Waste processing system and method

Abstract

Disclosed herein is a syngas production system for producing syngas from fish waste, the system comprising: a gasifier; and a feedstock input that is configured to supply a feedstock comprising fish w

Description

Field of the invention The present invention relates to the processing of waste products. Embodiments include processing fish waste to generate syngas. This may be integrated with a further processes such that bio-fuel / bio-oil, hydrogen, ethanol or other products are generated in dependence on the syngas. Background to the invention A substantial proportion of the world’s population are heavily reliant on liquid hydrocarbon fuels, that have been obtained from crude oil, for transportation and other uses. A problem with the use of such non-renewable energy sources is that they substantially increase greenhouse gas emissions. There is therefore a lot of interest in the generation and use of bio-fuels / bio-oils that are not derived from crude oil. There is a general need to improve techniques for producing bio-fuels / bio-oils, as well as other products, without substantially increasing greenhouse gas emissions. Summary of the invention Aspects of the invention are set out in the appended independent claims. Optional aspects are set out in the dependent claims. Brief description of the drawings Figure 1 schematically shows an oil / fuel generation system according to a first embodiment; Figure 2 schematically shows a hydrogen generation system according to a second embodiment; and Figure 3 schematically shows an ethanol generation system according to a third embodiment. Detailed description of the invention Embodiments concern the generation of bio-oils, including bio-fuels and other useful products, from waste materials. In particular, embodiments include the generation of syngas from fish waste. Due to fish waste being a carbon source, the generated syngas may be referred to as bio syngas. The syngas may be used to generate bio-fuels / bio-oils, such as aviation fuel, green hydrogen and / or ethanol. The processes for generating fuel, and other end products, may be integrated with the processes for generating syngas. Embodiments of the present invention use steam gasification to convert waste materials into syngas. A preferred waste material is fish waste. This is a waste product from fish farms that may be obtained at low, or no, cost. Advantages of fish waste also include its low level of impurities, its abundance and its similar calorific value to woody biomass. Embodiments include using the Fischer-Tropsch (FT) process to generate fuels, such as aviation fuel, in dependence on the syngas. Embodiments also include using a sorption enhanced water gas shift process to produce hydrogen, that may be referred to as green hydrogen. Embodiments also include performing bioconversion on hydrogen rich syngas to produce ethanol. Figure 1 schematically shows an oil / fuel generation system according to a first embodiment. The oil / fuel generation system comprises a syngas generation system 100 and a Fischer-Tropsch (FT) system. The syngas generation system 100 receives a feedstock 101 and generates a syngas supply 105 in dependence on the received feedstock 101. The FT system receives the syngas supply 105 from the syngas generation system 100 and generates fuel in dependence on the syngas supply 105. The feedstock 101 may comprise fish waste, that may alternatively be referred to as fish sludge. The fish waste comprises waste products from a fish farm, such as sludge from fish farming, fish silage and / or fish manure. The fish waste may be filtered to remove any dead fish. In particular, embodiments include the fish waste comprising dewatered fish faeces and residual fish feed. Embodiments also include the fish waste substantially consisting of dewatered fish faeces and residual fish feed. Table 1 shows the composition of typical dry fish waste according to embodiments. The compositions are shown with their dry weights (dw). The results in Table 1 were obtained following an analysis of a fish waste sample. The actual composition of the fish waste is expected to vary from what is shown in Figure 1 in dependence on a number of factors, such as the conditions in the fish farm, the type of fish and the constituents of the fish feed. Analysis Component Analysis Result Unit N, Nitrogen 4.5 % dw P, Phosphorus 3.68 0 / / 0 Ca, Calcium 6.45 % Mg, Magnesium 0.50 % K, Potassium 0.11 0 / / 0 S, Sulfur 0.30 0 / / 0 B, Boron 0.011 0 / / 0 Mn, Manganese 0.029 0 / / 0 Fe, Iron 1.70 % Mo, Molybdenum 0.01 % Na, Sodium 6.70 0 / / 0 As, Arsenic 2.6 mg / kg Cd, Cadmium 0.6 mg / kg Cr, Chromium 60.0 mg / kg Cu, Copper 29.0 mg / kg Hg, Mercury 0.06 mg / kg Ni, Nickel 32.0 mg / kg Pb, Lead 0.6 mg / kg Zn, Zinc 730.0 mg / kg pH 5.3 Dry matter 94.3 % Total organic matter 76.00 % TKB <10.0 CFU / g The feedstock 101 may be dried before it is supplied to the syngas generation system 100. Accordingly, when the feedstock 101 is fish waste, the syngas generation system 100 may receive dried fish waste. The syngas generation system 100 may comprise a gasifier 102 and a combustor 126. The gasifier 102 may receive the feedstock 101 and may also receive steam from a steam supply 123. The gasifier 102 may perform a gasification process so as to generate syngas. The gasification process may be a steam gasification process. The gasifier 102 is preferably a dual bubbling fluidized bed (DFB) reactor. The DFB reactor may be based on that implemented at TU Wein as published in S. Koppatz, C. Pfeifer, R. Rauch, H. Hofbauer, T. Marquard-Moellenstedt, M. Specht, Fuel Processing Technology 2009, 90, 914-921. A catalyst, or catalysts, may be used in the gasifier 102. The catalyst(s) may improve the efficiency of the gasification process and / or convert any formed tar by the gasification process to hydrocarbons. Alternatively, the tar conversion catalyst may be used in a separate downstream reactor. Hie gasification process may be performed on the contents on the gasifier 102 at a temperature in the range of about 550°C to about 800°C, and preferably about 650°C to about 700°C. The gasification process may be performed at a pressure of about 1 -5 bar. An advantage of the gasification process being performed below about 800°C is that any Ca present will remain in a solid phase and will mainly be attached to char. This will reduce the impurities in the generated syngas. The contents of the gasifier 102 may include the received feedstock 101 and steam from the steam supply 123. The contents of the gasifier 102 may also include a reactive material. The reactive material may comprise a sorbent for removing carbon dioxide and preferably also impurities from the syngas product of the gasification process. The reactive material may be multi-functional to the extent that it both removes impurities and reduces the carbon dioxide concentration of the syngas. It also has the effect of increasing the hydrogen (IT) to carbon monoxide (CO) ratio in the syngas without excess steam being added. Advantageously, this reduces costs and the generated syngas may be efficiently used in a Co-based FT process. Preferably, the reactive material comprises a mixture of CaO (e.g. limestone) and red mud (see https 7 / en.wikipedta.org / wiki / Rsd mud. as viewed on 5th April 2024). The reactive material may also include the reaction product of CaO with CO2, which is CaCO , The reactive material may also include the reaction products of the red mud. The specific reaction products of the red mud depend on the specific composition of the feedstock 101 and red mud. The reactive material preferably is in the form of solid spherical pellets. The high surface area of a spherical pellet provides a large heat flux. The reactive material may comprise pellets that comprise CaO and separate pellets that comprise red mud. The pellets of the reactive material that comprise CaO may be modified to also include, for example, a binding material so as to improve their longevity and / or performance. Both red mud and CaO may serve as efficient catalysts for high temperature water gas shift (WGS) reactions, and the CaO may also capture CO2 in-situ. The red mud may comprise reducible Fe oxides that are catalysts for chemical looping reforming. The red mud may comprise FczO; that is a catalyst for the cracking of tar and NH3. Mixed oxides containing MnO may be impregnated to red mud and this may selectively remove the impurities such as N and alkaline (Na and K), thereby makes gas cleaning simpler. The gasifier 102 comprises an outlet through which the syngas generated in the gasifier 102 is output as a syngas stream 103. The syngas stream may comprise: H2 / CO ratiodry >2.0 CH4 <2vol%dry CO2 <2 vol%diy tar <0.5 gm / m3 The H2:C0 ratiodry may be is greater than 2.0 and is preferably 2.1 or greater. The light hydrocarbon content, which may have molecules with 4 carbon atoms or less, may be less than 2 vol%dry. The heat for the gasification process may be provided by the combustor 126. The combustor 126 may receive an internal supply of fuel from the gasifier 102, an external supply of fuel as fuel stream 119, and an air stream 124. The internal supply of fuel may be a product of the gasification process of the feedstock 100, such as charcoal. The external supply of fuel may be any fuel source but is preferably a product of the later described FT process. The fuel in the combustor 126 may be combusted with the air in the combustor 126. The combustion process may generate an operating temperature in the combustor 126 in the range of about 600°C to about 850°C, and preferably about 700°C to about 750°C. The combustion process may be performed at a pressure of about 1-5 bar. The contents of the combustor 126 may also include the above-de scribed reactive material. Heat from the combustion process may regenerate some, or all, of the CaCO, in the reactive material to form CaO and CO2. The reactive material may be moved in a cycle between the gasifier 102 and the combustor 126. The CaO in the reactive material is a sorbent that may capture CO2 in the gasifier 102 by reacting to form CaCOs. The CaCO may then be transferred to the combustor 126 where it reacts to release CO2 and re-form CaO. The CaO may then be supplied back to the gasifier 102 and re-used to capture CO2. Embodiments include a number of techniques for moving the reactive material in a cycle between the gasifier 102 and the combustor 126. For example, lock hoppers or loop seals may be used to transfer the reactive material from the gasifier 102 to the combustor 126, and from the combustor 126 back to the gasifier 102, without substantial gas transfer occurring between the gasifier 102 and the combustor 126. A system for looping a solid sorbent between a gas capture system and sorbent regeneration system is disclosed in at least the published International patent application W0 / 2020 / 165440, the entire contents of which are incorporated herein by reference. The cycling of the reactive material between the gasifier 102 and the combustor 126 may additionally be used to transfer heat from the combustor 126 to the gasifier 102. That is to say, the CaO and / or red mud, and / or the reaction products of the CaO and / or red mud, may be a heat transfer material between the combustor 126 and the gasifier 102. The combustor 126 may comprise a first outlet for a first output stream of gaseous products. The first output stream may mainly comprise CO? and N?. Hie CO? and N? may be separated from each other and the CO? compressed and transported for storage and / or use. The combustor 126 may also comprise a second outlet for a second output stream of solid products, such as the reaction products between the red mud and the feedstock 101. The second output stream may comprise ash that is the resulting product from burning charcoal. The syngas supply 105 is an output of syngas from the syngas generation system 100. The syngas may be used on site for a number of different purposes, or transported away for use elsewhere or storage. There may be a return syngas stream 106 that is a flow of some of the syngas stream 103 output from the gasifier 102 back to the combustor 126 and / or gasifier 102. This provides fluidisation in the combustor 126 and / or gasifier 102. In a preferred embodiment, syngas generation system 100 is integrated with a Fischer-Tropsch (FT) system. The syngas supply 105 may be the source of syngas used in the FT system. The syngas generation system 100 may receive and use fuel and / or heat from the FT system. The FT system may comprise a syngas cleaning system 107, a FT reactor 114 and a fuel separation system 116. The syngas cleaning system 107 may be arranged to receive and clean the syngas supply 105. The syngas cleaning system 107 may be any of a number of known designs of syngas cleaning system. Hie syngas cleaning system 107 may comprise a wet scrubber. The syngas supply 105 may be washed with a cleaning liquid, that is preferably water, as it flows through the wet scrubber with wet scrubber operating below 100°C. The output flow 108 of cleaning liquid from the wet scrubber may be cooled in a heat exchanger 109. A pump 111 may then pump the cleaning liquid back to an inlet of the wet scrubber so that it may be used to w ash the syngas flow again. If water is sufficient for cleaning the syngas, then this is the preferred cleaning liquid because it is cheap and widely available. If cleaning the syngas requires a stronger solvent than water, then other chemicals may additionally, or alternatively, be used in the syngas cleaning system 107. The cleaned syngas stream 110 is preferably ultra-pure. The cleaned syngas stream 110 may flow out of the wet scrubber and to a compressor 112. The compressor 112 may compress the received syngas stream and output a compressed syngas stream 113 for supplying to the FT reactor 114. The pressure of the compressed syngas stream 113 may be about 15 to 25 bar, and preferably about 20 bar. Hie FL: CO ratiodry of the compressed syngas stream 113 may be greater than 2.0. The FT reactor 114 receives the compressed syngas stream 113 and performs an FT process to generate fuel. The FT reactor 114 may be any of a number of known designs of FT reactor. The FT process for generating fuel in dependence on syngas was developed a long time ago and suitable FT reactors are commercially available. The FT reactor may comprise a plurality of reactors that perform FT processes. The FT reactor 114 may perform an FT process on syngas with syngas that has an FL / CO ratiodry >2.0. The pressure ofthe FT process may be about 15 to 25 bar, and preferably about 20 bar. The temperature of the FT process may be about 170°C to 270°C, and preferably about 220°C. The FT reactor 114 may output a fuel stream 115 that is a bio-based crude oil. The fuel stream 115 is supplied to the fuel separation system 116. The fuel separation system 116 may be any of a number of known designs of fuel separation system. The fuel separation system 116 may be a dedicated bio-refinery. The fuel separation system 116 may separate the components of the fuel stream 115 by evaporation and / or condensation. The lighter components ofthe fuel stream 115 comprise fuel molecules with 1 to 5 carbon atoms. The lighter components may be separated into a light fuel stream 119. The remaining liquid fuel components may be separated further so as to generate fuel streams that are usable in specific applications, such as for aviation fuel. A preferred component of the a fuel stream 115 is paraffinic kerosene because this may be used as a sustainable aviation fuel (SAF). The liquid fuel components may be output from the oi 1 / fuel generation system in the fuel output stream 127. The light fuel stream 119 may be supplied to the combustor 126 where it is used as a fuel for the combustion process. The light fuel stream 119 may additionally, or alternatively, be supplied to a second combustor 120. The second combustor 120 may bum the light fuel stream 119 in air. The heat from the combustion process in the second combustor 120 may be used to generate steam for use in the gasifier 102. For example, a flue gas stream 121 may be output from the second combustor 120 and supplied to a heat exchanger in a steam generator 122. The steam generator 122 may be a water boiler that heats water to generate the steam supply 123 to the gasifier 102. Figure 2 schematically shows a hydrogen generation system according to a second embodiment. The hydrogen generation system comprises a syngas generation system 100 and a sorption enhanced water gas shift (SEWGS) system 200. The syngas generation system 100 receives a feedstock 101 and generates a syngas supply 105 in dependence on the received feedstock 101. The SEWGS system 200 receives the syngas supply 105 from the syngas generation system 100 and generates a substantially pure hydrogen stream 205 in dependence on the syngas supply 105. The syngas generation system 100 of the second embodiment may be substantially the same as the syngas generation system 100 of the first embodiment. Accordingly, it may receive a waste product, such as fish waste, and generate syngas. The SEWGS system 200 converts the syngas generated by the syngas generation system 100 into a hydrogen stream 205 and a carbon dioxide stream 206. The hydrogen generation system may comprise further components than those shown in Figure 2. hi particular, the hydrogen generation system may comprise a syngas cleaning system 107 arranged to clean the syngas output from the syngas generation system 100. The syngas cleaning system 107 may be substantially the same as the syngas cleaning system 107 as described in the first embodiment. The SEWGS system 200 may comprise further components than those shown in Figure 2. In particular the SEWGS system 200 may comprise a water / steam supply. The water-gas-shift reaction reacts carbon monoxide with steam to generate hydrogen and carbon dioxide. The SEWGS system 200 perform the water-gas-shift reaction in the presence of a sorbent of the carbon dioxide so that the products of the reactions are hydrogen and the reacted sorbent. The sorbent may be any sorbent of carbon dioxide. A preferred sorbent is based on calcium oxide. If the sorbent is calcium oxide, then the SEWGS system 200 may comprise a first reactor 201 for supporting the below reaction: CO + H2O + CaO = H2 T CaCO3 Accordingly, the carbon monoxide in the syngas supply 105 is converted to hydrogen, leaving hydrogen as substantially tine only remaining gas in the first reactor 201. The reaction in the first reactor 201 may be performed at approximately 400°C to 450°C. The generated hydrogen may output as a substantially pure hydrogen stream 205. The solid calcium carbonate may flow out of the first reactor 201, in sorbent stream 202, to a second reactor 203. In the second reactor 203, the sorbent may be regenerated so that it releases carbon dioxide. The sorbent may be regenerated by heating it. The sorbent regeneration reaction shown below: CaC03 = CaO + C02 The reaction in the second reactor 203 may be performed at approximately 800°C to 1000°C, and preferably at about 900°C. The released carbon dioxide may flow out of the second reactor 203 as carbon dioxide stream 206. The sorbent may flow back to the first reactor via the sorbent flow path 204. In a preferred implementation of the second embodiment, the SEWGS system 200 is based on the combined sorption enhanced reforming, SER, and SEWEGS system as disclosed in WO2019 / 115831, the entire contents of which are incorporated herein by reference. hi a SER reaction, methane is reacted with H2O to generate CO, CO2 and H2. WO2019 / 115831 discloses a system that receives methane, performs SER to generate syngas, and then performs SEWGS to generate substantially pure hydrogen. The SEWGS system 200 of the second embodiment may differ from the disclosure in WO2019 / 115831 by the system not performing SER to generate syngas. The syngas is instead supplied by the syngas generation system 100. The SEWGS system 200 may otherwise be substantially as described in WO2019 / 115831. In the second embodiment, the syngas generation system 100 and the SEWGS system 200 are preferably integrated together. For example, heat exchangers and / or heat loops may be used to transfer heat between the syngas generation system 100 and the SEWGS system 200 to improve the overall efficiency of the hydrogen generation system. Figure 3 schematically shows an ethanol generation system according to a third embodiment. The ethanol generation system comprises a syngas generation system 100 and a bioreactor system 300. The syngas generation system 100 receives a feedstock 101 and generates a syngas supply 105 in dependence on the received feedstock 101. The bioreactor system 300 receives the syngas supply 105 from the syngas generation system 100 and generates an ethanol stream 301 in dependence on the syngas supply 105. The syngas generation system 100 of the third embodiment may be substantially the same as the syngas generation system 100 of the first embodiment. Accordingly, it may receive a waste product, such as fish waste, and generate syngas. The bioreactor system 300 converts the syngas generated by the syngas generation system 100 into an ethanol stream 301 and a carbon dioxide stream 302. The ethanol generation system may comprise further components than those shown in Figure 3. In particular, tire ethanol generation system may comprise a syngas cleaning system 107 arranged to clean the syngas output from the syngas generation system 100. The syngas cleaning system 107 may be substantially the same as the syngas cleaning system 107 as described in the first embodiment. The bioreactor system 300 may comprise further components than those shown in Figure 3. The bioreactor system 300 may be any type of reactor for performing a bioconversion of syngas to generate ethanol. The bioconversion may use a biocatalyst. A suitable bioreactor system 300 has been developed by at least LanzaTech, and there are publications of suitable bioreactor systems 300, such as of example haps: / / www,sciencedi Fect.com / sesence / artick / pii / S2S90140020300022 (as viewed on 12th May 2024). In the third embodiment, the syngas generation system 100 and the bioreactor system 300 are preferably integrated together. For example, heat exchangers and / or heat loops may be used to transfer heat between the syngas generation system 100 and the bioreactor system 300 to improve the overall efficiency of the ethanol generation system. Further embodiments include using the syngas generated by the syngas generation system 100 to generate other products than liquid fuels, hydrogen and ethanol. Advantageously, the system according to embodiments converts fish w aste into the useful product syngas. Embodiments include using the syngas to generate liquid fuel, hydrogen, ethanol and other useful products. The carbon dioxide generated by the performed processes is captured so it is not directly released into the atmosphere. Embodiments include a number of modifications and variations to the above described processes. The feedstock 101 to the gasifier 102 may be substantially only fish waste. However, embodiments also include the feedstock 101 being a mixture of fish waste and other products, such as biomass. Advantageously, mixing the fish waste with other products prior to the gasification process provides more control over the specific composition of the syngas stream 103. Embodiments also include the feedstock 101 to the gasifier 102 being other waste products than fish waste. For example, the feedstock 101 may be, or comprise, pulp and paper waste, waste water sludge and municipal solid waste. Hie oil / fuel generation system, hydrogen generation system and ethanol generation system according to embodiments may be operated in a number of different configurations with the system using different components in each of the configurations. One or more of the components shown in Figures 1 to 3 may therefore be optional to the extent that embodiments include a configuration of the system that does not use the one or more components. Hie oil / fuel generation system, hydrogen generation system and ethanol generation system according to embodiments may also comprise further components to those shown in Figures 1 to 3. For example, the system may comprise pumps, coolers, heaters, heat exchangers, valves, manifolds, temperature sensors, pressure sensors, controllers and any other components required for the operation of the system. The oil / fuel generation system may comprise one or more further reactors for upgrading the output fuel. For example, a reactor may be used to perform a mild hydrocracking process (e.g. at 40-80 bar, 300°C to 400°C). Embodiments include the fuel separation system 116 alternatively being located remotely from the FT reactor 114 and the fuel stream 115 being transported to the fuel separation system 116. Embodiments include the gasifier 102 being any type of gasifier 102. For example, the gasifier 102 may be any of a fixed bed, fluidized bed and entrained flow gasifier. Embodiments also include alternative techniques for transferring heat from the combustor 126 to the gasifier 102. For example, heat may be transferred from the combustor 126 to the gasifier 102 by conduction through the walls of the reactors. Embodiments also include heat being transferred from the combustor 126 to the gasifier 102 via heat pipes or other heat transfer techniques. The gasifier 102 and the combustor 126 may be comprised by a single reactor system. Embodiments include the use of any technique for generating syngas from the feedstock 101. In particular, embodiments include performing a thermal hydrolysis process on the feedstock 101. The feedstock may be processed by a hydrothermal gasification reactor system to generate syngas. The processes and / or reactor system used to process the feedstock 101 may be substantially as described here: hUps.V / ww'w.cambixom / wbat-we-do / thennal-hvdrolvsis / (as viewed on 10th April 2024), with the key difference of embodiments being that the feedstock is based on fish waste. Fish waste typically comprises lower impurity levels than known alternative feedstocks, it is suitable for generating syngas and is available at low cost. 5 Tire flow charts and descriptions thereof herein should not be understood to prescribe a fixed order of performing the method steps described therein. Rather, the method steps may be performed in any order that is practicable. Although the present invention has been described in connection with specific exemplary embodiments, it should be understood that various changes, substitutions, and alterations apparent to those skilled in the art can be made to the disclosed embodiments without 10 departing from the spirit and scope of the invention as set forth in the appended claims.

Claims

1. A syngas production system for producing syngas from fish waste, the system comprising:a gasifier; anda feedstock input that is configured to supply a feedstock comprising fish waste to the gasifier;wherein the gasifier is configured to generate syngas by performing a gasification process on the received feedstock.

2. The system according to claim 1, further comprising a steam input configured to supply steam to the gasifier;wherein the gasifier is configured to perform a steam gasification process on the feedstock.

3. The system according to any preceding claim, wherein the gasifier is configured to perform the gasification process at a temperature in the range of about 550°C to about 800°C, and preferably about 650°C to about 700°C.

4. The system according to any preceding claim, wherein the gasifier is configured to perform the gasification process at a pressure in the range of about 1 to 5 bar.

5. The system according to any preceding claim, further comprising a combustor configured to perform a combustion process for generating heat for the gasification process.

6. The system according to any preceding claim, wherein the combustor is configured to perform the combustion process on solid products of the gasification process and / or a separate fuel supply to the combustor.

7. The system according to any preceding claim, wherein the combustor is configured to operate at a temperature in the range of about 600°C to about 850°C, and preferably about 700°C to about 750°C.

8. The system according to any preceding claim, wherein the combustor is configured to operate at a pressure in the range of about 1 to 5 bar.

9. The system according to claim 5, or any claim dependent thereon, further comprising a reactive material;wherein:the gasifier is configured to perform the gasification process in the presence of the reactive material; andthe combustor is configured to perform the combustion process in the presence of the reactive material;wherein the reactive material is a sorbent of CO2 and / or removes impurities from the products of the gasification process.

10. The system according to claim 9, wherein the reactive material comprises CaO. red mud, CaCOs and / or reaction products of red mud.

11. The system according to claim 9 or 10, wherein the gasifier and the combustor are configured so that, in use, the reactive material moves in a cycle between the combustor and the gasifier.

12. The system according to any preceding claim, wherein the gasifier is configured to output the generated syngas; andthe output syngas has the properties:H2 to CO ratiodry >2.0CH4 <2vol%dryCO2 <2 vol° / wtar <0.5 gm / m313. The system according to any preceding claim, wherein the feedstock comprises substantially only fish waste.

14. The system according to any preceding claim, wherein the fish waste comprises dewatered fish faeces and residual fish feed.

15. The system according to any preceding claim, wherein the fish waste has been filtered to remove dead fish.

16. An oil / fiiel generation system for producing oil / fucl from fish waste, the system comprising: the syngas production system according to any preceding claim; anda Fischer-Tropsch, FT, system configured to receive syngas generated by the syngas production system and generate oil / fuel in dependence on the received syngas.

17. The system according to claim 16, further comprising a syngas cleaning system configured to: clean the syngas output from the syngas production system;supply the cleaned syngas to the FT system.

18. The system according to claim 17, wherein the syngas cleaning system comprises a wet scrubber.

19. The system according to any of claims 16 to 18, further comprising a fuel separation system configured to separate the fuel output from the FT system into at least light fuel and other fuel components.

20. The system according to claim 19, when dependent on claim 5, further comprising conduit(s) arranged to receive light fuel components from the fuel separation system and to supply at least some of the light fuel components to the combustor.

21. The system according to claim 19 or 20, further comprising:a second combustor;a steam boiler; andconduit(s) arranged to receive light fuel components from the fuel separation system and to supply at least some of the light fuel components to the second combustor;wherein:the second combustor is configured to generate heat by combusting the received light fuel components;the second combustor is configured to supply the generated heat to the steam boiler so that the steam boiler generates steam; andthe steam boiler is configured to supply the steam to the gasifier.

22. An oil / fiiel generation system for producing oil / fuel from fish waste, the oil / fuel generation system comprising:a syngas production system;a feedstock input that is configured to supply a feedstock comprising fish waste to the syngas production system; anda Fischer-Tropsch, FT, system configured to receive syngas generated by the syngas production system and generate fuel in dependence on the received syngas;wherein the syngas production system is configured to generate syngas in dependence on the received feedstock.

23. A hydrogen generation system for producing hydrogen from fish waste, the system comprising:the syngas production system according to any of claims 1 to 15; anda sorption enhanced water gas shift, SEWGS, system configured to receive syngas generated by the syngas production system and generate hydrogen in dependence on the received syngas.

24. An ethanol generation system for producing ethanol from fish waste, the system comprising: the syngas production system according to any of claims 1 to 15; anda bioreactor system configured to receive syngas generated by the syngas production system and generate ethanol in dependence on the received syngas.

25. A method of producing syngas from fish waste, the method comprising:obtaining a feedstock comprising fish waste; andgenerating syngas by performing a gasification process on the obtained feedstock.

26. A method of producing oil / fuel from fish waste, the method comprising: the method of producing syngas according to claim 25; and generating oil / fuel by performing a Fischer-Tropsch, FT, process on the produced syngas.

27. A method of producing oil / fuel from fish waste, the method comprising: obtaining a feedstock comprising fish waste;generating syngas in dependence on the obtained feedstock; andgenerating oil / fuel by performing a Fischer-Tropsch, FT, process on the generated syngas.

28. A method of producing hydrogen from fish waste, the method comprising: the method of producing syngas according to claim 25; andgenerating hydrogen by performing a sorption enhanced water gas shift, SEWGS, process on the produced syngas.

29. A method of producing ethanol from fish waste, the method comprising: the method of producing syngas according to claim 25; and generating ethanol by performing a bioreaction process on the produced syngas.

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