plain de mineralised, de carbonated water).

CAO=The flow of CaO (calcium oxide) added to the carbonated water flow feed into the electrolysis cells (or into the electrolysis cells electrolyte directly), to react during the energised electrolysis process, with the CO2 absorbed in the water feed,to produce CaCO3 and improve the efficiency of the electrolysis cell, by creating an enhanced ionic reaction. If CaCo3 is not to be made, then CaO need not be added and the electrolysis cell can be run with or without a salt added, It is preferred that the system is run using CaO as the feed water could/will be carrying carbonates, which without CaO or another salt choice will decrease the cell electrical efficiency and may damage one or both electrodes by deposits and build-ups.

EI=Electrical inputs to energise the electrolysis bank/cells/electrodes from renewables or on site generation.

ii) Details of optional CaSO4 production system Key: SLO=CaCO3 slurry from electrolysis cells

Introduction to drawings continued:

X=CaCO3 store/processing CaCO3=route for CaCO3 product being dried CaCO3B=CaCO3 slurry route to reaction vessel Y SO2=Sulphur dioxide gas in feed to reaction vessel Y WS=Feed from post combustion products filter containing ash/char (modification as shown in drawings figure 3) Y=reaction vessel containing slurry composed of CaCO3 and WS, through which SO2 gas is bubbled through, chemical reaction CaCO3+502----3CaSO4+CO2 Y1=outflow/store of CaSO4 from reaction vessel y Y2=outflow/store of CO2 from reaction of CaCO3 with SO2 Drawings figure 8: Showing option to introduce and external source of CO2 and or CO2/ water vapour and/or any heat source containing vapours/gases/solids not detrimental to the equipment or processes or operation of the design.

i) Component key Z= fuel source D1= Methane supply, possibly dried and heated using recovered heat. F1=oxygen supply (from water electrolysis bank component F not shown) A=primary combustion chamber/section fed by fuel Z and/or combination of fuels and (if required Dried and heated Methane fuel supply D1), and heated oxygen supply Fl to provide heat energy for boilers or multiplicity of boilers to raise steam. (Or gas turbine or reciprocating engine to make electrical energy if fuel Z is suitable i.e. gaseous or liquid fuel) possibly at High internal pressures, and post combustion flue product flow Gl..

Introduction to drawings continued:

AS=Supplemental or additional source of CO2 and/or CO2 and water vapour and/or any other source of CO2 or heated material composed of solids,liquids or vapours that is not detrimental to the equipment or processes of the design, such as exhaust from a cement production kiln or rotary kiln.

AS1=flow from AS ii)Component Key A=Combustion component A or multiples thereof B=Combustion component B or multiples thereof. G2=post combustion section B products flow C= Heat exchanger or multiplicity of heat exchangers to recover heat and/or integral flue turbine or multiplicity of integral flue turbines powered by the velocity/pressure of the direct flow of products G2 becoming outflow G3.

AS=Supplemental or additional source of CO2 and/or CO2 and water vapour and/or any other source of CO2 or heated material composed of solids,liquids or vapours that is not detrimental to the equipment or processes of the design, such as exhaust from a cement production kiln or rotary kiln.

AS1=flow from AS Drawings figure 9: Variations and modifications showing some suggested arrangements of components A, B, C and D in series and modes of operation, as well as combustion choices that can be used in series. It is assumed components other than atmosphere AT can be multiplicities thereof. Components A,B, ABST,BBST,AGST and BGST fuels can be combusted with oxygen rather than air drafting and products are contained within a continuous/connected flue. Steam or gas turbines are assumed to have a rotational output shaft to rotate electricity generators (or rotate a mechanical drive). Key A=component A, primary combustion B=component B, secondary combustion

Introduction to drawings continued:

C=component C, heat recovery section D=component D, cooling section AT=release to atmosphere ABST=component A primary combustion as Boiler and steam turbines BBST=component B secondary combustion as Boiler and steam turbines AGST=component A primary combustion as gas Turbines BGST=component B secondary combustion as gas Turbines i) Component A where combustion takes place and post combustion flow transferring to component B, where secondary combustion takes place,the and post combustion flow to component C and then from component C the flow enters component D. ii) Component A where combustion takes place (secondary combustion is absent) the post combustion flow then going to component C and then from component C to enter component D. iii) Component A where combustion takes place and post combustion products flow transferring to component B, where secondary combustion takes place,the and post combustion flow to component C and then going from component C, the flow exits to the atmosphere AT.

iv) Component A where combustion takes place (secondary combustion is absent) the post combustion flow then going to component C and then from component C, the flows exits to the atmosphere AT.

v) Component ABST is where combustion takes place in a boiler to raise steam the post combustion flow transferring to component BBST where secondary combustion takes place takes place in a boiler to raise steam the post combustion flow transferring to component C and then from component C to enter component D. vi) Component AGST where combustion takes place within a gas turbine, the post combustion flow products then transferring to component BGST where secondary combustion in a gas turbine takes place the

Introduction to drawings continued:

post combustion flow transferring to component C and then from component C to enter component D. vii) Component AGST is where combustion takes place within a gas turbine, the post combustion flow transferring to component BBST where secondary combustion takes place takes place in a boiler to raise steam the post combustion flow transferring to component C and then from component C to enter component D. viii) vi) Component AGST where combustion takes place within a gas turbine, the post combustion flow products then transferring to component C and from there to BGST component where secondary combustion takes place within a gas turbine,the post combustion products flow transferring to an additional component C and then entering component D. Drawings figure 10: Variations and modifications showing further arrangement of a traditional air drafted combustion unit and series connected oxygen/fuel combustion units, where the post combustion products are transferred to sequential combustion units in a contained flue.

i) Traditional air drafted single combustion system with the post combustion flue products passing through a particulates or chemical scrubber cleaning device, before exhausting to atmosphere. Key:

AD=Air Drafting (oxygen for combustion is drawn as a mixed constituent of air) Z=fuel supply, to combustion chamber COM CLH=post combustion cleaner/scrubber to remove ash/char or neutralise certain products /heat recovery.

E=Exhaust flow ATM=Atmosphere ii)Series combustion units using oxygen and fuel combustion,where post combustion products are transferred to a subsequent combustion unit,the final combustion unit transferring its flow to a heat recovery component C and then to the cooling component D.

Introduction to drawings continued: Key:

OX=oxygen gas supply (preferred as pre heated) Z=Fuel supply COM1=ft in series combustion unit COM2=2"d in series combustion unit COM3=31d in series combustion unit C=Heat recovery component C D=Cooling component D iii) Series combustion units (showing a shorter inter component transfer design),using oxygen and fuel combustion,where post combustion products are transferred to a subsequent combustion unit,the final combustion unit transferring its flow to a heat recovery component C and then to the cooling component D. Key: OX=oxygen gas supply (preferred as pre heated) Z=Fuel supply COM1=1st in series combustion unit COM2=2nd in series combustion unit COM3=3rd in series combustion unit C=Heat recovery component C D=Cooling component D Drawings Figure 11: Variations and modifications showing other designs and arrangement of combustion units as a series combustion process, where primary combustion units are arranged to transfer there post combustion product flows, within a contained flue, into a larger secondary combustion unit. Steam or gas turbines (not shown in drawings) are assumed to have a rotational output shaft to rotate electricity generators (or rotate a mechanical drive).

i)Arrangement of 5 GST units (could be more or less individual GST units) fuelled by fuel input Z and oxygen supply OX,combustion taking place in the primary units GST which are gas turbines,the post combustion flows of the

Introduction to drawings continued:

GST units being contained within a flue and transfer into the secondary combustion unit BST, fed by fuel input Z and oxygen supply OX, where secondary combustion takes place in a boiler to raise steam,the post combustion product flow being conveyed within a flue to the heat recovery component C and then onto cooling component D. Key: Z=Fuel supply OX=oxygen supply GST=combustion unit gas turbine BST=combustion unit boiler to raise steam C=Heat recovery component C D=Cooling component D CO2=Carbon dioxide output CH4=Methane output ii) Arrangement of 5 BST1 units (could be more or less individual BST1 units) fuelled by fuel input Z and oxygen supply OX in the primary combustion units BST1 which are boilers to raise steam for steam turbines, the post combustion flows of the BST1 units transferring into secondary combustion unit BST2 which is fed by fuel Z and oxygen supply OX and is also a boiler to raise steam to power steam turbines. The post combustion flow of BST2 then transferring to the heat recovery component C and then transferring to become the feed for component D cooling component. Key:

Z=Fuel supply OX=oxygen supply BST1=primary combustion unit boiler to raise steam for steam turbine

Introduction to drawings continued:

BST2=secondary combustion unit boiler to raise steam for steam turbine C=Heat recovery component C D=Cooling component D CO2=Carbon dioxide output CH4=Methane output Drawings Figure 12: Variations and modifications to show a remote water electrolysis plant design to supply Hydrogen to feed a Sabatier reaction (or other use) some distance away and/or network, and to supply oxygen to a body of water (or other use) to oxygenate the said body of water. A further design to show a remote water electrolysis unit supplied with CO2 and with an energy supply to run/operate a Sabatier unit and cooling process/further processing to make CH4 to liquid or to feed gas to grid and to supply oxygen to a body of water (or other use) to oxygenate said body of water.

i) Simple drawing of a remote water electrolysis unit that has feeds of electrical energy and water, to feed electrolysis cell that electrolyses water to make elemental gases oxygen 02 and hydrogen H2, the Oxygen taking a route to oxygenate a body of water (or other use) and the hydrogen being piped to supply a Sabatier process at a power station, hydrogen network or other use. Key:

W=water supply (preferred demineralised) EE1=Electrical energy supply (preferred a renewable source) H2=Hydrogen gas output O2=Oxygen gas output EL=water electrolysis unit ii) Schematic drawing showing a remote water electrolysis unit combined with a Sabatier process and cooling unit being able to

Introduction to drawings continued:

optionally make CH4 to supply a gas grid or make liquefied CH4 using a cryogenic freezing plant (or other method of CH4 liquefication) and make solid CO2 in a separate cryogenic plant or release CO2 to atmosphere.CO2 gas being fed by pipe from a power station combustion unit or other source. Gaseous CO2 is fed from a source CFCP to a Sabatier process (powered by energy source EE2 which may be electrical preferred as renewable, but could also be heat from another source),where gaseous CO2 is combined with gaseous H2 (at temperature and pressure required) to produce CH4,CO2,H2 and water vapour, the post Sabatier flow then going to a DI section (a pre cooling section may added if required, not shown in drawing figure 12) ,which is a vessel filled with water ice, the post Sabatier flow then coming into direct contact with the water ice, to condense out the water vapour into liquid which exits the DI unit as flow WO. The cooled CH4, CO2 and H2 gases then are separated where possible, either by route FF to a cryogenic freezing component CRYO where CO2 is separated, gaseous CO2 from the CRYO function being then either returned to the Sabatier reaction CO2 input, or to CO2 supply to AT atmosphere or to CF cryogenic process to make solid CO2.H2 gas from the CRY() section if separated can also be returned to the Sabatier reaction via flow H2.The CRY() component also making liquefied CH4.Gases exiting the DI section can also be routed to gas grid feed G (with suitable processing,not shown in drawings figure 12). Hydrogen is made by from water electrolysis unit EL fed by electrical supply EE1 (preferred a renewable electrical source), which electrolyses water from water supply W (preferred demineralised water) to elemental Hydrogen and Oxygen gases,the Hydrogen being fed to the Sabatier reaction and the Oxygen being fed to oxygenate a body of water (or other use). Key:

W1=water supply (preferred demineralised) for making water ice EE1=Electrical energy supply (preferred a renewable source) H2=Hydrogen gas output 02=Oxygen gas output

Introduction to drawings continued:

EL=water electrolysis unit CFCP=carbon dioxide supply from remote source e.g. exhaust from power station.

SAB=Sabatier reaction chamber/heat exchanger EE2=energy source likely to be electrical, but may be heat or recovered heat from another process Dl=unit to bring post Sabatier products flow into direct contact with water ice introduced into the vessel (without affecting pressure integrities of the flow) FF=post Sabatier products flow consisting of CH4, H2 and CO2 CRYO=Cryogenic processing plant to separate CO2, then produce liquefied CH4 and cool gaseous H2.

CO2=carbon dioxide flows CO2 as gas G=Input to the gas grid/network CF=Separate cryogenic processing plant for CO2 SC=Solid carbon dioxide to store AT=Release of CO2 to atmosphere LCH=Liquefied methane CH4 to store Drawings Figure 13: Modifications and variations. Cross section of two differing use suggested designs of the water ice cooling column/vessel found in unit DI (in drawings figure 6, figure 12 and figure 14) and DISP (drawings figure 6), a section of the larger cooling component D.Water ice (preferably demineralised) is introduced into the top of the vessel from IM at a continuous rate sufficient to keep the vessel full of water ice I. The cooled gases (mostly CO2) and water vapour as flow GF1 or GF2 enters the bottom of the vessel, the ice held by a perforated tray with the melt water collecting beneath as MI (shaded area) and exiting the vessel as flow WO, the flow GF1 or GF2 passing up through the water ice column condensing out water and allowing CO2 to be dissolved into water/water ice. Gases H2 and CH4 if present do not dissolve into water and can therefore pass through the water ice column without being dissolved, some or all (depending upon sizing and CO2 present) of the CO2 can be removed by this method although it is expected that large flows of post

Introduction to drawings continued:

Sabatier products would have flows containing amounts of CO2 that could not all be absorbed, requiring removal of CO2 by another method, prior e.g. to CH4 liquefication.

i) Drawing of a cross section through a suggested vessel design for a post Sabatier products flow contact with water ice. The flow GF1 is thought to consist of water vapour and gases CH4,H2 and CO2,passes into the lower part of the vessel, and up through the water ice column,CO2 being absorbed into the water and the CH4 and H2 passing up through the vessel to exit as flow C,to go onto further processes. The water vapour from the post Sabatier flow GF1 condensing out, with water ice I to produce the melt water MI, which exits the vessel as cold water flow W01. Key:

Wl=water in feed, preferred demineralised EE1=electrical supply preferred a renewable source IM=Water Ice maker, crushed, flaked or shaped 1=water Ice GF1=Mixed gas/water vapour stream of CH4, H2O vapour, 112 and CO2 MI/shaded area=liquid Water ice melt/condensed water vapour WO1=outflow of cool liquid water from vessel C=outflow of CH4 and H2 gases with little CO2 gas or none ii) Drawing of cross section through a suggested vessel design to cool a flow of mainly CO2 and water vapour H2O, by direct contact of product flow with water ice The flow GF2 passes up through the ice column and over flows into a none water ice compartment, the water vapour being condensed out and the flow mostly being cooled CO2 gas, exiting the chamber as flow COO. Melt water and condensed water vapour, falls to the bottom of the vessel as liquid MI exiting the vessel as flow W02.

Introduction to drawings continued: Key:

Wl=water in feed, preferred demineralised EE1=electrical supply, preferred a renewable source IM=Water Ice maker, crushed, flaked or shaped 1=water Ice GF2= CO2 gas/water vapour stream MI/shaded area=liquid Water ice melt/condensed water vapour WO2=outflow of cool liquid water from vessel COO=overflow and outflow of CO2 gas Drawings Figure 14: Modifications and variations Shows a suggested alternative design for a system of processing the post combustion flow into CO2 gas and or to a cryogenic freezing process to make CO2 (solid).The post combustion products flow, cooling section (or component D in drawings figure 1) uses the similar aspects of the unit processes,as shown in drawings figure 6, in that the post heat recovery section/and or post combustion products flow, (composed of hot gases and water vapour) is flow G3,entering unit DG1 which is a gas heat exchanger,the coolant in feed being flow Gil and the coolant outflow as 601,the coolant gases being either H2,02,CO2 or CH4.The post combustion product flow through DG1 becoming flow G31 which enters a second gas heat exchanger DG2, with coolant inflow GI2 and coolant outflow GO2, the coolant gases being either 112,02,CO2 or CH4.The post DG2 unit flow becoming flow G32 entering the unit DW,which is a water cooled heat exchanger, fed by cool/chilled water inflow WI and exiting as flow WO. The cooled post combustion products flow exiting DW becomes flow G33 entering into unit DI which is a vessel capable of continuous filling of water ice as required, flow G33 being introduced at the bottom of the ice water column and coming into direct contact with the water ice,made by

Introduction to drawings continued:

water input DMII, condensing out the water vapour as liquid water which exits the vessel as flow WO2 (and can be used as inflow water coolant input WI to DW unit) ,to leave a flow mostly of cooled CO2 gas, which can either exit the unit DI through the DICO route (which could be CO2 gas to atmosphere), or exit the DI unit as flow G34 going to the CRY() unit (fed by energy input EN1,which is preferred as renewable electricity, which could also be a heat exchanger to recover heat) , where the cooled CO2 is taken down to temperatures to make frozen CO2 solid (suggested as -80oC,but other temperatures and pressure as required),It is assumed that heat produced when cooling can be recovered to use elsewhere e.g. to pre heat fuels. This cooling component design enables a combustion plant to manage CO2 flows as part can go to atmosphere and part can be made into a solid that can be exported for use in other processes e.g. as a coolant. Key:

G3=post combustion products flow entering DG1 DG1=gas cooled heat exchanger G11=gas coolant inflow into DG1 suggested as H2, 02, CO2 or CH4 gases

Introduction to drawings continued:

GO1=gas coolant outflow from DG1 G31=post DG1 product flow to DG2 DG2=gas cooled heat exchanger G12= gas coolant inflow into DG2 suggested as H2, 02, CO2 or CH4 gases GO2=gas coolant outflow from DG2 G32=post DG2 product flow to DW DW=water cooled heat exchanger Wl=coolant water input to unit DW

Introduction to drawings continued:

G33=post DW product flow to DI DI=direct water ice cooling vessel DMII=water inflow to DI to make ice solid water DICO=outflow from DI unit if required of cooled CO2, if required to atmosphere G34=post DI unit flow, mostly of cooled CO2 gas CRYO=cryogenic freezing unit to make CO2 gas to CO2 solid SCO2=solid CO2 output EN1=energy input preferred as a renewable source, could also be a heat exchanger Drawings figure 15: Modifications and variations i) Shows a suggested large volume oxygen supply device using atmospheric air intake from a tall column structure WP which has an internal cluster of reducing height pipe intakes,enabling air to be drawn in at segmented heights of the vertical column (rather than just one point) .having also an external weather cover which could be louvered or perforations. Atmospheric air ATM is draw by a fan located in the air filtration unit FT, which also filters the air from particulates and could also dry the air, powered by electrical supply EE1 which is suggested as renewable electricity supply. The air flow from the FT unit then goes to the air separator unit AS which (using either micro filter separation and/or pressure swing technology) separates the oxygen from the air to give supply/flow OG which is then put to store 550, which has the outflow FIX whereby the oxygen is pre heated for use in the combustion processes/units. The air separation unit AS also has an output flow NOG of the non-oxygen constituents of air (mostly Nitrogen) which can be sent for other processes e.g. ammonia manufacture.

Introduction to drawings continued: Key

WP=tall column induction of air device, enabling air to be drawn in through a protective weather shield, to tubes of graduated height to draw atmosphere at various points of height (rather than one individual point) ATM=atmospheric air drawn into the device WP FT=filter of air drawn in, and fan or system to draw air EE1=electrical supply to supply unit FT (and air separation/oxygen supply system in whole) preferred as renewable electricity supply. AS=air separation device,to separate oxygen from other constituent gases of air, suggested as micro filter or pressure swing technology, but could be other method such as cryogenic separation. NOG=outflow from device AS mostly composed of non-oxygen constituents of air (mostly Nitrogen) OG=oxygen gas flow from air separator unit AS SSO=store of gaseous or liquefied oxygen, preferred gaseous HX=outflow of oxygen store SSO, of oxygen gas to be pre heated for the combustion process ii) Drawing showing suggested dispersion unit for large volumes of CO2 to be released to atmosphere, from processes such as combustion of fuels, or other processes. Flow FC is CO2 gas to a store CCO2, which may also have a fan to push the CO2, powered by electrical supply EE1 preferred as renewable electrical source. The CO2 gas flow COG then being forced by pressure to rise up the tall exhaust column (it could also be drawn up by air movement effects at the top of exhaust column e.g. the venturi effect), the CO2 gas then overflowing from the top of the exhaust column, into a space/chamber which has a weather protection outer shield that may be louvered or perforated, to allow for the dispersion of flow COG to the atmosphere ATM. By dispersion of a heavy gas such as CO2 to height in tall exhaust, that allows the gas to spread, in a more even dispersion should be achieved of at dense gas at volume. Key

FC=supply of CO2 gas (preferred with water/water vapour removed) CCO2=store of CO2 gas with possible fan to drive CO2 in flow out of store CCO2 EE1=electrical energy supply to drive system, preferred as a renewable supply.

COG=flow of CO2 from CCO2 up through exhaust column to the dispersion chamber/space, to exit through perforations/louvres to atmosphere.

ATM=atmosphere

Claims (14)

1. Claims: 1 That this device/system of energy combustion and production has four main component sections A,B,C and D that run consequentially in series and are connected to make a continuously operating system with modes of operation that are useful and not found on current electrical power generation systems. The basic technical system as follows Component A:Primary combustion,where any solid,liquid or gaseous fuel,and or combination of such fuels,is fed into a combustion chamber,to be combusted with Oxygen to produce heat,electrical energy and post combustion exhaust products She preferred method for component A is a combustion chamber that is also a boiler or multiples thereof,to raise to steam at pressure,the said pressured steam then causing a steam turbine to rotate or multiples thereof,the said steam turbines rotational output then rotating an electrical generator or multiples thereof,to generate electrical power.Component B being a secondary combustion chamber/boiler or gas turbine to combust a solid, gas or liquid fuel with oxygen to produce heat, electrical energy and post combustion products with an exhaust contained within a flue The preferred method for component B and multiples of B, is a combustion chamber that is also a boiler or multiples thereof,to raise to steam at pressure,the said pressured steam then causing a steam turbine to rotate or multiples thereof,the said steam turbines rotational output then rotating an electrical generator or multiples thereof,to generate electrical power.The option to use a gas turbine in component A or B or multiples of B in sequence of parallel or series arrangement,for liquid or gaseous fuels, with oxygen fuel combustion,operates by the combustion of fuel/oxygen to create high pressure post combustion vapour/gas stream, which is directed to the turbine blades/shaft,the pressure/expansion upon the blades causing the said turbine to rotate, the rotational output shaft of the gas turbine then rotating an electrical generator to produce electrical power. That the exhaust of component A combustion process is contained within a flue continuously from the said boiler/combustion chamber/gas turbine and is routed to feed an inlet into component B boiler/combustion chamber/gas turbine (or multiple inlets of component B), providing a heat source /heat transfer/flow of combustion Claims continued: products, from component A,thereby reducing what are some times termed "stack losses" which is lost heat in the exhaust,where said exhaust goes to atmosphere. This design /construction feature of a continuous flue from combustion chamber/boiler or gas turbine is repeated to any repeat/multiple of inlets component 81 to B2, B2 to B3 combustion chamber/boiler or gas turbine so connected in consequential series, or parallel to series, or series parallel as required. This designs is thus one of series multiple combustion stages or units, but with the post combustion exhaust connected to an inlet of the next subsequent combustion chamber, boiler or gas turbine, that utilises the exhaust heat and its heat transfer and post combustion products to give a heating effect to the next combustion chamber, boiler or gas turbine until no further combustion chamber, boiler or gas turbine, exists, whereby the accumulated post combustion exhaust/products enter the heat recovery component C which is a continuation of the exhaust flue containing the accumulated combustion heat and products. The heat recovered can be used to heat oxygen and fuel feeds, pre use in combustion sections, thus enabling recovered heat to be fed back into the combustion component, boiler or gas turbine, giving another thermal efficiency improvement and reducing the amount of fuel per kg used, per kw of electricity produced. Additional electrical power production can take place also with a turbine so placed within the flue/exhaust stream, the velocity/pressure of said exhaust stream, causing a turbine to rotate, the rotational output of the turbine (passing to the outside of the containment flue see drawings 5 ii and iii) , rotates an electrical generator to make electrical power, and or a steam circuit using a counter current flow (see drawings 5 i) to make pressured steam to power a steam turbine to rotate, the rotational output of which rotates an electrical generator to produce electrical power.From component C the post combustion products stream still within a flue/containment running continuously, proceeds to component D which is composed of a cooling and water removal section using cooling stages and a stage of direct contact of the post combustion products with water ice (Preferably demineralised), in a continuous flow. The now post combustion products flow, has water removed and will mostly be composed of CO2 (which Claims continued: can be stored in balance tanks if required not shown) ,this flow then goes to a Sabatier process/methantion unit where it is mixed with Hydrogen gas and taken up to temperature and pressure as required to facilitate the Sabatier reaction, which is CO2+4H23CH4 +2H20 in chemical 100% formulae,the now post Sabatier /Methantion unit flow should be cooled at temperature and pressure as required to not allow for decomposition of the CH4 and then be cooled in a similar procedure to the flow from component C, passing through a water ice column to condense and remove water (preferably demineralised) in a continuous and contained flow, the post Sabatier reaction products with the water and CO2 removed and cooled then go onto a cryogenic/freezing section to separate out the variable post Sabatier gaseous products not absorbed or can be dissolved in water, where temperatures are reduced and taken to the liquefication point of methane CH4, the point of liquefication of CH4 is still not low enough for the liquefication of Hydrogen which remains a gas and can be removed as a gas. The heat produced by the ice production and cryogenic freezing can be recovered enabling further heat efficiencies such as heating fuel or oxygen prior to combustion thereby putting heat not previously available in the liquefication of CH4 and cooling of hydrogen back into the combustion thermal balances, resulting in better thermal efficiency and reducing the fuel per kg used per kw of electricity produced.
2. 2 That CO2, (unlike Hydrogen and Methane) is soluble or absorbed in water, producing a slightly acidic carbonated water, which can be removed and used as a coolant and/or water supply as electrolyte to one or multiple electrolysis cells. This process taking place in the condensed water vapour and interaction with the iced water (preferably demineralised) of the iced water sections of component D, that treat the post combustion flows exiting component C and the post Sabatier/methantion process. In the post combustion flow prior to the Sabatier process the iced water section is mainly to cool and cause the water vapour so present to liquefy, In the post Sabatier/Methantion product flow, the iced water section seeks to cool the flow prior to the cryogenic freezing separation, but its preferable function is to also remove any residual CO2 that may be present from unreacted products within the post Sabatier flow.That Claims continued: said water recovery greatly improves water usage in electrolysis requirements and other requirements,enabling such energy systems to be placed in low/variable water availability situations, compared to similar electricity generation or Sabatier/methantion process/plants/systems.
3. 3 That the water so described in claim 3 when used for the water electrolyte in one or multiple electrolysis cells can have a salt added (in the example preferred this is given as Calcium Oxide /CaO) to create an ionic electrolyte which improves the electrical conduction processes/chemical ionic steps of the electrolysis steps to produce elemental Hydrogen/H2 and Oxygen/02 gases, by the disassociation of water/H2O, that is achieved by the know process of electrolysis where an electrical current is passed between two electrodes suspended in an electrolyte (or other process of water electrolysis or water disassociation) , the gases forming separately at the separated electrodes when energised as electrical circuit in accordance with the principals of electrolysis.
4. 4 That water so described in claim 2 and 3, with a salt added (CaO) containing dissolved CO2, when electrolysed not only improves the electrical conduction processes/chemical ionic steps, by creating an ionic electrolyte, but that in energising the electrolysis cell CaO is converted into Calcium Carbonate CaCO3 which forms a solid on one of the electrodes.When the said CaCO3 solids are removed from the electrolysis cell, can be used as CaCO3 or further process into CaSO4 (Calcium sulphate) by reaction with Sulphur Dioxide (S02) ,CaSO4 being a form of cement.
5. That by arranging the combustion units in series, connecting exhaust flow products to the next combustion stage directly in a flue, so containing said products continuously is an efficient heat transfer system capable of being used where oxygen /fuel combustion is used, rather than air/ fuel combustion.Air combustion requires draughting to supply the combustion chamber/boiler Claims continued: or gas turbine, which can be at variable temperatures and requiring a large volume of air per kg of fuel burnt as the required Oxygen component of air approx. 20%.) for combustion, includes the Nitrogen component of air (79% approx.), which often leads to Nitrogen Oxides being produced (which are considered a pollutant) in air combustion process, a pure oxygen (or Stoichiometric combustion of a fuel) does not give rise to Nitrogen Oxides being produced in combustion (other than those in the fuel) due to the introduction of Nitrogen gas in the air used.
6. 6 That by arranging the combustion units in series, connecting the exhaust flow products to the next combustion stage directly, in a flue so containing said products continuously can enable a pressurised internal flue flow products system, that accumulates in mass and post combustion products as it flows out of each combustion stage. The post combustion products being preferably water and CO2 can be achieved, as oxygen and not air is used, giving control of combustion. Post combustion products will also be dependent upon the chemical composition and decomposition in combustion of fuels so used. The opportunity to use a pressurised continuous combustion flue products flow enabling potential extra electrical power generation opportunities not used in current designs, that being a turbine or turbines being powered by the pressure/velocity of the flue/contained products, at intermediate to the combustion stages of A to B or B to B units or the component C stage of the whole system. This enables a greater electrical output per kg of fuel burnt if used, than other electrical power stations of current design and is a useful inventive step and step change only available in this energy system design.Given water vapour is a component of the flue exhaust products, the accumulation of water vapour in such series multiple stages of combustion will be considerable in some designs at the final post combustion stage, pressures/velocities within the flue containment may be high, it also known that water carries latent heat and this device claims that the final post combustion will (by mass/volume) carry considerable amounts of heat to be recovered and may be enough to power a closed cycle steam electricity generation unit on its own (as in drawings 5 i) or the heat can be used and/or to pre heat fuels and or oxygen prior to combustion in components A or B (or Claims continued: multiples of B), thereby improving the combustion section boiler or gas turbines thermal efficiency, and resultant steam turbine, gas turbine electrical output efficiency per kg of fuel so combusted.The auto ignition temperature of the fuel Methane being particularly of use in this aspect, as it is high enabling it to be a carrier/transfer of good heat amounts as well as a combustion fuel source.Oxygen whilst not a fuel as such in the meaning of combustion, can also be heated to high temperatures giving a useful heat input /transfer ability of this system design in that both Oxygen and fuel can be pre heated, with recovered heat and inputted into the closed/sealed combustion units possibly at pressure. dependent upon the pressures of the internal flue flow system and combustion sections, allowing heat losses in combustion systems for electricity production to be greatly reduced when compared to other designs, giving an inventive step and step change in such combustion electrical plants efficiency.
7. 7 That Component D, can cool post component C combustion flows and post Sabatier/methantion unit product flows,by a combination of separated flows heat exchange with cold gases, cooled water and can also remove water vapour by reducing the temperature to the formation of liquid water and by passing said flows to direct contact with water ice (preferably demineralised) to create/collect cooled liquid water, to be removed and used as coolant and/or electrolyte in the electrolysis cell or multiples of electrolysis cells.
8. 8 That component D has a post Sabatier/methantion flow that may contain a mixture of synthesised CH4 and H2O and also unreacted CO2 and H2, as the Sabatier reaction is not 100% efficient based on collected data.CO2 is soluble into water and it is thought that the unreacted CO2 from this unit could be absorbed by a suitably sized direct water ice contact process giving the benefit of producing a post Sabatier product stream with the H2O removed and also the CO2 removed,prior to the cryogenic freezing separation unit simplifying the cryogenic freezing separation process to handling just the CH4 and H2 products and or creating a Hydrogen rich CH4 fuel which if used in one or more components A and B and multiples of B, would give an increase in said fuel calorific value and heat produced by said fuel mixture in combustion,if the pre heating performance/ability of said H2/CH4 mixture could be high enough to Claims continued: equal the performance of the high auto ignition temperature of Methane on its own as a fuel It is felt that separated Hydrogen is better used or re used in the Sabatier reaction feed, and or as a electrical generator gas coolant and then re used as a fuel or for a Sabatier reaction feed.
9. 9 That components A and B and multiples of B components can combust any solid, liquid or gaseous fuel with oxygen in an oxy combustion process. However as CH4 is being made/synthesised by a Sabatier/methantion process that can react Hydrogen gas with CO2. Fuels that combust to make CO2 exhaust products are desirable.That the said synthesised CH4 can be used as fuel taking advantage of its form as a gas to give efficient and controlled combustion, producing CO2 and H2O from said oxy fuel combustion from said pure/dried synthesised fuel,in efficiencies known to be greater that those obtained from some other physical and chemical fuel types.This property of Methane (and some other gaseous fuels) in giving better boiler or gas turbine heat production and combustion efficiency gives a preferred use of said methane as either co firing, in component A to use this combustion efficiency to combust more efficiently, less combustion efficient fuels by use of its heat and dispersion in the combustion zones, and as a single fuel in component B or multiples of B as this gives a secondary efficiency of the high temperature of CH4 and Oxygen combustion,possible converting any remaining unburnt particles from component A in secondary combustion, to the desired CO2/H20 rather than unburnt/unconverted/uncombusted fuel particles remaining in component B post combustion streams. This higher temperature per kg of the methane gaseous fuel burnt (higher still with pure Hydrogen as fuel) and combustion efficiency, if using boilers to make steam, greatly increases boiler efficiency and therefore steam output per KJ/Kg of fuel giving a second stage combustion and steam generation,and or gas turbine power output and electrical power output generation, improving the amount of KJ of heat to make the same amount of steam,or gas turbine power output.By using the series connected units of combustion as described in claims 1 it enables an initial fuel, such as a solid fuel like biomass or tyre crumb, or liquid fuel such as alcohol or oils or fossil fuel, which is possibly a little less Claims continued: combustion efficient than a gaseous one in oxygen, to be combusted without much concerns about component A exhaust emission composition, as it resolves to a better exhaust component composition in component B combustion stages, or multiples of component B in connected series, giving a post final combustion stage exhaust composition of mainly water vapour and CO2, a considerable advantage/improvement over systems using only one combustion unit to feed a Sabatier process or other process where uncombusted fuels may be a problem,in subsequent products and processes. It is considered that component A fuel selection should be a solid or liquid, and or co fired with Methane, and that component B and/or multiples of component B use Methane as fuel, the efficiency of the combustion within, boilers, gas turbine also meaning more heat for less CO2 is produced, reducing the Hydrogen requirement for the Methane synthesis/Sabatier process, than if the fuel used were less efficient in complete combustion than a gaseous fuel.It is known that inlets for gas turbines if receiving an unfiltered air stream (noting this device uses oxygen) the particles can damage the turbine blades reducing performance, it is therefore not recommended that a post combustion flue flow from component A, that has unburnt fuel particles or other particulates, feed a secondary component B as gas turbine power generation due to damage that may occur to said gas turbine blades. However subsequent component B units in series could work as gas turbines, although it is felt Boilers and steam turbines to rotate electrical generators will offer the highest efficiency of kg of fuel used to kw of power generated.
10. That this system and specific design of continuous multiple combustion units as described in claims 1, can continuously generate high amounts of electricity and as the component D function is post all combustion steps/process that CH4 can be produced continuously in a methane synthesis/Methantion at amounts dependent upon the fuel burnt quality and quantity. This is an improvement on systems on systems which combust and store CO2 and is an inventive step improvement on such systems, or any power stations currently in use, as it not only converts CO2 into a useful fuel CH4, but effectively increases the possible power output per initial kg of fuel used, as the exhaust product of CO2 can be made into a fuel using Hydrogen, Claims continued: thus we can make fuels from current resources, rather than combust/burn fossil fuels, water being a source of hydrogen when electrolysed into its component elemental gases. It negates the current thinking that for more power, more fossil fuel must be burnt, whereby converting the exhaust CO2 to a fuel, from a source not a fuel (water) enables the initial fuel power output to be extended. As CO2 is converted in CH4 in the final stage component D, post combustion, it can be claimed that this plant emits zero or little CO2, and further that synthesised CH4 not used by the system effects to make CO2 emissions of said synthesised CH4 when combusted (in e.g. an engine or domestic gas boiler putting exhaust to atmosphere), that said CO2 so formed is of a carbon neutral property as (if initial fuel is biomass or biofuel or bio derived not so classed as fossil fuel,in that the fuel source has captured CO2 by natural photosynthesis and does not therefore add to CO2 imbalances that fossil fuels are accused of doing, and therefore reduce the problem of global heating/warming, water acidification for which elevated CO2 levels, from combustion of non-photosynthetic derived fuels to atmosphere are often cited.
11. 11 The specific design operation of using a series connected combustion units of component A and component B and multiples in series of component B enables a high level of heat transfer directly to subsequent combustion stages, coupled with the heat recovery from component C to pre heat fuel and Oxygen prior to combustion adding to thermal efficiency performance, coupled with heat recovery from component D operations, including water ice making and cryogenic freezing/separation process that further heat can be recovered in the making of the end products of liquid CH4 and very cold Hydrogen (and CO2 and Oxygen if required for process improvement/function), which gives a heat recovery from the use of ice water and cryogenic freezing separation not only when such substances are used as coolants, but acts as additional heat recovery to the system e.g. if used in pre heating of fuel or oxygen, gives a heat use efficiency not available to current designs of combustion electricity production plants, giving considerable heat recovery improvements in the energy used to make liquefied CH4 or separate H2 from a mixed post Sabatier Claims continued: process stream. Pre heated fuels and/or oxygen can be heated to different temperatures as required e.g. if a combustion process burning a difficult fuel such as tyre crumb the oxygen feed and or any gaseous fuel feed,temperature can be increased/varied to help this or in any other combustion unit.It is calculated that 1000kg per hour combusted of biomass in the specific design of this system will generate in excess of 600MW/hr of electrical energy and a useful quantity of liquid CH4 as a product (to be used as fuel directly in system or put to store) This is nearly double the electrical power output of any biomass energy plant burning/combusting the same quantity of biomass to exhaust to atmosphere in an air /fuel combustion process and as specific design is more efficient per kg of fuel combusted per kw of electricity produced than any non-continuous designed combustion energy system yet designed, having also a CO2 methantion system that can be run continuously,to a high efficiency to create a continuous fuel source for use in the power plant and not be turned off and on, i.e. can be run continuously,unless in failure or maintenance.
12. 12 That the specific design benefit of connected series combustion units as described in claims 1 making use of the latent heat within post combustion exhaust flows by direct connection, this not interfering with combustion as Oxygen is supplied to enable stiochmetric combustion within a continuous flue/pipe flow process through the system, with the Sabatier/methantion post combustion and heat recovery and heat incorporation into fuels, oxygen and cooling processes is that the Sabatier/methantion can run continuously whilst ever combustion is taking place in components A or B and /or multiples of A/ B and Sabatier processes are not placed after single combustion operations/systems, enabling heat to be transferred to further heat/combustion processes, and heat recovery and cooling and water removal and Sabatier functions to perform more efficiently and recover more water per kg of fuel combusted than systems not of this design,overcoming a design problem of placing Sabatier/methantion process intermediate between combustion stages/operation. Also enabling a pressurised and combustion and Claims continued: exhaust system most probably in components A to C, component D having lower pressures (and /or pressures of product flow not being required) ,due to cooling of post component C products creating pressure differentials that would need much greater design precision, to enable functionality, that aside a pressurised continuous connected multi stage combustion system using oxy fuel combustion may give other efficiencies where by using pressure, velocity can be reduced and giving a longer dwell time for heat transfer to a design as boilers, to make steam to power steam turbines,to power electricity generators, and raise either more or higher pressures of steam and therefore more power and efficiency of said boiler and steam turbine. It is noted that heat transfer dwell time is not necessarily an efficiency of gas turbines, where high velocity of gas is required.
13. 13 That this design is primarily a zero or low CO2 to atmosphere efficient series connected combustion stage design, to make high outputs of electrical energy at a kw per kg of initial fuel burnt, more efficiently than any other combustion electricity generation system design, that the power outputs of either steam turbines or gas turbines so used in said system could power direct mechanical drives such as a wheel, cog,pulley,chain or propeller conveying the same efficiencies to mechanical movements and operations.
14. 14 That the high temperatures of oxy fuel combustion will give higher heat transfer possibilities than air fuel combustion processes or stages, giving a multi combustion stage/step system, that is connected as described in claims 1, using oxy fuel combustion, giving a dimension of thermal efficiency that compliments a multi combustion series connected system, in being able to reduce consumption overall and in initial fuel used in component A. That Oxyfuel combustion processes give a higher degree of control of the combustion process and combustion products, than a conventional air drafting fuel combustion system or process.16 That this specific design using series connected multiple stage combustion steps as described in claims 1, that an option for some modality is possible whereby a combustion section can be closed off /shut down (working with the last stage of combustion backwards towards component A as they are Claims continued: connected in series). The remaining combustion units having a method of diverting (in a contained flue at the pressures required) the exhaust products of combustion to a section component C and D.This enables the electrical output of the system to be reduced say for e.g. in summer when less electricity is being used, whilst still making synthesised CH4 as a product, negating need for large CO2 stores where electricity outputs overrides, the CH4 requirement/production seasonally or in other demand patterns. That also components A and B using oxy fuel combustion can be adjusted/reduced/increased if required to give other modality abilities if required e.g. if CH4 production (via CO2 precursor quantity from combustion i.e. fuel reduction/increase) needs to be adjusted, where CH4 stores may be full or non-useable and it has no immediate route to go to, reducing the fuel burnt in mainly component A (but also component B and multiples in series of component B) , where by this does not create an inefficiency (unless in an urgent situation) that creates/raises insufficient steam for powering the steam turbines correctly.Possible variants of this modality (not shown) are being able to redirect steam circuits to select single steam turbine or a steam turbine group, or in component A to have one or multiple units of combustion, boiler or gas turbine that are capable of a converged exhaust via a valved manifold that can open/close sections,individual combustion, boilers or gas turbines that are in use or not, whilst maintain a continuous flow of exhaust and exhaust products as described in claims 1, to component B or multiples of component B. 17 That this system with the introduction of an additional external CO2 source (see drawings 8) that may be heated or not (and that does not contain substances that may harmful to operation or products of the system.e.g. the exhaust from a cement making kiln or rotary kiln),but preferably also heated, to gain thermal transfer efficiencies could be introduced at any point from component A to component C (or pre component A not shown in drawings figure 8), when running at design parameters will create an additional Hydrogen production requirement from the electrolysis component F to synthesise more CH4 via component D Sabatier Methantion process and steps, creating an excess of Oxygen production that may not be required in the Claims continued: station designs and is an inventive step improvement to any design I have seen in theory or in use, and overcomes some problematic aspects of Oxy fuel systems,using electrolysis to create Hydrogen and Oxygen gases, and electrolysis cell efficiency and Sabatier/Methantion unit systems, by having not only a more refined operation in respect of efficiencies and CH4 production from CO2, but by placing components C and D post the series connected combustion stages (as described in claims 1), is a step change and inventive step in previous theories and real life use in operation of the technology described in these claims and the claims I have seen in other electricity generation system designs, facilitating not just pollution concerns of nonnuclear and nuclear electrical energy generation systems, or systems of mechanical power from combustion,or processing using combustion for heat or drying. If using biomass or biofuels enables a system of carbon capture, by photosynthesis making the fuel sources a system capable of combating climate change, by CO2 absorption and will therefore be an important technology in gaining the sort of energy consumption and CO2 reductions that scientific information is informing that we need to do to stop damage to the life systems of the planet that we use and rely upon for living. Cuts of up to and over 50% in CO2 emissions from energy and electrical power production and possibly transport emission effects (if CH4 is used as transport fuel or the electricity produced is used for transport), are possible if this system can be used as common practice more than other designs of such synthesised CH4, power and electrical energy systems in theory or in use since the first concept of this system of a design filed in June 2016.That in commissioning the system where synthesised CH4 from the Sabatier process is used as fuel source, will have to introduce from a tempory independent fuel store,until the process is producing CH4 from the cryogenic freezing section,that can be used, then the tempory feeds/stores can be removed, as the system will be producing CO2.21 That in certain configurations of modality and high moisture content fuel and/or external hot CO2 source, this system could produce an excess of water that could be used for example to irrigate farm crops.Claims continued: 22 That an air drafted variant of the series connected combustion system is possible, using recovered heat to heat drafted inflow air and fuel.23 That oxygen can be supplied from sources other than electrolysis, using air separation pressure swing systems, or micro filter technology of air, to separate oxygen gas from air.24 That a series combustion system as variation can be operated using oxygen sources from air, to enable oxygen fuel combustion,to gain the benefits of oxygen fuel combustion, but need not make CH4 in a Sabatier process, and instead release CO2 to atmosphere,or cool and process post combustion streams to give CO2 gas,when can then be cryogenically processed to make CO2 as a solid,which can then be used in other processes and exported to other uses.That CO2 produced in combustion, can if required, be partially released to atmosphere if required operationally, and need not all be made into CH4 in the Sabatier process.26 That CO2 from combustion on site can be exported from site as a gas via pipe and act as feed to a remote Sabatier process site to make CO2, where renewable energy and water may be more effectively and efficiently used.See modifications and variations drawings fig 12.27 That steam waste flows, such as steam drum blow down, or safety valve pressure release can be diverted into the post combustion flows (or pre combustion of component A if required) , thereby passing heat and water vapour from boilers/steam circuits,to transfer to improve thermal efficiency of the combustion sections and help in water recovery. See modifications and variations 21.