e-methanol SAGD plant system applicable to non-traditional oil production areas

Abstract

We provide an e-methanol SAGD plant applicable to non-traditional oil production areas. [Solution] The e-methanol SAGD plant system comprises: a first water treatment module that removes impurities from the supply water and produces purified water; a boiler module that heats the purified water and produces steam; a hydrogen generation module that generates hydrogen by decomposing the purified water using electricity; an injection well that supplies the steam to the inside of the oil sands mining area; a hydrogen supply unit that supplies a portion of the hydrogen produced by the hydrogen generation module to the inside of the oil sands mining area; a producer well in which bitumen and gas are recovered from the lower part of the oil sands mining area; a gas collection unit that receives natural gas from the outside and collects CO2 from the combustion of excess gas; and a methanol production unit that produces e-methanol using the hydrogen produced by the hydrogen generation module and the CO2 from the gas collection unit.

Description

Technical Field

[0001] <Description related to the results of commissioned research by countries, etc.> The present invention has been made with the support of research conducted by the Korea Agency for Infrastructure Technology Advancement (KAIA) under the support of the Ministry of Land, Infrastructure and Transport of the Republic of Korea. [Research project name: "Development of Core Technologies for the Construction of Non-Conventional Oil Production Plants"; Research topic name: "Modular Design and Integrated Demonstration Technology Development of Oil Production Plants"; Topic specific number: 1615012996; Topic number: 00143644] The present invention relates to a SAGD plant system, and more specifically, based on the most widespread SAGD (steam assisted gravity drainage) technology among the methods for recovering bitumen from oil sands, when recovering oil components from oil sands buried underground, instead of ES-SAGD (Expanding Solvent SAGD), which is a method of using additives such as solvents to reduce the SOR (Steam Oil Ratio) that affects steam, natural gas, and environmental pollution, it relates to an e-methanol SAGD plant system applicable to non-conventional oil production regions that can produce e-methanol using carbon-reduced green hydrogen and CO2 generated in a plant that recovers bitumen with a mixture of natural gas and steam of environmentally friendly hydrogen generated by a water electrolysis device.

Background Art

[0002] In recent years, due to factors such as rising oil prices and the Ukraine war, the demand for oil has resurfaced, and non-conventional oils such as oil sand plants in extremely cold environmental conditions have once again attracted attention.

[0003] In particular, bitumen, a residue generated during petroleum rectification, is a type of petroleum product composed of natural hydrocarbon compounds, yet it dissolves in carbon dioxide and liquid-phase hydrocarbons at room temperature as a black semi-solid or liquid-phase substance. A variety of methods are being applied to recover bitumen underground. Due to the nature of oil production, environmental pollution issues such as greenhouse gas emissions remain a persistent issue, and long-term environmental pollution reduction measures are needed. This is also a crucial factor in determining the sustainability of oil sands operations.

[0004] Currently, the SAGD method, which accounts for more than 80% of bitumen production, uses large amounts of water, steam, and gas, which are major causes of environmental pollution and greenhouse gas emissions. To reduce this, the ES-SAGD (Expanding Solvent SAGD) method is being used, which reduces the amount of steam by mixing in high-grade refined oils such as solvents.

[0005] In other words, not only are harmful substances such as H2S generated during the steam generation and bitumen treatment processes, but the large amount of water required for steam generation is almost always found in the use of arbitrary wells or ponds. This requires more than three times the amount of water as the oil produced, and even when the used water is treated, some contamination cannot be avoided.

[0006] Thus, since the SAGD method itself uses a large amount of water, which is a major cause of environmental pollution, ES-SAGD (Expanding Solvent SAGD) is applied to reduce the amount of steam by mixing in high-grade refined oils such as solvents.

[0007] Thus, when applying SAGD or ES-SAGD technology to recover bitumen from oil sands buried underground, there is a need for a method that can significantly reduce greenhouse gas emissions in preparation for the mixing of hydrogen and natural gas, and the injection of additives such as solvent and CO2, and that can improve the quality of bitumen through the hydrogenation reaction of the injected hydrogen. In this context, the applicant, through Korean Patent No. 10-2840992 (registered July 28, 2025), has presented a carbon-reducing SAGD plant system utilizing green hydrogen that can recover bitumen while significantly reducing greenhouse gas emissions, which have been identified as the biggest problem with conventional methods, by using only a mixture of environmentally friendly hydrogen produced by a water electrolysis device with natural gas and steam.

[0008] In this case, transporting green hydrogen produced in non-traditional oil-producing regions requires liquefaction, high-pressure processing, or the installation of pipelines, which incurs significant costs and creates the problem of hydrogen embrittlement.

[0009] Furthermore, due to the characteristics of oil sands regions, where natural gas must be continuously used as blanket gas, the only option was to burn the various gases, including CO2, generated in bitumen through flare stacks. [Prior art documents] [Patent Documents]

[0010] [Patent Document 1] Korean Patent No. 10-2840992 Specification [Overview of the Initiative] [Problems that the invention aims to solve]

[0011] The present invention was created in view of the above facts, and the object of the present invention is to provide an e-methanol SAGD plant system applicable to non-traditional oil production areas, which produces e-methanol by capturing CO2 released from a flare stack and mixing it with green hydrogen produced in a carbon-reducing SAGD plant utilizing green hydrogen. [Means for solving the problem]

[0012] To achieve the above objectives, the present invention provides an e-methanol SAGD plant system applicable to non-traditional oil production areas for recovering bitumen from oil sands fields, characterized by comprising: a first water treatment module for removing impurities from feedwater and producing purified water; a boiler module for heating the purified water and producing steam; a hydrogen generation module for generating hydrogen by decomposing the purified water using electricity; an injection well for supplying the steam to the inside of the oil sands field; a hydrogen supply unit for supplying a portion of the hydrogen produced by the hydrogen generation module to the inside of the oil sands field; a producer well for recovering bitumen and gas from the lower part of the oil sands field; a gas collection unit for receiving natural gas from the outside and capturing CO2 from the combustion of excess gas; and a methanol production unit for producing e-methanol using the hydrogen produced by the hydrogen generation module and the CO2 from the gas collection unit.

[0013] In this configuration, the boiler module is configured to use natural gas supplied from an external source and a portion of the hydrogen produced by the hydrogen generation module as fuel, and may further include a second separator that generates reformed hydrogen through the gas components that have passed through the first separator.

[0014] The system may further include a first gas mixing module connected to the hydrogen supply unit, which supplies natural gas and hydrogen to the inside of the oil sands mining area while mixing them in a set ratio; and a second gas mixing module which supplies the natural gas separated by the second separator and a portion of the hydrogen produced by the hydrogen generation module as fuel to the boiler module while mixing them in a set ratio.

[0015] Furthermore, it is preferable that the methanol production section is composed of an FT reactor that reduces CO2 on the catalyst surface and converts it to CO, reacts hydrogen with the active center of the catalyst to form hydrocarbons and oxygen compounds, and produces methanol by CC bond formation.

[0016] Furthermore, it is preferable that the methanol production unit separates methanol from the product of the FT reactor through distillation and adsorption steps. [Effects of the Invention]

[0017] Through this invention, instead of using additives (such as solvents) in ES-SAGD (Expanding Solvent SAGD), bitumen can be efficiently recovered from oil sands using only a mixture of natural gas and steam with environmentally friendly hydrogen generated by a water electrolysis device. In this process, greenhouse gas emissions, which have been identified as the biggest problem with conventional methods, can be significantly reduced, while also producing e-methanol, an environmentally friendly raw material.

[0018] Unlike ordinary methanol, the e-methanol according to the present invention is produced solely from green hydrogen and CO2 through carbon capture, and is recognized as an environmentally friendly raw material that can contribute to RE100. This not only attracts attention as an alternative energy source to petroleum, such as for ship propulsion fuel, but also has great scalability because it can be transported in existing pipelines and general tanks.

[0019] In particular, by significantly reducing the carbon dioxide generation rate through green hydrogen production, the cost of carbon dioxide based on carbon emission rights can be reduced.

Brief Description of the Drawings

[0020] [Figure 1] It is a conceptual diagram of ES-SAGD production according to the prior art. [Figure 2] It is a system diagram of ES-SAGD production according to the prior art. [Figure 3] It is a system diagram of the e-methanol SAGD plant according to the present invention. [Figure 4] It is a system diagram of the e-methanol SAGD plant according to the present invention.

Embodiments for Carrying Out the Invention

[0021] Hereinafter, with reference to the accompanying drawings, the e-methanol SAGD plant system applied to the unconventional oil production area of the present invention will be specifically described.

[0022] FIG. 1 is a conceptual diagram of ES-SAGD production according to the prior art, and FIG. 2 is a system diagram of ES-SAGD production according to the prior art. In the SAGD method, a series of complex processes are required to extract the bitumen solidified in the oil sand and use it as crude oil. At this time, a large amount of water, electricity, gas, etc. are required, and environmental pollution caused by steam and gas, etc. occurs in the treatment process.

[0023] In particular, the factors that have the greatest impact on greenhouse gases are steam and methane in natural gas. The lower the values of SOR, which is the production ratio of steam and oil, and GOR, which is the production ratio of gas and oil, the more advantageous it is in terms of environmental pollution and economy. In order to reduce SOR and GOR, in recent years, the In-situ method (underground recovery method), which is an ES-SAGD method that mixes a solvent with steam and increases bitumen extraction productivity while reducing the proportion of natural gas, has been applied.

[0024] The ES-SAGD plant is very similar to the SAGD method and includes injection wells for injecting gas, steam, and solvent for underground recovery, and production wells for recovering bitumen from underground. The ES-SAGD plant also includes basic separation equipment such as wellpad units, a central process facility (CPF) with an oil-water separator, water treatment equipment, and boiler packages for generating steam, as well as equipment for injecting and recovering solvent. Partial reforming is also performed as needed.

[0025] Furthermore, the water used to produce the steam is obtained from source water acquired in the natural environment and tailing water after oil sands treatment, and is supplied as Boiler Fresh Water (BFW) after water treatment. In other words, continuous water generation is necessary for the BFW supply of steam, so it is possible to secure a sufficient amount of water for water electrolysis-based hydrogen production, which is a characteristic of the present invention.

[0026] The present invention, in order to reduce greenhouse gas emissions, which are the biggest problem in methods of recovering bitumen from oil sands, uses a method of recovering bitumen by mixing hydrogen produced in a water electrolysis device with natural gas, and then using this as a base to produce methanol through the CO2 and hydrogen generated. In other words, this is methanol produced in an environmentally friendly way that reduces carbon dioxide (CO2) emissions or uses renewable resources, and is usually referred to as e-methanol.

[0027] Based on SAGD (steam-assisted gravity drainage), the most widespread of the many production methods for bitumen, this new method will recover bitumen from underground oil sands using only environmentally friendly hydrogen and natural gas, along with steam, instead of ES-SAGD (Expanding Solvent SAGD), which uses steam, natural gas, and additives such as solvents to reduce the SOR (Steam Oil Ratio) that impacts environmental pollution.

[0028] Hydrogen is efficient in this type of SAGD system because it has a higher heat capacity than steam, potentially allowing it to transfer more heat to the storage facility and increase the oil recovery rate.

[0029] Next, hydrogen can be used in in-situ combustion, a process that generates heat while reacting with oil in storage, creating conditions that promote oil flow. Furthermore, unlike traditional combustion processes that use natural gas, hydrogen combustion produces only water vapor as a byproduct, potentially reducing greenhouse gas emissions associated with the extraction process.

[0030] This invention relates to an e-methanol SAGD plant system applicable to non-traditional oil production areas for recovering bitumen from oil sands fields. Essentially, it applies to a plant that supplies steam and hydrogen to oil sands fields to recover bitumen. In this process, instead of using traditional natural gas-based steam generators, it is possible to generate environmentally friendly steam using a hydrogen boiler that directly supplies hydrogen, which is currently in the commercialization stage.

[0031] Furthermore, in areas where nearby natural gas production is possible or where natural gas can be easily used via gas pipelines, it is also possible to replace the solvent used with steam and natural gas, as in the conventional SAGD system, with hydrogen. For this purpose, a first water treatment module 101 is provided to remove impurities from the feedwater and produce purified water for steam generation and hydrogen production.

[0032] As described above, the supply water can be raw water obtained from natural environments such as ponds, reservoirs, and rivers, as well as tail water present in the mining area after oil sands treatment. Impurities are removed through the first water treatment module 101, and water for BFW (Boiler Fresh Water) and water for water electrolysis hydrogen production is supplied.

[0033] At this time, the water obtained from the tail water can be divided and supplied through the first branching section 118 to the degreasing tank (Skim Tank) and the hydrogen generation module 103 of the oil-water separation module 108, which will be described later.

[0034] Furthermore, BFW (Boiler Fresh Water) can be divided and supplied to the boiler module 102 and the hydrogen generation module 103 via the second branching section 119.

[0035] Subsequently, the purified water, from which impurities have been removed as it passes through the first water treatment module 101, is heated through the boiler module 102 to produce steam. Initially, steam is generated only through the purified water that has passed through the first water treatment module 101, but water for steam generation can also be supplied to the boiler through the second water treatment module 113, which will be described later.

[0036] A portion of the purified water, from which impurities have been removed as it passes through the first water treatment module 101, is then decomposed using electricity in the hydrogen generation module 103 to produce hydrogen. For this purpose, the hydrogen generation module 103 is equipped with electricity, a catalyst, and a separation membrane to electrolyze the purified water, using materials such as platinum, iridium, and ruthenium. By applying a catalyst-free hydrogen generation technology that does not use expensive catalysts, it is possible to enhance competitiveness.

[0037] In this system, electricity generated from renewable energy sources such as solar and wind power can be used for water electrolysis, and green hydrogen, which is the most necessary future energy source in the era of carbon neutrality, can be produced as hydrogen with no carbon emissions during the production process. In particular, in recent years, the effects of green hydrogen have been greatly enhanced while the value of renewable energy has been declining, and the boiler module 102 can be configured to use a portion of the hydrogen produced by the hydrogen generation module 103 as fuel, thereby improving the overall efficiency of the system.

[0038] A portion of the hydrogen produced through the hydrogen generation module 103 is supplied to the inside of the oil sands mining area and used as fuel for the boiler module 102, while the remainder is stored in the H2 sales tank and can be utilized in various ways.

[0039] The steam produced through the boiler module 102 is supplied to the inside of the oil sands mining area via the injection well 105, and a portion of the hydrogen produced by the hydrogen generation module 103 is also supplied to the inside of the oil sands mining area via the hydrogen supply unit 104. Through this, bitumen and gas are recovered from the producer well 106 installed at the bottom of the oil sands mining area, and the gaseous component and bitumen of the producer well 106 are separated via the first separator 107.

[0040] At this time, the bitumen is a mixture of the oil component of the bitumen and water from the steam supplied to the oil sands mining area, while the gas component is a mixture of hydrogen supplied to the oil sands mining area, hydrogen that is naturally present in the mining area, or hydrogen supplied separately, and natural gas. Since the gas component of the producer well 106 and the bitumen are in different states, the first separator 107 easily separates the gas component and the bitumen using the principle of separating gaseous and non-gasic components.

[0041] Furthermore, since the bitumen recovered from the producer well 106 and separated through the first separator 107 is a mixture of oil and water, the water component is separated from the bitumen that has passed through the first separator 107 through the oil-water separation module 108.

[0042] Specifically, the bitumen separated through the first separator 107 is transferred through a sludge pump and then supplied to an oil-water separation module 108, where sand removal and dewatering may occur. The oil-water separation module 108 is configured to use FWKO (Free Water Knockout) and is equipped with a desalination module 109, which may perform desalination of the bitumen from which the water has been separated.

[0043] The water separated through the oil-water separation module 108 is treated through a second water treatment module 113, which is composed of IGF (Induced Gas Floatation), via a degreasing tank, and then supplied to the boiler module 102 and the hydrogen generation module 103. At this time, additional water may be supplied to the degreasing tank via the first branching section 118.

[0044] The aforementioned IGF refers to a water treatment process that removes suspended solids such as oil and solid matter and purifies wastewater (or other water), and includes ceramic membrane filters, reverse osmosis filters (RO), and CDI (Capacitive Deionization), which removes ions using electrical force and is based on the supercapacitor principle, enabling sewage treatment and chlorine desalination at low cost and with high efficiency. Furthermore, sludge contained in the concentrated water generated by RO can be treated by recirculating the water without discharging effluent (ZLD: Zero Liquid Discharge) technology.

[0045] To improve the efficiency of the oil-water separation module 108, a diluent processing module 114 may be included, comprising a diluent tank 115 containing a diluent, a diluent supply unit 116 that supplies the diluent to the oil-water separation module 108, and a diluent recovery unit 117 that recovers the diluent from the bitumen that has passed through the oil-water separation module 108 and supplies it to the diluent tank 115.

[0046] The diluent from the diluent tank 115 is supplied to the rear of the pre-head desander for sand removal and dewatering, and the diluent is recovered from the bitumen that has passed through the oil-water separation module 108 and resupplied in a circulating manner, thereby improving the separation efficiency of water and oil components.

[0047] In this case, the diluent may vary depending on the detailed composition of bitumen, but depending on the diverse forms of hydrocarbons, C4 (butene), C5 (pentene), and C6 (hexene) can be used, and the diluent is used during the SAGD treatment to promote the effective separation and production of crude oil and water.

[0048] In other words, since SAGD produces crude oil using a steam-assisted gravity drainage method, the crude oil contains a considerable amount of water along with the steam. Therefore, the crude oil-water mixture needs to be separated. Diluents reduce the interface surface tension with water, promoting fluid separation and more effectively separating water from crude oil, thus efficiently assisting in oil collection. Also, high viscosity can make fluid flow difficult, so diluents can reduce the viscosity of impure fluids with high viscosity and improve flow characteristics.

[0049] Furthermore, the gas components that have passed through the first separator 107 can be used as fuel gas together with the gas components partially removed through the oil-water separation module 108. Alternatively, the gas components that have passed through the first separator 107 can be mixed with natural gas and hydrogen as the main components, and hydrogen can be produced using a second separator 110 that generates reformed hydrogen through the gas components that have passed through the first separator 107. Additionally, a portion of the gas components that have passed through the first separator 107 can be used as fuel for the boiler module 102.

[0050] As described above, if the supply of natural gas from an external source is smooth, a first gas mixing module 111 can be provided, which is connected to the hydrogen supply unit and supplies natural gas and hydrogen to the inside of the oil sands field while mixing them in a set ratio. Preferably, by mixing natural gas and hydrogen in a ratio of 70:30 to 90:10, the bitumen recovery efficiency can be greatly improved.

[0051] Furthermore, the system includes a second gas mixing module 112 that supplies the natural gas separated by the second separator 110 and a portion of the hydrogen produced by the hydrogen generation module as fuel to the boiler module while mixing them in a set ratio, thereby reducing energy waste and increasing efficiency. In this case, it is preferable to mix the natural gas and hydrogen in a ratio of 60:40 to 80:20.

[0052] Through this invention, greenhouse gas emissions can be reduced using green hydrogen in non-traditional oil production regions with the worst greenhouse gas emissions, while simultaneously achieving P2G (Power-to-Ground) by storing and supplying green hydrogen. Furthermore, it is possible to transform into a new non-traditional oil plant that can simultaneously produce and utilize oil, which is essential for industry, and green hydrogen, which will be essential for combating global warming in the future.

[0053] Adding 10 vol% hydrogen to South Korea's annual natural gas consumption of 40 million tons could reduce natural gas use by 1.29 million tons per year and carbon dioxide emissions by 3.55 million tons per year. Furthermore, with increasing sanctions against environmental pollution in Canada and other non-traditional oil reserve regions, a significant contraction of non-traditional oil production is anticipated. However, this invention can provide an environmentally friendly solution to the problems of non-traditional oil production, and the hydrogenation reaction, one of the properties of hydrogen, can also greatly improve the quality of bitumen.

[0054] As described above, the present invention is provided with a gas supply unit 120 that receives natural gas from an external source, and is applied to areas where nearby natural gas production is possible or where the use of natural gas is easily accessible through gas pipelines. The gas supply unit 120 supplies natural gas necessary for the operation of the plant, including the boiler module 102, the first gas mixing module 111, and the second gas mixing module 112.

[0055] In this case, a combustion section 122 is provided as a type of flare system used for process safety in petrochemical, oil refining, and gas processing plants. This combustion section burns off excess pressure and unwanted gas in a flare stack without releasing them into the atmosphere, reducing the emission of harmful substances and ensuring safe processing. Specifically, the combustion section 122 burns off the gas to relieve pressure that could damage equipment and pipelines if the pressure of natural gas increases abnormally during the process, thereby protecting the process and the environment. For this process, a knockout section 121 may be provided between the gas supply section 120 and the combustion section 122 to separate liquids such as oil and condensed water from the gas flow and maintain stability.

[0056] Thus, a gas collection unit 123 is provided to collect CO2 from the products of excess gas combustion. The gas collection unit 123 uses flare CO2 capture technology, which collects carbon dioxide (CO2) from the high-temperature exhaust gas released into the flare and recycles or stores it environmentally. Unlike general CO2 capture processes, specialized technology is applied that is designed to match the high temperature, intermittent emission, and high flow rate of the flare.

[0057] The exhaust gas from the combustion section 122 consists of a mixture of high-temperature CO2, nitrogen, methane, oxygen, etc. By cooling this mixture, it is brought into a state suitable for CO2 capture, and particulate matter and other impurities are removed in this process.

[0058] CO2 capture can be carried out using methods such as selective absorption of CO2 using amine-based absorbents, which are chemical substances such as MEA (monoethanolamine) and DEA (diethanolamine); adsorption of CO2 using materials such as zeolite and activated carbon; and membrane separation, which separates CO2 through a selective permeable membrane. The captured CO2 can be purified by concentration and stored by compression.

[0059] Subsequently, e-methanol is produced through the methanol production unit 124 using the hydrogen produced in the hydrogen generation module 103 and the CO2 in the gas collection unit 123.

[0060] The process of producing environmentally friendly green hydrogen through a water electrolysis (PtG, Power-to-Gas) process, and methanol (CH3OH) using carbon dioxide (CO2) emitted during the process, utilizes the Fischer-Tropsch (FT) reaction and employs a technology that converts gas into liquid fuel using a chemical catalyst.

[0061] To achieve this, the process of first mixing CO2 and H2 in the appropriate ratio (1:3 or 1:2) to produce synthesis gas that meets the reaction conditions proceeds according to the following reaction equation.

[0062] CO2+3H2→ CH3OH+H2O, CO2+H2-> CO+H2O

[0063] To maximize the reaction efficiency of CO2 and H2, transition metal catalysts and specific catalyst combinations can be used, such as ruthenium (Ru), iron (Fe), nickel (Ni), and cobalt (Co). Catalysts specifically designed for methanol production are oxide-based catalysts such as Cu / Zn / Al2O3, which activate the step of converting CO2 to CO and help form a carbon-carbon bond (CC bond) by combining it with H2.

[0064] In the present invention, the methanol production unit 124 is an FT reactor that promotes the reaction at a pressure of 20 bar to 50 bar and a temperature range of 200°C to 300°C, and can be a fixed-bed reactor or a fluidized-bed reactor. The FT reaction process consists of a CO2 activation step in which CO2 is reduced on the catalyst surface and converted to CO, and a synthesis gas reaction step in which CO and H2 react at the active center of the catalyst to form various hydrocarbons and oxygen compounds, and low-carbon alcohols including methanol are produced through CC bond formation.

[0065] Subsequently, methanol separation and purification can be carried out through distillation and adsorption steps to separate methanol from the reaction product.

[0066] The e-methanol produced through this process can be used as automotive fuel, aviation fuel, and chemical raw material. It is a carbon-neutral fuel that uses carbon dioxide as a raw material, and is used as an environmentally friendly alternative to existing fossil fuels. [Explanation of Symbols]

[0067] 101 Water Treatment Module 1 102 Boiler Module 103 Hydrogen generation module 104 Hydrogen Supply Department 105 injection wells 106 Producer Well 107 First Separator 108 Oil-water separation module 109 Desalination Module 110 Second Separator 111 First Gas Mixing Module 112 Second Gas Mixing Module 113 Second Water Treatment Module 114 Diluent Treatment Module 115 Diluent Tank 116 Diluent supply unit 117 Diluent Recovery Section 118 First Branch 119 Second Branch 120 Gas Supply Department 121 Knockout Section 122 Combustion section 123 Gas collection section 124 Methanol Production Department

Claims

1. In an e-methanol SAGD plant system applied to non-traditional oil production areas for recovering bitumen from oil sands fields, A first water treatment module that removes impurities from the supply water and produces purified water; A boiler module that heats the purified water and produces steam; A hydrogen generation module that generates hydrogen by decomposing the purified water using electricity; An injection well for supplying the aforementioned steam to the inside of the oil sands mining area; A hydrogen supply unit that supplies a portion of the hydrogen produced by the aforementioned hydrogen generation module to the inside of the oil sands mining area; Producer wells where bitumen and gas are recovered from the lower part of the oil sands field; Receiving natural gas from an external source, and CO2 is produced by the combustion of excess gas. 2 A gas collection unit for collecting gases; and The hydrogen produced in the aforementioned hydrogen generation module and the CO2 from the gas collection unit 2 An e-methanol SAGD plant system characterized by comprising a methanol production unit that produces e-methanol using [a specific method / tool].

2. The boiler module is configured to use natural gas supplied from an external source and a portion of the hydrogen produced by the hydrogen generation module as fuel. The e-methanol SAGD plant system according to claim 1, further comprising: a second separator which separates the gas component recovered from the producer well from bitumen and generates reformed hydrogen through the gas component that has passed through the first separator;

3. A first gas mixing module connected to the hydrogen supply unit, which supplies natural gas and hydrogen to the inside of the oil sands mining area while mixing them in a set ratio; and The e-methanol SAGD plant system according to claim 2, further comprising: a second gas mixing module that supplies the natural gas separated by the second separator and a portion of the hydrogen produced by the hydrogen generation module as fuel for the boiler module while mixing them in a set ratio;

4. The methanol production unit is CO 2 The e-methanol SAGD plant system according to claim 1, characterized in that it is comprised of an FT reactor that reduces a substance on the catalyst surface and converts it to CO, reacts hydrogen with the active center of the catalyst to form hydrocarbons and oxygen compounds, and produces methanol by C-C bond formation.

5. The e-methanol SAGD plant system according to claim 4, characterized in that the methanol production unit separates and purifies methanol through distillation and adsorption steps using the products of the FT reactor.

Images