JP2008503609A - A liquefied natural gas plant with appreciable capacity - Google Patents

Abstract

  The present invention relates to a hydrocarbon fluid treatment plant, a hydrocarbon fluid treatment plant design method, a hydrocarbon fluid treatment plant operation method, and a hydrocarbon fluid production method using the hydrocarbon fluid treatment plant. More specifically, some aspects of the invention relate to a natural gas liquefaction plant, a method for designing a natural gas liquefaction plant, a method for operating a natural gas liquefaction plant, and a method for producing LNG using the natural gas liquefaction plant. To do. One aspect of the present invention includes a hydrocarbon fluid processing plant that includes a plurality of processing unit module types, the plurality of processing unit module types including one or more first processing unit modules. Including at least one first processing unit module type and a second processing unit module type containing two or more integrated second processing unit modules, wherein at least one of the first The at least one processing unit module and the at least one second processing unit module are sized to have a substantially maximum processing efficiency.

Description

(Mutual reference with related applications)
This patent application claims the benefit of US Provisional Patent Application No. 60 / 580,746, filed June 18, 2004.

(Field of Invention)
The present invention relates to a hydrocarbon fluid treatment plant, a hydrocarbon fluid treatment plant design method, a hydrocarbon fluid treatment plant operation method, and a hydrocarbon fluid production method using the hydrocarbon fluid treatment plant. More particularly, some embodiments of the present invention relate to a natural gas liquefaction plant, a method for designing a natural gas liquefaction plant, a method for operating a natural gas liquefaction plant, and a method for producing LNG using the natural gas liquefaction plant.

(background)
A large volume of natural gas (ie, mainly methane) is localized in remote areas of the world. This gas will have enormous value if it can be economically transported to the market. If the gas reserve is located reasonably close to the market and the topography between these two regions allows, typically the gas is produced and then buried and / or Transport to the market through a ground-mounted pipeline. However, if the gas is produced in a location where pipeline laying is not feasible or economically impossible, other technologies will be used to send this gas to the market. There is a need.

  For the purpose of transporting gases other than pipelines, a commonly used technique is to liquefy the gas at or near the gas production site and then pack the liquefied gas into a special storage tank, Includes shipping to the market with loadable shipping containers. The natural gas is cooled and condensed to its liquid state to produce liquefied natural gas (LNG). LNG is typically, but not always, transported at substantially atmospheric pressure and at temperatures of about -162 ° C (-260 ° F), resulting in certain storage tanks on the means of transport. The amount of gas that can be stored within is greatly increased. Once the LNG vehicle has arrived at its destination, the LNG is typically packed into other storage tanks, and the gas is re-vaporized from the tanks as needed, as a gas to the end user. It is transported through a pipeline. Transportation by LNG has become an increasingly popular transportation method using natural gas to supply major energy-consuming countries.

  Processing plants used to liquefy natural gas are being built in stages as the quality of the feed gas, ie the supply of natural gas and the gas contracted for sale, increases. One traditional way to build an LNG processing plant is to build the plant site as several incrementals, or parallel trains. Each stage of assembly can consist of a separate, independent line of equipment, which results in liquefying the feed gas stream into LNG and transporting it for storage, Consists of all individual processing units or stages. Each device row can function as an independent production facility. The size of the device train can depend largely on the extent of the resource quantity, the technology and equipment used in the device train, and the available investment funds in the development of this project.

  Traditional LNG plant trains are typically designed to operate at selected natural gas feedstock processing rates and are usually not able to operate at significantly reduced natural gas feedstock processing rates. Not designed that way. This lack of flexibility in processing natural gas feed rates reduces the ability of traditional LNG plant trains to adapt to changing commercial conditions. This lack of flexibility in natural gas feed rate processing results in a narrow operating range for traditional LNG plant trains.

  Due to the increasing demand seen in recent years, a significant emphasis is placed on the cost and schedule efficiency of new gas liquefaction projects in order to reduce the cost of the gas supplied. Large natural gas liquefaction projects expose developers to significant commercial risks because of the huge initial capital costs of these projects ($ 5 billion or more). Improvements in cost, design, and schedule efficiency can help mitigate significant commercial risks associated with large LNG development projects.

(wrap up)
One aspect of the present invention includes a hydrocarbon fluid processing plant including a plurality of processing unit module types, wherein the plurality of processing unit module types includes at least one or more first processing unit modules. A first processing unit module type, and a second processing unit module type comprising two or more integrated second processing unit modules, wherein at least one first processing unit module and at least one The second processing unit modules are sized so as to obtain a substantially maximum processing efficiency.

  Another aspect of the present invention includes a method for designing a hydrocarbon fluid treatment plant, the method comprising: A) identifying a plurality of treatment unit module types contained within the hydrocarbon fluid treatment plant Wherein the plurality of processing unit module types includes at least a first processing unit module type and a second processing unit module type; B) a first processing unit of the first processing unit module type Determining a first maximum processing efficiency for a module and a second maximum processing efficiency for a second processing unit module of the second processing unit module type; and C) designing the hydrocarbon fluid processing plant The hydrocarbon fluid processing plant design has a size that substantially satisfies the first maximum processing efficiency; A processing unit module and one or more second processing unit modules having a size that substantially satisfies the second maximum processing efficiency.

  Another aspect of the present invention includes a method for designing an extended capacity of a hydrocarbon fluid processing plant having an existing plant maximum feed capacity, which includes the steps listed below: A) Preparing an existing configuration of the hydrocarbon fluid processing plant, wherein the hydrocarbon fluid processing plant includes a plurality of processing unit module types; B) requiring additional maximum feedstock processing capacity; Determining a maximum processing efficiency of the first processing unit module of the first processing unit module type; and determining a maximum processing efficiency of the first processing unit module of the first processing unit module type; And D) designing an expanded hydrocarbon fluid treatment plant, the design comprising one or more first treatments having a size that substantially satisfies the maximum treatment efficiency. Including the addition of unit modules.

  Another aspect of the invention encompasses a method of operating a hydrocarbon fluid processing plant that includes a plurality of processing unit module types, wherein the plurality of processing unit module types include one or more first processing units. At least one first processing unit module type comprised of unit modules and at least one second processing unit module type comprised of two or more integrated second processing unit modules. And the at least one second processing unit module are sized to take substantially maximum processing capacity of each, and the method includes the steps listed below: A) Measuring a plant feedstock processing rate; B) each processing unit required to meet the first plant feedstock processing rate. Determining the number of processing unit modules of the module type; C) at least the number determined in step B) of each processing unit module type required to satisfy the first plant feedstock processing rate. Putting the unit module into operation; and D) producing a hydrocarbon fluid product.

  Another aspect of the present invention includes a method of producing a hydrocarbon fluid using a hydrocarbon fluid processing plant, the hydrocarbon fluid processing plant being configured with a plurality of processing unit module types, the plurality of processing Each unit module type is composed of one or more processing unit modules, and the method includes the following steps: A) For each processing unit module type included in the plurality of processing unit module types Providing at least one raw processing unit module, wherein one or more of the raw processing unit modules are each sized to obtain a substantially maximum processing efficiency, resulting in a first A staged hydrocarbon fluid treatment plant; B) one or more treatment unit modules included in the first stage hydrocarbon fluid treatment plant; Providing one or more additional processing unit modules to the module type, wherein the additional processing unit module is integrated with the original processing unit module within the processing unit module type, and as a result Providing a second stage hydrocarbon fluid treatment plant; and C) producing a hydrocarbon fluid from the second stage hydrocarbon fluid treatment plant.

  Another aspect of the present invention includes a method for producing liquefied natural gas, the method comprising the following steps: A) preparing a LNG liquefaction plant having a plurality of product sizes and including a processing unit module type, wherein The LNG liquefaction plant has a first plant maximum feed capacity; B) at least one of the processing unit module types having the product size, but less than all of the maximum supply Extending the material throughput to achieve a second plant maximum feed throughput that is 10% or more of the first plant maximum feed throughput; and C) starting the expansion phase (B) And a step of producing LNG in the LNG liquefaction plant.

  Another aspect of the present invention includes a method for producing liquefied natural gas using an LNG liquefaction plant, wherein the LNG liquefaction plant includes a plurality of processing unit module types, each of the plurality of processing unit module types being The process comprises the following steps: A) At least one original process for each processing unit module type included in the plurality of processing unit module types Providing a unit module and consequently providing a first stage LNG liquefaction plant; B) producing a first LNG from the first stage LNG liquefaction plant; C) to the first stage LNG liquefaction plant; Construct one or more additional processing unit modules for one or more processing unit module types included, while at least one of the manufacturing steps (B) D) placing the one or more additional processing unit modules in operation, wherein the additional processing unit module is within the processing unit module mold and the original processing unit module; Integrated, resulting in a second stage LNG liquefaction plant; and E) producing a second LNG from the second stage LNG liquefaction plant.

  Another aspect of the invention includes an LNG liquefaction plant, which is one or more high construction cost, processing unit module type with product size and one or more low construction costs, Including at least one processing unit module type having a product size, wherein at least one processing unit module type having a product size is at least one processing unit module having a product size. Has a maximum feed capacity of at least 110% of the maximum feed capacity of the mold.

  Another aspect of the present invention includes a method for producing liquefied natural gas, the method comprising: A) preparing an LNG liquefaction plant comprising a plurality of processing unit module types, wherein the LNG liquefaction plant Has at least one first refrigerant circuit, the first refrigerant circuit including at least one first refrigerant compressor service type, wherein the first refrigerant compressor service type is: Consisting of one or more first raw refrigerant compressors in parallel, the LNG liquefaction plant has a plant maximum feedstock capacity; B) at least one additional first refrigerant compressor; Expanding the plant maximum feed capacity of the LNG liquefaction plant by adding to the first refrigerant compressor service type, wherein the additional first refrigerant compressor is the first refrigerant compression Within the machine service type, 1 or Is integrated with the further raw first refrigerant compressor; and C) after the start of the expansion step (B), producing LNG in the LNG liquefaction plant.

  Another aspect of the present invention includes a method for producing liquefied natural gas using an LNG liquefaction plant, wherein the LNG liquefaction plant includes a plurality of processing unit module types, each of the plurality of processing unit module types being The method comprises one or more processing unit modules, and the method includes the steps listed below: A) At least one for each processing unit module type included in the plurality of processing unit module types. Providing a first processing unit module to provide a first stage LNG liquefaction plant; B) at least one second processing unit module for each processing unit module type included in the plurality of processing unit module types; To provide a second stage LNG liquefaction plant; C) 1 for each of two or more treatment unit module types Integrating one or more of the original processing unit modules and one or more of the second processing unit modules; and D) after initiating the integration step (C), the LNG liquefaction plant Manufacturing LNG from

(Detailed explanation)
As used herein and in the claims, the phrase “hydrocarbon fluid processing plant” refers to any process that processes a hydrocarbon fluid feed and converts it from the feed to a product that has undergone some change. Means plant. For example, the feed can be a variation in composition, physical state, and / or combination of physical state and composition. An example of a hydrocarbon fluid treatment plant is an LNG liquefaction plant.

  As used herein and in the claims, the phrase “LNG liquefaction plant” refers to a carbonization process that includes processing a gaseous methane-containing feed stream to convert it to a product stream containing liquid methane. Means a hydrogen fluid treatment plant. For example, an LNG liquefaction plant can include a cryogenic heat exchanger, a refrigerant compressor, and / or an expansion stage. The LNG liquefaction plant can optionally include other fluid treatment stages. Non-limiting examples of optional fluid treatment stages include feed purification process stages (liquid removal, hydrogen sulfide removal, carbon dioxide removal, dehydration), product purification stages (helium removal, nitrogen removal). , Including production stages of products other than methane (deethanization, depropanation, sulfur recovery). An example of an LNG liquefaction plant is that a gaseous feed stream containing methane, ethane, carbon dioxide, hydrogen sulfide and other species is reduced in volume compared to methane and the feed stream. Including plants that convert to liquefied natural gas, including some other non-methane species.

  As used herein and in the claims, the phrase “equipment types” refers to any type of processing device used in any type of processing unit module. Non-limiting examples of equipment types include compressors, heat exchangers, distillation columns, flash drums, reactors, pumps, expanders, gas turbines, electric motors, combustion heaters, liquid / gas contactors, liquid / gas Includes separation drums and other processing equipment used in hydrocarbon fluid processing plants.

  As used herein and in the claims, the phrase “process unit module” means a group of one or more device types that are grouped together. In some cases, a specific function is completed in a hydrocarbon fluid treatment plant, or the achievement of the corresponding function in a hydrocarbon fluid treatment plant is maintained. For example, such functions include changing the temperature, pressure, composition, physical state and / or combination of temperature, pressure, physical state and composition of a material. Furthermore, processing units that maintain these functions include processing units that supply, for example, electricity, steam, and / or cooling water to a processing unit that completes a processing stage. Non-limiting examples of processing unit modules include utility units, gas preheating units, slag collection units, exhaust gas compressor units, condensate stabilization units, acid gas removal contactor units, acid gases Removal regenerator unit, sulfur recovery unit, dehydration unit, deethanization unit, depropanation unit, fractionation unit, precooling heat exchanger unit, cryogenic heat exchanger unit, refrigerant compressor unit, nitrogen rejection unit, cogeneration (cogeneration) units, liquefaction units, helium recovery units, compression units, refrigerant production units, and combinations thereof.

  As used herein and in the claims, the phrase “process unit module type” means the total amount (number) of a particular type of processing unit module in a hydrocarbon fluid processing plant. The processing unit module type is made up of one or more processing unit modules. For example, a particular processing unit module type can consist of a number of processing unit modules in parallel, each processing unit module having the ability to perform the same processing stage.

  As used herein and in the claims, the phrase “maximum feed processing capacity” is included within a hydrocarbon fluid processing plant based on the feed to the hydrocarbon fluid processing plant. , Meaning maximum processing capacity for a particular processing unit module type. The maximum feedstock processing capacity represents the supply to the hydrocarbon fluid processing plant, which may be different from the supply to the specific processing unit module type and has the capacity of the specific processing unit module type Can be processed by a hydrocarbon fluid processing plant. For example, a hydrocarbon fluid processing plant has three processing unit module types A, B and C. When processing unit module type A is operated at its full capacity, while the hydrocarbon fluid processing plant is operated with 100 units of feed, the maximum feed capacity of the processing unit module type A is 100 units. It is. This is true even when the processing unit module type A actually processes 150 units of intermediate flow, 50 units of intermediate flow or 0 units of intermediate flow. Furthermore, the processing unit module type B is not operating at its full capacity, while the hydrocarbon fluid processing plant is operated in 100 feedstock units, and the processing unit module type B is a hydrocarbon fluid processing plant. The maximum supply material for this processing unit module type B if it is in a 10% no-load condition (meaning that this processing unit module type B can operate at a higher capacity by 10%) It can be said that the processing capacity is 110 units.

  The phrase “plant maximum feed processing capacity” as used herein and in the claims means the maximum feed capacity of the overall hydrocarbon fluid processing plant.

  As used herein and in the claims, the phrase “plant minimum feed processing capacity” refers to the overall hydrocarbon fluid processing plant that can operate in a stable mode of operation. Means minimum feed capacity. A stable operating mode is a mode in which the control system effectively controls the relevant process variables and the device type operates at substantially its design efficiency. For example, in a stable mode of operation, the distillation column can achieve a substantially predetermined degree of separation, and the compressor can generate a substantially predetermined head without entering the surge mode. it can.

  As used herein and in the claims, the phrase “construction cost” refers to an item, such as a processing unit module or a processing unit module type, where the module is already operational. It means the total cost at such a position. The construction cost includes manufacturing cost, equipment cost, device cost, procurement cost, license acquisition cost, training cost, trial operation cost, and the like.

  As used herein and in the claims, the phrase “construction cost per unit of maximum feed capacity” refers to “maximum feed capacity” for an item, eg, a process unit module or a process unit module type. It means the above "construction cost" divided.

  As used herein and in the claims, the phrase “maximum processing efficiency” refers to the capacity size of a processing unit module with respect to a processing unit module type that minimizes the cost per unit of processing unit module capacity. Where the cost can be selected from total processing module construction cost, total processing unit module operating cost, total processing unit module life cycle cost, or a combination thereof.

  The phrase “life cycle cost” as used herein and in the claims refers to a comprehensive measure of the construction cost and the operating cost of the device type or processing unit module. For example, the life cycle cost can be represented by a commonly accepted present value, where the construction cost value is substantially represented by a commonly accepted present value and is equivalent to the operating cost. The present value can be calculated in a manner known to those skilled in the art by taking into account the time value of money and adjusting for future declines in the present value.

  In the present specification and claims, the term “integrated” as used for a processing unit module type means that the processing unit module type is composed of a plurality of processing unit modules in a parallel relationship. Each processing unit module provides a portion of the maximum feedstock processing capacity of the processing unit module type, and the processing unit module type includes each processing unit module 1) of the feedstock of the hydrocarbon fluid processing plant. Any part, any part of the hydrocarbon fluid treatment plant product, or any part of a specific intermediate stream of the hydrocarbon fluid treatment plant, and / or 2) the hydrocarbon fluid treatment plant And / or 3) of the hydrocarbon fluid treatment plant, and / or It is formed in a shape that can complete any part of a specific support service for a physical unit module type, a plurality of processing unit modules or a plurality of device types. In both 2 and 3, the origin of each feed, product, intermediate flow, processing stage, processing unit module type, multiple processing unit modules or multiple device types are not relevant.

  As used herein and in the claims, the phrase “product sized processing unit module type” refers to the product stream whose capacity (size) is primarily the most valuable for the hydrocarbon fluid processing plant. Means processing unit module type, determined by percentage. The most valuable product stream is the product stream that produces the largest total revenue (eg, market price × production volume; it need not be the product with the largest value per unit of quantity). For example, for an LNG liquefaction plant, the most valuable product stream is the LNG product stream. Non-limiting examples of processing unit module types with product sizes for LNG liquefaction plants include acid gas removal contactor units, dehydration units, deethanizer units, cryogenic heat exchanger units, refrigerant compressor units, nitrogen Includes an exclusion unit, a liquefaction unit, a helium recovery unit, and combinations thereof. Non-limiting examples of processing unit module types that are not processing unit module types with product sizes for LNG liquefaction plants include utility units, sulfur recovery units, cogeneration units, gas preheating units, slag collection units, Includes exhaust gas compressor unit, condensate stabilization unit, acid gas removal regenerator unit, and fractionation unit.

  As used herein and in the claims, the phrase “processing unit modular with high build cost product size” refers to the cost of building a hydrocarbon fluid treatment plant including such a processing unit, 10 This means a processing unit module type with product size that occupies more than%.

  As used herein and in the claims, the phrase “processing unit module type with low construction cost product size” refers to the cost of constructing a hydrocarbon fluid processing plant comprising such processing units, 7 It means a processing unit module type with a product size that occupies less than%.

  As used herein and in the claims, the phrase “transport container” means any container capable of transporting a hydrocarbon fluid product over land or over water. A transport container may include one or more diesel vehicles, tanker trucks, barges, ships or other means of traveling on land or water.

  As used herein and in the claims, the phrase “capital cost basis” means any cost basis that represents capital and non-capital costs on a capital cost equivalent basis. Capital costs typically represent costs for design, procurement, construction, and equipment installation, as well as any other costs incurred by the project prior to the initial start-up of the plant or plant improvement. Non-capital costs, such as continuous operating costs, determine the cost of capital that will function by determining the “present value” of such continuous costs or as the same economic benefit as the continuous costs. Can be converted into the capital cost equivalent. These economic evaluation techniques are commonly used by those skilled in the art.

  The phrase “modular heat exchanger” as used herein and in the claims is a type of heat exchanger whose main exchange function is due to the addition of a similarly sized exchanger. It means something that can be easily expanded.

  As used herein and in the claims, the phrase “refrigerant circuit” means a process step in which spent refrigerant is prepared for later use in achieving a cooling function. The refrigerant circuit may include, for example, means for compressing the used refrigerant under high pressure, cooling and condensing the refrigerant under high pressure, and means for reducing (eg, expanding) the pressure of the condensed refrigerant. After leaving the refrigerant circuit, the refrigerant can be put into a heat exchanger that performs a predetermined cooling function.

  As used herein and in the claims, the phrase “operating cost” means any cost incurred during the routine operation of the plant. For example, operating costs include repair costs, salaries and labor costs, chemical and catalyst costs, and other routine plant operating costs.

  One aspect of the present invention includes a hydrocarbon fluid processing plant. The hydrocarbon fluid processing plant can include a plurality of processing unit module types. For illustrative purposes, a general arrangement of one type of hydrocarbon fluid processing plant is briefly described below with reference to FIG. 1 representing an exemplary LNG liquefaction plant.

  The LNG liquefaction plant 45 can consist of several separate processing sections. Exemplary processing compartments include introduction equipment, gas processing, dehydration, gas liquefaction, refrigerant compression, and refrigerant preparation compartments, each of which can be implemented in one or more processing unit module types. This concept can be most easily explained using the example of an LNG liquefaction plant included in FIG.

  The feed gas is received at the introduction facility, which removes water as a liquid and any hydrocarbon liquid (condensate) that may be present. This introduction facility can also stabilize the condensate in commercially available products. The introduction equipment also includes an exhaust gas compression unit 30 for returning the exhaust gas of the slag capturing unit 30, various separation containers (not shown), the condensate stabilization unit 31, and the condensate stabilization device to the main gas stream. And a supply gas preheating unit 32 may be included. The feed stream is first passed through the slag trap and separator (not shown) to remove most of the components that tend to cause freezing and clogging problems in cryogenic processing. The condensed liquid (gas condensate) separated from the gas stream is generally under high pressure, for example below about 3.445 MPa to 6.89 MPa gauge pressure (500 to 1000 psig) or more, and a significant amount of dissolution. Methane and ethane. For transport as well as later use, the condensate is typically stabilized in the condensate stabilization unit 31, ie its vapor pressure is typically reduced to below atmospheric pressure. The removal of light hydrocarbons to reduce the vapor pressure not only increases the calorific value of the condensed product, but also changes the pressure and temperature of the condensate during its transportation and storage, so that It also reduces potential problems caused by exhaust gas treatment of the components.

The main processing functional areas in the gas processing and dehydration section are acid gas removal (AGR) (including AGR contactor unit 33 and AGR regenerator unit 34), mercury absorbent (not shown), and dehydration unit 35. is there. Various methods are used to treat the gas and remove acid gases (H ₂ S and CO ₂ ). One method for treating a sour gas stream includes contacting the gas stream with a solvent (e.g., an organic amine, such as methyldiethanolamine, and other additives) in a contactor vessel, the solvent comprising: Absorb the acid gases and carry them away from the gas stream.

In order for this type of process to be economical, the “rich” solvent should be regenerated in the AGR regenerator unit 34 so that it can be reused in the process. . That is, the acid gas (both H ₂ S and CO ₂ ) and hydrocarbons in the dense solvent are removed or substantially reduced prior to reuse in the process. The dense solvent can be regenerated by passing it through a regenerator vessel that removes substantially all of the acid gas, after which the regenerated solvent is used for the processing step. Returned there. Next, the recovered acid gas stream is treated with a sulfur recovery unit (SRU) 38 to recover the sulfur product from H ₂ S.

The dehydration unit 35 removes H ₂ O to a dew point level compatible with the LNG product of about −127 ° C. (−260 ° F.) using, for example, molecular sieving and / or glycol treatment. The dehydration adsorption vessel is generally comprised of vessels that are in parallel relationship, and these cycle the feed gas from dehydration to regeneration mode.

  The gas liquefaction section 37 generally cools the natural gas stream from about ambient to cryogenic by heat exchange with one or more cryogenic heat exchangers and optionally one or more refrigerants. Including one or more pre-cooling heat exchanger units. The cryogenic heat exchanger used in the cryogenic heat exchanger unit can be, for example, a spiral heat exchanger, often referred to as a spool heat exchanger, or a plate-fin heat exchanger made of brazed aluminum. .

  The refrigerant compressor unit (not shown) collects the evaporated refrigerant coming out of the cryogenic heat exchanger and / or the precooling heat exchanger, which is sufficient for its condensation and reuse. Compress to proper pressure. An LNG liquefaction plant can have one or more refrigerant compression circuits that can use single component refrigerants (eg, propane or mixed refrigerants (eg, methane, ethane and propane). Two or more refrigerant circuits. Each circuit can cool and condense the natural gas stream in a series, parallel or cascade arrangement, in which one refrigerant circuit is connected to the second refrigerant circuit. Used for cooling of the second refrigerant, the second refrigerant sequentially cools the natural gas stream.

  Many cooling cycles can be used to cool natural gas, but further illustrate the following three types of cycles: (1) Heat arranged stepwise to reduce the temperature of the gas to the liquefaction temperature A “cascade cycle” using multiple single component refrigerants in the exchanger; (2) an “expander cycle” that expands the gas from high pressure to low pressure with a corresponding decrease in temperature; and (3) heat “Multi-component cooling cycle” using multi-component refrigerant in the exchanger. Most natural gas liquefaction cycles use variations or combinations of these three basic types.

  Gas liquefaction systems using mixed refrigerants typically involve circulation of a multicomponent refrigerant stream after precooling with propane or another mixed refrigerant. Exemplary multicomponent systems can include methane, ethane, propane and optionally other light components. Without precooling, heavy components such as butane and pentane can be included in the multicomponent refrigerant. Mixed refrigerants exhibit the desired property of condensing and evaporating over a range of temperatures, which can be thermodynamically more efficient than a pure component refrigerant system. Enable design.

  The refrigerant preparation unit (not shown) includes one or more distillation columns, which use some or all of the refrigerant used in the liquefaction unit 37 from the feed gas, such as ethane, propane, etc. A product can be produced that can be used to construct

Another optional component of the gas liquefaction section 37 or another independent unit is a distillation tower such as a scrub tower (not shown), a demethanizer (not shown), or a deethanizer 36. This has the function of removing pentane and heavier components from at least the feed gas and preventing freezing in the cryogenic heat exchanger. Some plants use a demethanizer or deethanizer unit 36 instead to produce some natural gas liquid as a separate product. Natural gas leaving the dehydration unit 35 may be separated. In this outline, some of the C ₃₊ hydrocarbons are separated from the natural gas by a deethanizing distillation column. The light fraction collected at the top of the deethanizing distillation column is passed through a liquefaction unit 37. The liquid fraction collected at the bottom of the deethanization distillation column is sent to a fractionation unit 40 for recovery of C ₃ / C ₄ liquid petroleum gas (LPG) and C ₄₊ liquid (condensate). This arrangement is preferred when the LPG product is to be sold separately. If the feed gas has a low LPG content or if the LPG has a low value, the deethanizer tower is scrubbed to remove pentane and heavier hydrocarbons to a specified level. It can be replaced with a tower.

The LNG plant may also include a sulfur recovery unit (SEU) 38 and a nitrogen rejection unit (NRU) 39, and possibly a helium recovery unit (HRU) 39. Several methods have been developed for the direct conversion of H ₂ S to elemental sulfur. Most conversion methods are based on oxidation-reduction reactions that convert H ₂ S directly to sulfur. In large liquefier trains, H ₂ S is converted to sulfur by “burning” a portion of the acid gas stream with air in a reactor using the Claus method. In this method, SO ₂ is given to the reaction with H ₂ S that has not been burned, and elemental sulfur is formed by the Claus reaction: 2H ₂ S + SO ₂ → 3 / 2S ₂ + 2H ₂ O.

  At the end of this liquefaction process 37, the LNG can be processed for nitrogen removal (NRU) and, if any, possibly helium recovery (HRU) 39. A method for achieving this purification can be provided by the authorizer. Most of the nitrogen that may be present in natural gas is typically removed after liquefaction. This is because nitrogen is not included in the liquid phase during conventional LNG transport, and the presence of nitrogen in the LNG at the time of distribution is undesirable from a sales specification standpoint. For storage and / or transportation, the pressure of the liquefied natural gas is usually reduced to approximately atmospheric pressure. Such a pressure drop, often referred to as an “end flash” decrease, gives end flash gas and LNG. One advantage of such end flash reduction is that low boiling components, such as nitrogen and helium, are at least partially removed from the LNG along with some methane. The end flash gas can be used as a fuel gas in a mechanically driven gas turbine or in a power plant 41. The recovery of the helium is an optional operation that depends on the amount of helium in the natural gas feed stream and the market value of helium.

  The cogeneration unit 41 can be utilized to reduce costs associated with energy use in commercial and industrial operations. In the exemplary cogeneration unit 41, a mechanically driven gas turbine, or generator, such as a gas-combustion turbine driven generator, that drives a cooling compressor, generates electricity to meet the electrical demand of the plant. Used to generate. Any excess power generated can be sold to the power company or used in the LNG plant, and power is only to the extent necessary to replenish the amount of power generated by the cogeneration unit 41. Buy from a power company. Waste, such as heat loss, is reduced by utilizing the heat generated as a result of power production supplied for, or at least contributed to, heating and / or cooling of the plant. The heat generated as a result of the operation of the gas-combustion turbine can be recovered from the exhaust gas by a heat exchanger and used, for example, for steam generation, to meet the heat demand of the plant. Alternatively, the steam generated from this process is used to generate more electricity in the steam-driven turbine generator.

  One aspect of the present invention includes the design of a hydrocarbon fluid processing plant, such as an LNG liquefaction plant, that is cost effective and can be expanded at any plant capacity. In another embodiment of the invention, a portion of the plant can be completed and put into operation while an extension of this same plant can be built. Such an arrangement allows hydrocarbon production to begin earlier than would be allowed if the entire system was built at once, thus improving the overall economics of the project. This type of arrangement transforms the concept of an instrument array into an advantage of a larger, integrated plant that makes it easier to achieve the economic benefits of scale. Some aspects of the invention are particularly applicable to LNG projects that are planned for large resources, where initial equipment trains are built and later expanded. Such a development plan can be achieved with some upfront investment in the initial construction phase, which has the advantage of shortening the schedule required for the expansion.

  One way to design, build and / or operate a cost effective hydrocarbon fluid processing plant is to use one or more processing unit modules, one or more processing unit modules, Including designing for substantially maximum processing efficiency. The maximum processing efficiency of a processing unit module is the construction cost of the entire processing unit module, the processing cost of all processing unit modules per unit of processing unit module capacity, any one or more per unit of processing unit module capacity, The capacity of the processing unit module, or the size of the processing unit module type, that minimizes the life cycle cost of the entire processing unit module, or a combination of these costs, per unit of processing unit module capacity. Preferably, the maximum processing efficiency is determined for the life cycle cost of the entire processing unit module per unit of processing unit module capacity because this measure spans the entire life of such a plant. It is best suited to achieve the lowest overall cost for a hydrocarbon fluid treatment plant. The life cycle cost is a measure obtained by combining the construction cost and the operation cost of the apparatus type or the processing unit module. Whatever cost measure is used, it is preferable to adjust the cost on a capital cost basis. Non-capital costs, such as continuous operating costs, can also be compared to capital costs by determining the “present value” of such continuous costs, which is commonly used by those skilled in the art. Technology. The substantially maximum processing efficiency is also within 25% of the actual maximum processing efficiency. Alternatively, the substantially maximum processing efficiency is within 20%, within 15%, within 10% or within 5% of the actual maximum processing efficiency.

  In order to determine the maximum processing efficiency of the processing unit module, the relationship between cost and design capacity for one or more equipment items is determined. This relationship explains the design limits for these device types due to the addition of devices in parallel when the design limits for a single device are reached. The total cost for the processing unit module can include the sum of the main equipment costs, secondary equipment costs and installation costs. The last two costs are usually expressed as part of the main equipment cost based on similar modules actually built in the past. Installation costs include costs for other hardware parts such as pipes, valves and fittings, labor costs for installation, and incidental items such as consumables and tools for welding. For example, the main equipment type of the processing unit module of the deethanizer may consist of a distillation column, several heat exchangers, a separator drum, and a pump. Once the cost-capacity relationship is determined, the maximum processing efficiency can be found by defining a minimum cost per processing unit module capacity by any standard optimization technique. For example, for a complex processing unit module, the single most expensive device can be used as an approximation of the overall processing unit module cost. Alternatively, multiple devices of multiple equipment type can be used to approximate the overall processing unit module cost. Preferably, one or more high construction cost equipment types can be used. For example, the processing unit module of the deethanizer may consist of a distillation column, several heat exchangers, a separator drum, and a pump. The most expensive equipment item in this module can be a deethanizer, which can be used to approximate the overall cost-capacity relationship of this module. Once this cost-capacity relationship is determined or approximated, standard optimization techniques can find its maximum processing efficiency to provide a minimum cost per processing unit module capacity. The maximum processing efficiency will show a trend towards greater production capacity until some cost, manufacturing, material, transportation, or installation limit is reached. For example, the size of a cryogenic heat exchanger may be limited by its manufacturing technology and / or equipment transport limitations. In search of higher production capacities than can be achieved with a single cryogenic exchanger, the construction of an LNG plant would require the use of two small exchangers in parallel. This division of exchanger operation and the use of smaller exchangers negates the natural economic benefits of scale.

  This design principle has been explored to determine the optimum size for each processing unit module type processing unit module included in the selected hydrocarbon fluid processing plant. Once the optimal size has been determined, multiple processing unit modules of the processing unit module type, designed to take practically maximum processing efficiency, are initially being built during the first stage of the plant, Alternatively, if an existing plant is expanded to provide additional feed throughput for a particular processing unit module type, it can be integrated into a parallel unit with a large production capacity. Build and operate a more economical plant by designing two or more of the processing unit module types to include processing unit modules that have substantially maximum processing efficiency, It can also be extended to meet market requirements.

  The previous design principle is to design and build the most expensive equipment that is large enough to meet a given plant throughput, and then to meet the production capacity of the most expensive equipment The focus was on designing devices and units. One aspect of the invention designs processing unit modules of multiple processing unit module types that abandon this previous design principle and take their substantially maximum processing efficiency. Once the optimal processing efficiency of a processing unit module type is determined, one or more of the processing unit modules are included in the design to meet a given plant maximum feed capacity of the hydrocarbon fluid processing plant be able to. The design methodology discussed here can also be applied to expand the production capacity of existing hydrocarbon fluid processing plants. Existing hydrocarbon fluid processing plants can also be expanded by adding one or more additional processing unit modules to the existing processing unit modules before or after being put into operation. The unit module-type maximum feed capacity can be expanded.

In another aspect, multiple processing unit modules can be integrated such that the multiple processing unit modules function as a single common processing unit within the hydrocarbon fluid processing plant. Examples of particular types of integration include processing unit modules integrated in a parallel relationship and / or integrated internally. Integration in parallel includes, for example, a situation where two or more processing unit modules are distributed into one or more common inlet streams and one or more common outlet streams. Internal integration includes one or more processing unit modules including several device types that share, for example, one or more common inlet streams and one or more common outlet streams. FIG. 2A is a schematic representation showing an exemplary processing unit configuration for one integrated acid gas removal contactor unit that may be part of an LNG liquefaction plant. FIG. 2A shows a common feed gas stream 11 containing sour natural gas (that includes carbon dioxide (CO ₂ ) and hydrogen sulfide (H ₂ S)) entering the acid gas removal contactor unit 10. It is to depict. As can be seen from this figure, the illustrated acid gas removal contactor unit 10 is actually composed of two integrated processing unit modules in a parallel relationship. After being split, the feed stream flows into the first heat exchangers 12 and 12a of each processing unit module for heating before entering the solvent contactors 13 and 13a. In the solvent contactors 13 and 13a, the gaseous feed stream 11 is placed in contact with a lean solvent 14. This solvent 14 can be, for example, an amine solvent and is depicted as entering the acid gas removal contactor unit 10 as one stream prior to splitting, and in each acid gas removal contactor unit module. Sent. In the solvent contactors 13 and 13a, the acid gas (H ₂ S gas, other sulfur-containing components, and / or CO ₂ ) contained in the feed stream 11 is dissolved in the liquid solvent 14. The remaining gaseous hydrocarbon portion of the feed stream exits as the sweet natural gas stream 20 from the top of the solvent contactor. After leaving each acid gas contactor, each natural gas stream is merged into a single sweet natural gas stream 20. The rough cut rich solvents 16 and 16a (ie, containing acid gas, some methane and solvent) exit the bottom of the solvent contactors 13 and 13a and enter flash drums 15 and 15a . In the flash drums 15 and 15a, the proportion of the rough cut rich solvents 16 and 16a is reduced, resulting in a methane-containing flash gas that can be used as the fuel gas 21 for the plant. After exiting each flash drum 15 and 15a, each fuel gas stream is merged into a single fuel gas stream 21. The liquid streams 17 and 17a exiting the flash drums 15 and 15a are composed of rich solvent (i.e. containing acid gas and solvent) and also flow into the second heat exchangers 18 and 18a, where the The liquid streams 17 and 17a are heated prior to leaving the acid gas removal contactor unit 10 for regeneration in an acid gas removal regeneration unit (not shown). Following regeneration, the hot anti-solvent 14 is passed through the second heat exchangers 18 and 18a where the anti-solvent 14 heats the liquid streams 17 and 17a exiting the flash drums 15 and 15a. Cooled by replacement. The poor solvent 14 is further cooled by fin-fan heat exchangers 19 and 19a before being pumped to the solvent contactors 13 and 13a by pumps 20 and 20a. FIG. 2B depicts a second exemplary acid gas removal contactor unit 10, which includes processing unit modules integrated in three parallel relationships. 2A and 2B show two examples for processing unit modules integrated in a parallel relationship. The level of integration in the processing unit module type can vary and the examples depicted in FIGS. 2A and 2B are not meant to be limiting of the invention. Further, the acid gas removal contactor unit shown in FIGS. 2A and 2B is an example relating to the flow diagram and arrangement of one particular acid gas removal contactor unit and is intended to limit the invention It is not a thing. Integration of processing unit modules, flow diagrams of acid gas removal contactor units and arrangements of devices in other manners are also intended to be included within the scope of the present invention.

  By integrating a number of processing unit modules within the processing unit module type, high operational flexibility can be obtained. In another embodiment, two or more processing unit module types are integrated. In yet another embodiment, three, four, five, six or all processing unit module types of a hydrocarbon fluid processing plant are integrated.

  A hydrocarbon fluid processing plant designed and constructed to include multiple processing unit module types, made of one or more processing unit modules, designed for substantially maximum processing efficiency Can include processing unit module types, each with a different maximum feed capacity. These different processing unit modules are designed to target economic efficiency, as opposed to targeting capacity matching, so that each processing unit module type does not necessarily have the same maximum feed capacity. It doesn't have to be a thing. In another embodiment of the present invention, the maximum feed capacity of different processing unit module types may differ by more than 10%. In another embodiment, one processing unit module type may have a maximum feed capacity that is less than 85% or 80% of the second and / or third processing unit module type.

  In another aspect of the invention, the maximum processing efficiency is determined for one processing unit module type and a standardized processing unit configuration is determined. Two processing unit modules formed in substantially the same shape are processing unit modules having substantially the same general processing flow diagram. For example, a processing flow diagram for a processing unit module includes at least an arrangement of device types and an arrangement of flow paths for transporting the processing fluid within the device type. The standardized processing unit configuration can thus be repeated for a number of processing unit modules with respect to the processing unit module type in a hydrocarbon fluid processing plant. Preferably, the standardized processing unit configuration also has a standardized size or capability. Processing unit modules having substantially the same size are preferably processing unit modules having the same processing capacity. Alternatively, processing unit modules with equal sizes are processing unit modules whose capabilities are within 15% of each other. Alternatively, the ability is within 10%, 5% or 2% of each other. In this way, standardized processing unit modules are repeated in parallel to expand the maximum supply material processing capacity of the processing unit module type in the originally designed or constructed plant, or the plant maximum supply of an existing plant. Material processing capacity can be expanded. In any case, the individual standardized processing unit modules are preferably integrated to provide operational flexibility.

  A processing unit module can be configured with one or more different device types. In one alternative embodiment of the present invention, the device molds that form standardized processing unit modules are formed with substantially equal sizes and / or substantially equal shapes. Two devices having substantially the same size mean that the two devices have approximately the same processing capacity. Preferably, the capabilities are within 15% of each other. Alternatively, the ability is within 10%, 5% or 2% of each other. Devices formed of two substantially equal shapes are of essentially the same design. If two devices are manufactured and installed at different points in time, the manufacturer of the device can expect increasing changes or improvements to the device, but these two devices It should be kept of essentially the same design to the extent that relative compatibility is maintained.

  By standardizing the processing unit module and / or the equipment type that includes the processing unit module, a hydrocarbon fluid processing plant designer, builder, or operator may achieve a more cost effective plant. For example, a plant designer may design a single processing unit module and repeat it to reach the maximum feed capacity of a given processing unit module type, resulting in reduced design costs. it can. In essence, the design of the processing unit module can be reused many times. By obtaining a large number of several identical equipment types at a lower purchase price, cost savings can be realized when a plant is built using standardized processing unit modules. Furthermore, competitive bidding can be used to achieve lower costs by determining the device size that can be obtained by many manufacturers. For example, a plant designer or builder may require some sort of high-capacity processing unit module or equipment type, and only one or a limited number of manufacturers for a large size equipment type. If only present, the predetermined capacity can be achieved by using a number of smaller capacity devices that can be supplied by a number of manufacturers. Thus, the overall device cost for a given capability can actually be reduced by purchasing a number of smaller capability devices. Additionally, common spare parts can be stocked for unscheduled repairs to reduce or delay the purchase of replacement parts. Cost savings can be realized when the plant is operated using standardized processing unit modules and / or equipment types, because the plant operator can maneuver it. And only need to be trained on how to repair a limited number of processing unit modules and / or device types.

  In another aspect of the present invention, a hydrocarbon fluid processing plant is provided that has considerable feed throughput flexibility. A hydrocarbon fluid processing plant, including a processing unit module type, composed of a number of integrated processing unit modules, can have considerable plant feedstock processing capacity flexibility. For example, one processing unit module type consisting of four equal sized, integrated processing unit modules can be configured by placing one or more respective processing unit modules in service or on line The shut-off allowed stable operation at at least 25%, 50%, 75% and 100% of its maximum feed capacity. When multiple processing unit module types are configured with multiple processing unit modules, each processing unit module type can also operate with multiple feed material throughputs. The flexibility of additional feed throughput could be achieved by using multiple integrated device types within a single processing unit module, resulting in additional flexibility in feed throughput. . Alternatively, some processing unit module types may include variable speed (capacity varying) devices as opposed to constant speed (constant capacity) devices. For example, the compressor can be combined with a variable speed electric motor rather than a constant speed gas turbine. In another aspect, the hydrocarbon fluid processing plant may have a plant minimum feed capacity that corresponds to 75% or less of the plant maximum feed capacity. Alternatively, the hydrocarbon fluid treatment plant may provide a plant minimum supply corresponding to 70, 65, 60, 55, 50, 45, 40, 35, 30, or 25% or less of the plant maximum feed capacity. Can have material processing ability.

  The design, construction and operation methods discussed above are particularly suitable for large LNG liquefaction plants and / or LNG liquefaction plants that become large LNG liquefaction plants by increasing their capacity over time. Yes. In one embodiment, the LNG liquefaction plant has a plant maximum feedstock processing capacity (MTA) of greater than 4 million tonnes per year. In another embodiment, the LNG liquefaction plant has a plant maximum feed capacity (MTA) of greater than 5, 6, 7, 8, or 9 million tons per year. In one aspect, the LNG liquefaction plant can be extended over a period of time to become a large LNG liquefaction plant, as previously discussed. In one embodiment, the LNG liquefaction plant starts with a first stage maximum feedstock throughput in the range of 1-5 MTA. In another embodiment, the LNG liquefaction plant starts with a first stage maximum feedstock capacity ranging from 1.5 to 4.5, 2.0 to 4, or 2.5 to 3.5 MTA. In one embodiment, the LNG liquefaction plant is expanded in stages with a step expansion size in increasing plant maximum feed capacity in the range of 1-5 MTA. In another embodiment, the LNG liquefaction plant is expanded in stages with a step expansion size in increasing plant maximum feed capacity in the range of 1.5-4.5, 2.0-4, or 2.5-3.5 MTA. In one embodiment, the LNG liquefaction plant is expanded in a first stage and subsequent 1-6 stages. Alternatively, the LNG liquefaction plant is expanded in the first stage and subsequent 2-5 or 2-3 stages.

  In one aspect of the invention, the maximum feedstock processing capacity of one or more of the processing unit module types included in a hydrocarbon fluid processing plant, but less than all, is expanded. Thereby expanding the plant maximum feedstock throughput of the hydrocarbon fluid treatment plant. In one aspect, the processing unit module type is a product sized processing unit module type. A processing unit module type with a product size is a processing unit module type whose capacity (size) is mainly determined by the most valuable product stream of the hydrocarbon fluid processing plant. In an LNG liquefaction plant, the most valuable product stream is LNG. This embodiment of the invention can be practiced according to one or more of the various aspects of the invention described herein. In one aspect of the invention, an existing hydrocarbon comprising a processing unit module type having one or more product sizes, including a processing unit module having a product size designed for each maximum processing efficiency. A fluid treatment plant is the treatment unit module type having one or more product sizes included in the hydrocarbon fluid treatment plant, but the maximum supply of the treatment unit module type having a product size less than all Expanded by expanding material handling capacity. Hydrocarbons designed or built to include multiple processing unit module types, made up of one or more processing unit modules designed for each maximum processing efficiency, as previously discussed The fluid treatment plant can include treatment unit module types, each with a different maximum feedstock throughput. These different processing unit modules are designed for economic efficiency rather than for capacity matching, so each processing unit module type does not necessarily have the same maximum feed capacity. Need not be. One aspect of the present invention utilizes the unequal maximum feed capacity of different processing unit module types in the expansion of a hydrocarbon fluid processing plant. In this aspect, the plant maximum feedstock processing capacity is additional to the processing unit module type with the product size that requires additional capacity to increase the plant maximum feedstock processing capacity. A processing unit module with one or more product sizes that does not require an additional maximum feedstock processing capacity to add the processing unit module with a product size while increasing the plant maximum feedstock processing capacity The mold can be expanded by not adding processing unit modules with additional product sizes. By utilizing such an expansion plan, the life cycle cost of the hydrocarbon fluid treatment plant can be reduced compared to prior art plans.

  Another aspect is comprised of one or more high build cost, product size processing unit module types and one or more low build cost, product size processing unit module types, At least one of the low build cost, product size processing unit module types including a hydrocarbon fluid processing plant, wherein the high build cost, at least one of the processing unit module types with product size is the largest supply It has a maximum feed throughput that corresponds to at least 110% of the material throughput. This embodiment of the invention can be practiced according to one or more of the various aspects of the invention described herein. This embodiment can be used for an LNG liquefaction plant that produces LNG.

  In another aspect of the invention, the maximum feed capacity of one or more low build cost, product size processing unit module types is the same as that of the high build cost, product size process unit module type. At least 115, 125, 135 or 150% of at least one maximum feed capacity. In another aspect, the high build cost, processing unit module type with product size is the total build per unit of the maximum feedstock processing capacity of the low build cost, process unit module type with product size. With a total build cost per unit of maximum feed capacity that is 1.25, 1.5, 1.75 or 2.0 times the cost. In another aspect, the low build cost, product size processing unit module type is selected from a contactor unit for acid gas removal, a dehydration unit, a fractionation unit, a nitrogen exclusion unit, and a helium recovery unit. In another aspect, the processing unit module type having a product size with a high construction cost comprises an introduction equipment unit (i.e., slag collection unit, gas preheating unit and condensate stabilization unit), refrigerant condenser unit, pole Selected from a low temperature heat exchanger unit and a liquefaction unit.

  In another aspect, the first stage hydrocarbon fluid processing plant can be expanded while the first stage hydrocarbon fluid processing plant can produce a hydrocarbon fluid product. This method can be used for LNG liquefaction plants that produce LNG. In this embodiment, a first stage hydrocarbon fluid processing plant can be provided. This first stage hydrocarbon fluid processing plant is comprised of a plurality of processing unit module types, and each processing unit module type may be comprised of one or more processing unit modules. The method produces one or more processing units that produce a hydrocarbon fluid (e.g., LNG) from the first stage hydrocarbon fluid processing plant while being included in the first stage hydrocarbon fluid processing plant. For a module type, one or more additional processing unit modules can be built. In this method, one or more additional processing unit modules are put into operation, and the additional processing unit module is integrated with a processing unit module type original processing unit module, so that the second capability is high. Providing a staged hydrocarbon fluid processing plant may be included. The method can include producing a hydrocarbon fluid (eg, LNG) from the second stage hydrocarbon fluid processing plant. This embodiment of the invention can be practiced according to one or more of various aspects described herein.

  In another aspect of the method, the additional processing unit module is placed in operation while the first stage plant is producing hydrocarbon fluid or is in operation for a limited outage period. Can do. In one aspect, the method includes placing the one or more additional processing unit modules in service while producing a hydrocarbon fluid from the first stage hydrocarbon fluid processing plant. it can. Provisions for installing the integrated additional unit may be included in the first stage hydrocarbon processing plant, and include connecting parts, block valves, isolation valves, balancing valves, blind flanges, Eyeglass flanges, headers and manifolds can be included. In one aspect, the method produces a hydrocarbon fluid from the first stage hydrocarbon fluid processing plant, while at least partially placing the one or more additional processing unit modules in service. Steps may be included. In one aspect, the method does not produce hydrocarbon fluid from the first stage hydrocarbon fluid processing plant while at least partially bringing the one or more additional processing unit modules into operation. A placing step can be included. In one aspect, the method does not produce a hydrocarbon fluid from the first stage hydrocarbon fluid processing plant for a period of less than 30 days, while the one or more additional processing unit modules are removed. , May include at least partially placing in operation. In another embodiment, the method does not produce a hydrocarbon fluid from the first stage hydrocarbon fluid processing plant for a period of less than 20, 10, 5, 2, or 1 day, while the 1 Alternatively, the process may include at least partially placing additional processing unit modules in service.

  This method is economically advantageous and can be used to increase the maximum feedstock throughput of the plant. For example, increasing the plant's maximum feedstock processing capacity while continuing to produce hydrocarbon fluids in a first stage hydrocarbon fluid treatment plant, or reducing the hydrocarbon fluid treatment plant for a limited period of time. By stopping it, the processing capacity can be increased. In this way, the first stage plant makes it possible to produce valuable products and expand their capacity, thus avoiding or reducing the amount of revenue loss. Alternatively, the additional processing unit module can be put into operation while the hydrocarbon fluid processing plant is shut down for scheduled maintenance. In addition, the method is used to build a relatively small first stage plant, with the first stage plant in operation, generating a profitable product, and then once the revenue product stream is established, the plant The maximum feedstock throughput can be expanded. This gradual expansion can be repeated as resource development plans are expanded and / or buyers are identified for the products of the hydrocarbon fluid treatment plant. In one embodiment, the LNG liquefaction plant is started at the maximum feed capacity of the first stage plant, ranging from 1-5 MTA. In another embodiment, the LNG liquefaction plant is started at the maximum feed capacity of the first stage plant ranging from 1.5 to 4.5, 2.0 to 4, or 2.5 to 3.5 MTA. In one embodiment, the LNG liquefaction plant is expanded in stages with a step expansion size that results in an increase in plant maximum feed capacity in the range of 1-5 MTA. In another embodiment, the LNG liquefaction plant is expanded in stages at a step expansion size that results in an increase in plant maximum feed throughput in the range of 1.5-4.5, 2.0-4, or 2.5-3.5 MTA. In one embodiment, the LNG liquefaction plant is expanded in a first stage and subsequent 1-6 stages. Alternatively, the LNG liquefaction plant is expanded in the first stage and subsequent 2-5 or 2-3 stages. In this way, capital plant costs and revenue generation can be more evenly balanced, thus increasing plant life cycle costs to a later point in time where market conditions can be more favorable. Can be reduced by delaying the drop of

  One aspect of the present invention includes a process for making a hydrocarbon fluid. The method includes providing a hydrocarbon fluid processing plant having plant maximum feedstock processing capacity, the plant including a plurality of processing unit module types and having at least a first refrigerant cycle. The first refrigerant cycle can include at least one first refrigerant compressor service type comprised of one or more original first refrigerant compressors in parallel. The method includes expanding the plant maximum feedstock throughput of the plant by adding at least one additional first refrigerant compressor to the first refrigerant compressor service type, wherein The additional first refrigerant compressor is integrated with one or more original first refrigerant compressors in the first refrigerant compressor service type. The method can include producing a hydrocarbon fluid (eg, LNG) in the hydrocarbon fluid processing plant (eg, LNG liquefaction plant) after the beginning of the expansion phase. This embodiment of the invention can be practiced according to one or more of the various aspects of the invention described herein. This embodiment can be used for an LNG liquefaction plant that produces LNG.

  In another aspect, the compressor may have certain features to enhance the design, construction and operability of a hydrocarbon fluid processing plant. In one aspect, the method can include at least one original first refrigerant compressor and at least one additional first refrigerant compressor of substantially equal size. In one aspect, the method can include at least one original first refrigerant compressor and at least one additional first refrigerant compressor that is mechanically formed into a substantially equal shape. In one aspect, the method can include an original first refrigerant compressor comprised of a plurality of original first refrigerant compressors and a plurality of original first refrigerant compressors having a maximum overall throughput, wherein The maximum overall throughput is less than the largest compressor available on the market for this purpose. In one aspect, each of the plurality of raw first refrigerant compressors used in the method can have a processing capacity that is less than the processing capacity of the largest compressor available on the market. As previously discussed, cost savings can be realized when building a plant using standardized processing unit modules by obtaining a number of comparable equipment types, such as compressors, at a lower purchase price. Can be realized. Furthermore, competitive bids can be used to save money by seeking compressors of a size that many manufacturers can provide. For example, if a plant designer or builder requires a processing unit module with a certain compression capability, there will be only one or a limited number of manufacturers for a large size compressor. There is a possibility that it is only. Alternatively, by using a number of smaller capacity compressors that can be supplied by a number of manufacturers, the predetermined capacity can be achieved, thus reducing the cost of the overall compression circuit. .

  In one aspect, the method can include the original and / or additional first refrigerant compressor, which is an electric motor driven compressor. In one aspect, the method can include the original and / or additional first refrigerant compressor, which is a gas turbine driven compressor. Depending on the situation, it may be desirable to use a variable speed electric motor driven compressor, which has the advantage of being able to operate over a range of capabilities. It is particularly advantageous when this plant is combined with a cogeneration unit that generates sufficient electricity for the electric compressor. Cogeneration units can be used to reduce the costs associated with using energy to drive the compressor. An exemplary cogeneration system can be used by a generator, such as a gas-combustion turbine driven generator, to generate electricity to meet the electrical demand of the electric motor driven compressor. Waste, such as heat loss, can be reduced by utilizing the heat generated as a result of power production that meets or contributes to the heating and / or cooling demands of the plant. The heat generated as a result of operating the gas-combustion turbine can be extracted from the exhaust gas by a waste heat boiler that is used to generate steam that can be used to meet the heat demand of the plant. . Alternatively, the steam generated in the waste heat boiler can be used to generate more electricity in a steam driven turbine generator. A gas turbine may be desirable if variable operating capability is important or if insufficient electricity is available.

  In one aspect, the method can include a first refrigerant circuit, which can further include one or more plate-fin heat exchangers and / or one or more spiral heat exchangers. Here, each of these heat exchangers is adapted to cool the natural gas stream through heat exchange with the refrigerant compressed by the first refrigerant compressor. In one embodiment, the method can include one or more plate-fin heat exchangers, eg, a plate-fin heat exchanger made of brazed aluminum. Alternatively, the plurality of plate-fin heat exchangers can be arranged in a cooling box. Traditionally, large spiral heat exchangers are used to obtain the surface area required in large LNG liquefaction plants. However, these large spiral heat exchangers are often more expensive than plate-fin heat exchangers. In some cases, instead of using a large spiral heat exchanger, it may be more economically advantageous to couple multiple small plate-fin heat exchangers together in a cooling box. As previously discussed, cost savings can be achieved by using a standardized processing unit module by obtaining a number of comparable equipment types, such as plate-fin heat exchangers, at a lower purchase price. This can be realized when building. In addition, competitive bidding can be used to save money by seeking smaller plate-fin heat exchangers that many manufacturers can provide.

  One aspect of the present invention includes a method for producing a hydrocarbon fluid using a hydrocarbon fluid processing plant, wherein the hydrocarbon fluid processing plant is configured by a plurality of processing unit module types, and the plurality of processing Each unit module type is composed of one or more processing unit modules. This embodiment can be used for an LNG liquefaction plant that produces LNG. The method includes providing a first stage LNG liquefaction plant, the provision providing at least one raw processing unit module for each processing unit module type included in the plurality of processing unit module types. Is possible. The first stage plant may be a stand-alone plant that, in operation, begins manufacturing profitable products. The method comprises the steps of preparing a second LNG liquefaction plant by providing at least one second processing unit module for each processing unit module type included in the plurality of processing unit module types, 2 or Integrating one or more of the original processing unit modules and one or more of the second processing unit modules for each of the above processing unit module types, and two or more of each Hydrocarbon fluids from the hydrocarbon fluid processing plant after starting integration of one or more of the original processing unit modules and one or more of the second processing unit modules for a processing unit module type of The process of manufacturing can be included. Alternatively, the method comprises 3, 4, 5, 6, 7 or more or all of the respective processing unit module types and one or more original processing unit modules and one or more A step of integrating the second processing unit module may be included. The integration of the processing unit module of the first stage plant and the module of the second stage plant, as discussed above for other aspects of the present invention, is associated with operational flexibility. May bring about. Furthermore, this embodiment of the invention may be practiced according to one or more of the various aspects of the invention described herein to obtain additional benefits.

  A scale for building a large hydrocarbon fluid processing plant, such as a large LNG liquefier line, may require a large number of large equipment items to be provided in a large number of parallel processing unit modules. As discussed herein, attendant benefits are obtained when the multiple parallel processing unit modules are integrated. As the size of the hydrocarbon fluid treatment plant increases, more equipment, such as 2 x 50%, 3 x 33%, 4 x 25%, etc. (or 3 x 50%, 4 if space is used) X33%, 5x25%, etc.) must be designed in parallel. This is because a single item is unusable, heavy, or beyond the limits of experience. In order to maximize economies of scale, it is preferable to be able to purchase each separate equipment item as large as possible.

  An LNG liquefaction plant typically consists of several separate processing sections, as previously discussed. In order to take advantage of some aspects of the plant design concept discussed here, each processing unit module type in the processing functional section is designed to be as multiplicity as possible, and the maximum of each processing unit module type is designed. Maximum benefits of scale and / or size can be obtained that are consistent with processing efficiency. One aspect of this concept can be most easily explained by using the example of a large, 20 million ton / year (MTA) LNG liquefaction plant.

  A single slag collection unit can handle all feed gases equally for this very large plant, but may require the use of two condensate stabilization units. Even if it is necessary to use two condensate stabilization units, only one exhaust gas compression unit is required due to the relatively small volume of this operation. However, because of the high flow rate through each of these devices, four or more gas preheating units may be required.

  AGR systems often include one of the heaviest items in this liquefaction plant, namely the AGR contactor vessel. Up to four of these high pressure vessels may be required for this plant. An exemplary acid gas removal contactor unit including a number of acid gas contactor vessels has already been discussed with reference to FIGS. 2A and 2B. On the other hand, up to four acid gas contactor vessels are required for this plant, but all of the solvent can be regenerated in one or two AGR solvent regeneration units. An exemplary acid gas removal regenerator unit 49 is shown in FIGS. 3A and 3B. FIG. 3A shows the rich solvent 50 entering the acid gas regenerator vessel 53. The acid gas regenerator vessel 53 is put into operation by two acid relation reboilers 55a and 55b, which are in parallel, and the reboiler is in the rich state in the acid gas regenerator vessel 53. It serves to heat the solvent and to liberate acid gases from the solvent. The hot acid gas travels above the regenerator, leaves the top of the acid gas regenerator vessel 53 and is cooled in an overhead cooler 56a before entering the settling drum 57. In the settling drum 57, the acid gas vapor is separated from any condensed liquid, the latter being refluxed to the acid gas regenerator vessel 53 via pumps 58a and 58b. The extracted acid gas 52 leaves the settling drum 57 and leaves the regenerator unit 49 for removing acid gas. The poor solvent 51 exits from the bottom of the acid gas regenerator vessel 53 via the integrated pumps 54a, b, and c in parallel relationship. FIG. 3B shows an expanded acid gas removal regenerator unit 49, which includes the addition of integrated pumps 54d and 58c, overhead cooler 56c, and acid gas regenerator reboiler 55c in parallel relationship. Has been extended. Depending on the initial design of the acid gas regenerator vessel 53, internal changes may be required, but in this embodiment, the acid gas regenerator vessel 53 itself is not replaced. 3A and 3B show one form of internal integration. The degree of integration in one processing unit module type can be varied, and the examples shown in FIGS. 3A and 3B are not meant to limit the invention. Further, the regenerator unit for removing acid gas shown in FIGS. 3A and 3B is an example of the flow mechanism and apparatus arrangement of one specific regenerator unit for removing acid gas, and this also limits the present invention. is not. Other processing unit module integration methods, flow mechanisms and apparatus arrangements for regenerator units for acid gas removal are also within the scope of the present invention.

  In this exemplary plant, several mercury adsorption vessels may be required. Molecular sieve systems generally consist of two or more parallel vessels, even in the smallest plant. In this large plant, it is not unusual to need 15 or more containers, depending on the technology specified.

  In some LNG liquefaction plants, the gas liquefaction unit does not limit the capacity of the system due to the heat exchange technology used, eg, a spiral heat exchanger. Due to the cost of manufacturing these heat exchangers, there is a strong incentive to purchase one near these maximum capacities. For example, if the maximum capacity of the exchanger was 5MTA, it would be costly inefficient to build a plant with a capacity of 6MTA using two 3MTA exchangers. One embodiment of the concept described here preferably uses instead a molecular heat exchanger type, typically made of brazed aluminum, a plate-fin heat exchanger. Such large liquefaction plants require as many as a dozen, the largest plate-fin heat exchangers that can be built. Alternatively, this size liquefaction plant uses a large number (5 or more) of spiral heat exchangers as long as each heat exchanger has the largest available size that can take advantage of economies of scale. can do.

  In the precooling heat exchanger unit, the cryogenic heat exchanger unit and the refrigerant compressor unit, a number of similarly functioning compressors are integrated into one or more similarly functioning cryogenic heat exchangers. A refrigerant compressor can be provided. A single refrigerant preparation unit can be used to prepare a single component or mixed component refrigerant. In one aspect, the requirements for the entire plant could be met by a single fractionation unit. FIG. 5 illustrates one embodiment of a cryogenic heat exchanger unit 95 that includes a number of parallel, integrated cooling boxes (89a, b, c, and d) that include a number of cryogenic heat exchangers. Is shown. The feed gas 83 is divided into four streams, cooled in the multiple cryogenic heat exchangers contained in the four cooling boxes (89a, b, c, and d), and as LNG 87, the four Exit the cooling box (89a, b, c, and d). In the cryogenic heat exchanger, the supply gas 83 is cooled by a refrigerant (for example, the low-temperature mixed refrigerant 81 and the hot-mixed refrigerant 82). The warm mixed refrigerant 82 is removed from the cryogenic heat exchanger at three different pressures 84, 85 and 86 to return to the warm mixed refrigerant compression circuit 111 (see FIGS. 6A and 6B). The low-temperature mixed refrigerant 81 is taken out of the cryogenic heat exchanger after cooling the supply gas 83, and returned to the low-temperature mixed refrigerant compression circuit 125 (see FIGS. 7A and 7B) (88). FIG. 5 is a diagram showing an example of processing unit modules integrated in parallel. The level of integration in one processing unit module type can vary and the example shown in FIG. 5 is not meant to limit the invention. Furthermore, the cryogenic heat exchanger unit shown in FIG. 5 is an example of the flow mechanism and apparatus arrangement of one particular cryogenic heat exchanger unit, and this is not intended to limit the invention. Other processing unit module integration methods, cryogenic heat exchanger unit flow mechanisms and device arrangements are also intended to be within the scope of the present invention.

  FIG. 6A shows an example of an integrated warm mixed refrigerant compression circuit 111 including a three-stage refrigerant compression process. The low pressure hot mixed refrigerant stream 86 returning to the cryogenic heat exchanger unit 95 is split and parallel first stage feed surge drum before being compressed in the first stage compressors 101a and 101b. Enter 100a and 100b. After exiting the first stage feedstock surge drums 100a and 100b, the low pressure warm mixed refrigerant stream, now at high pressure, is returned to the intermediate pressure warm mixed refrigerant stream from the cryogenic heat exchanger unit 95. With 85, it enters the second stage feedstock surge drums 102a and 102b. This combined stream is compressed in a second stage compressor 103a and 103b and then with a high pressure warm mixed refrigerant stream 84 returning from the cryogenic heat exchanger unit 95, along with third stage feed surge drums 105a and 105b. to go into. The outlets of the second and third stage compressors are connected to intermediate coolers 104a and 104b and final stage coolers 107a, 107b, 108a and before the warm mixed refrigerant enters the final separation drums 110a and 110b. Cooled by 108b. These liquid temperature mixed refrigerant streams are then merged 82 and returned to the cryogenic heat exchanger unit 95. FIG. 6B is a diagram illustrating a second exemplary warm mixed refrigerant compression circuit 111 that includes three parallel, integrated warm mixed refrigerant compression circuit modules. 6A and 6B show two examples of processing unit modules integrated in a parallel relationship. The level of integration in one processing unit module type can vary and the examples shown in FIGS. 6A and 6B are not meant to limit the invention. Furthermore, the warm mixed refrigerant compression circuit unit shown in FIGS. 6A and 6B is an example of the flow mechanism and device arrangement of one specific warm mixed refrigerant compression circuit unit, and this also does not limit the present invention. Other processing unit module integration methods, flow mechanisms and apparatus arrangements of warm mixed refrigerant compression circuit units are also within the scope of the present invention.

  FIG. 7A shows an example of an integrated low-temperature mixed refrigerant compression circuit 125 including a two-stage refrigerant compression step. Returning to the cryogenic heat exchanger unit 95, this cold mixed refrigerant stream 88 is split and enters the parallel first stage feed surge drum before being compressed in the first stage compressors 120a and 120b. . After exiting the first stage compressors 120a and 120b, each of the cold mixed refrigerant streams enters a second stage feed surge drum. This refrigerant stream is then compressed in second stage compressors 122a and 122b. The outlets of the first and second stage compressors are cooled by first stage coolers 121a and 121b and final stage coolers 123a and 123b. These liquid cold mixed refrigerant streams are then merged 81 and returned to the cryogenic heat exchanger unit 95. FIG. 7B is a diagram illustrating a second exemplary low temperature mixed refrigerant compression circuit 125 that includes three parallel, integrated low temperature mixed refrigerant compression circuit modules. 7A and 7B show two examples of processing unit modules integrated in a parallel relationship. The level of integration in one processing unit module type can vary and the examples shown in FIGS. 7A and 7B are not meant to limit the invention. Furthermore, the low-temperature mixed refrigerant compression circuit unit shown in FIGS. 7A and 7B is an example of the flow mechanism and device arrangement of one specific low-temperature mixed refrigerant compression circuit unit, and this also does not limit the present invention. Other processing unit module integration methods, low temperature mixed refrigerant compression circuit unit flow mechanisms and device arrangements are also within the scope of the present invention.

  Another member or independent unit of the gas liquefaction compartment is a distillation column, such as a scrub tower, a demethanization column, or a deethanization column, which removes at least pentane and heavier components from the feed gas. It has a function of removing and preventing freezing in the cryogenic heat exchanger. For a plant with a capacity of 20 MTA, it is necessary to select and use one of 2-3 columns (columns) in parallel. FIG. 4 illustrates one embodiment of a deethanization unit 60 that includes a number of devices integrated in a parallel relationship. The treated gas 61 enters the deethanization unit 60 as a common feed stream, enters one common knockout drum 65b, and three parallel, integrated expander-compressor sets 66a, 66b. And divided into two streams that enter two parallel heat exchangers 64a and 64b before being sent to 66c. The expanded gas then flows into the two columns 71a and 71b where a predetermined amount of NGL is recovered. This cold gas exiting from the top of these columns is routed through a set of heat exchangers 72a, 72b, 64a and 64b where cooling energy is recovered. The gas is then compressed in expander-compressor sets 66a, 66b and 66c and 68a and 68b to a predetermined liquefaction pressure. The gas is cooled in ambient-medium heat exchangers 70a and 70b before entering the cryogenic heat exchanger. The liquid from the bottom of the columns 71a and 71b is warmed in heat exchangers 72a and 72b before entering the deethanization column 73. The deethanizing column removes light hydrocarbon residues remaining from the liquid. The overhead gas stream from this column is partially condensed in heat exchangers 72a and 72b and phase separated in reflux drum 74. The steam from the drum is combined with the steam from the columns 71a and 71b before the cooling recovery and compression process. This drum-derived liquid is pumped in pumps 75a, 75b and 75c to provide low temperature reflux for both sets of distillation columns 71a and 71b and 73. FIG. 4 shows one form of internal integration. The level of integration in one processing unit module type can vary, and the example shown in FIG. 4 is not meant to limit the invention. Furthermore, the deethanation unit shown in FIG. 4 is an example of the flow mechanism and apparatus arrangement of one particular deethanation unit, and this is not intended to limit the invention. Other process unit module integration methods, deethanization unit flow mechanisms and device arrangements are also within the scope of the present invention.

  At the end of this liquefaction process, the LNG is processed to remove nitrogen in a nitrogen rejection unit (NRU) and possibly to recover helium if some is present. LNG liquefaction plants will also typically require a sulfur recovery unit (SRU). These units could be designed by the methodology described here. The method for performing these purifications is provided by licensors who are instructed and can receive instructions to design these systems according to this principle. FIG. 8 shows an example of a combined nitrogen exclusion unit and helium recovery unit 130. The LNG feed 131 is in a parallel relationship and its pressure is reduced and fed to a common feed flash drum 136 via integrated expanders 135a, 135b and 135c. This vapor stream from flash drum 136 is in parallel relationship and cooled in integrated heat exchangers 137a and 137b before entering helium product flash drum 138. The vapor stream from the helium product flash drum 138 is a helium rich stream, which results in a raw helium product stream 133. The liquid stream from drum 138 is vaporized in heat exchangers 137a and 137b to provide the required cooling. The liquid stream from the common feed flash drum 136 is in parallel and passed through the integrated heat exchangers 139a and 139b before being sent to the fuel gas flash drum 140. The liquid stream from the fuel gas flash distillation column 140 becomes the LNG product 132, while the vapor stream is combined with the vaporized stream from the heat exchangers 137a and 137b before entering the fuel gas system 134. It is then in parallel and compressed in the integrated fuel gas compressors 141a and 141b. FIG. 8 shows one form of internal integration. The level of integration in one processing unit module type can vary and the example shown in FIG. 8 is not meant to limit the invention. Further, the HRU unit shown in FIG. 8 is an example of the flow mechanism and device arrangement of one specific HRU unit, and this is not intended to limit the present invention. Other processing unit module integration methods, HRU unit flow mechanisms and device arrangements are also within the scope of the present invention.

  In order to maximize the advantages of one aspect of the present invention, the plant capacity advancement is always planned, and as a result, many expensive equipment types and / or processing unit modules are always fully utilized. For example, if one or more refrigerant compressor unit modules are the most expensive, the initial LNG liquefaction plant will probably have an appropriate number of other types of refrigerant compressor unit modules and other processing unit module types. It is designed to have a functional processing unit module, and as a result, it can handle the throughput of a given plant. When expanding a plant, one more refrigerant compressor unit module is required, thus adding the appropriate number of other processing unit modules of the other functional processing unit module type, the most expensive The available capacity of the bulky processing unit module could be fully utilized.

  Utilizing the methodology described here, the overall unit cost of a plant designed, constructed and / or operated can be reduced compared to a plant designed according to the concept of a traditional instrument array. Was made. This is because each of the device types and / or processing unit modules are constructed on a very large scale and / or for their respective maximum processing efficiencies. Although several types of devices are manufactured, it is only necessary to design one type of device, so that the engineering cost can be reduced. Costs can also be reduced by the common use of control systems and large utility systems.

  One powerful advantage of this design plant is its modularity. Since almost any equipment item is given in multiples, some parts of the plant are complete and can be put into operation even if other parts of the plant are still under construction. . This concept can have enormous advantages in terms of project economics. This is because more revenue is generated early in the life of the project. Also, various parts of the plant can be shut down for maintenance without shutting down the entire plant, which results in high utilization of the plant.

  The methods described herein can be used to design one or more processing unit modular or complete hydrocarbon fluid processing plants. This method can also be used to expand the capacity of existing processing unit modular or hydrocarbon fluid processing plants. A unit or plant designed in this way can be constructed and operated more efficiently using the methods described herein. Such a unit or plant can also be used to produce a sellable product (e.g. LNG) that can be transported to the market through pipelines and / or using shipping containers. . A transport container may include one or more diesel vehicles, tanker trucks, barges, ships or other means of traveling on the ground or sea.

  Several features of the invention have been described by a group of numerical upper limits and a group of numerical lower limits. It should be understood that ranges formed by any combination of these limits are within the scope of the invention, unless otherwise stated. Some dependent claims exhibit single dependency in accordance with US practice, but each feature in any such dependent claim is dependent on one or more independent claims. Can be combined with the features of the other dependent claims.

  The invention has been described with reference to its preferred embodiments. However, since the above description is specific to a particular embodiment or particular application of the present invention, the description is intended to be exemplary only and is understood to limit the scope of the present invention. Should not. On the contrary, the intention is to cover all alternatives, modifications, and equivalents included within the spirit and scope of the invention as defined by the appended claims.

It is a block flow figure showing an example child composition of an LNG liquefaction plant. FIG. 3 is a simplified process flow diagram illustrating an exemplary acid gas removal contactor unit. FIG. 3 is a simplified process flow diagram illustrating a second exemplary acid gas removal contactor unit. FIG. 2 is a simplified process flow diagram illustrating an exemplary acid gas removal regenerator unit. FIG. 6 is a simplified process flow diagram illustrating a second exemplary acid gas removal regenerator unit. FIG. 2 is a simplified process flow diagram illustrating an exemplary deethanizer unit. FIG. 3 is a simplified process flow diagram illustrating an exemplary cryogenic heat exchanger unit. FIG. 2 is a simplified process flow diagram illustrating an exemplary refrigerant compressor unit. FIG. 4 is a simplified process flow diagram illustrating a second exemplary refrigerant compressor unit. FIG. 4 is a simplified process flow diagram illustrating a second exemplary refrigerant compressor unit. FIG. 4 is a simplified process flow diagram illustrating a second exemplary refrigerant compressor unit. FIG. 3 is a simplified process flow diagram illustrating an exemplary helium recovery unit.

Explanation of symbols

  49 ·· Regenerator unit for removing acid gas; 50 · · Rich solvent; 51 · · Poor solvent; 52 · · Acid gas; 53 · · Acid gas regenerator vessel; 54a, b, c, 58d · · Integrated pump 55a, b, c ... acid gas regenerator reboiler; 56a, c ... overhead cooler; 57 ... sedimentation drum; 60 ... deethanizer unit; 64a, b, 72a, b ... heat exchange 65b ·· Knockout drum; 66a, b, c, 68a, b · · Integrated expander-compressor set; 71a, b · · column; 73 · · Deethanizer column; 75a, b, c · · · Pump; 81 · · Low temperature mixed refrigerant; 82 · · Warm mixed refrigerant; 83 · · Supply gas; 85 · · Medium pressure mixed refrigerant flow; 86 · · Low pressure mixed refrigerant flow; · LNG; 88 ·· Low temperature mixed refrigerant flow; 89a, b, c, d · · Cooling box; 95 · · Cryogenic heat exchangers; 100a, b · · First stage feed material surge drums; first Stage compressor; 102a, b ... second stage feed material surge drum; 103a, b ... second stage compressor; 104a, b ... intermediate cooler; 105a, b ... third stage feed surge drum; 107a, b, 108a, b ... Final stage cooler; 110a, b ... Warm mixed refrigerant final separation drum; 111 ... Warm mixed refrigerant compression circuit; 120a, b ... Final stage compressor; 121a, b ... 122a, b ... second stage compressor; 123a, b ... final stage cooler; 125 ... low temperature mixed refrigerant compression circuit; 130 ... helium recovery unit; 131 ... LNG feed; ·· Helium product stream; 134 · · Fuel gas system; 135a, b, c · · Integrated expander; 136 · · Feed material flash drum; 137a, b, 139a, b · · Integrated heat exchanger;・ Helium product flash drum; 140 ・ ・ Fuel gas flash drum; 141a, b ・ ・ Integrated fuel gas compressor

Claims (384)

  A method for producing liquefied natural gas using an LNG liquefaction plant, the LNG liquefaction plant comprising a plurality of processing unit module types, wherein the plurality of processing unit module types is at least one or more first. A first processing unit module type including a processing unit module; and a second processing unit module type including two or more integrated second processing unit modules; and at least one first processing unit The module and at least one of the second processing unit modules are each sized to obtain substantially maximum processing efficiency, and the LNG liquefaction plant comprises two or more integrated processes A unit module type, wherein the method includes producing liquefied natural gas from the LNG liquefaction plant. Wherein the manufacturing method of the liquefied natural gas.   The method of claim 1, wherein the substantially maximum processing efficiency is within 25% of an actual maximum processing efficiency.   3. The method of claim 2, wherein the substantially maximum processing efficiency is within 15% of the actual maximum processing efficiency.   4. The method of claim 3, wherein the substantially maximum processing efficiency is within 10% of the actual maximum processing efficiency.   5. The maximum processing efficiency is the capacity size of the processing unit module for each processing unit module type that minimizes the life cycle cost of all processing unit modules per unit of processing unit module capacity. the method of.   5. The method of claim 4, wherein the LNG liquefaction plant further comprises a third processing unit module type comprised of one or more third processing unit modules.   5. The method of claim 4, wherein the maximum feed capacity of the second processing unit module type is at least equal to the maximum feed capacity of the first processing unit module type.   The first and second processing unit module types have first and second construction costs per unit of maximum feedstock throughput, and the first construction cost per unit of the maximum feedstock throughput is The method of claim 7, wherein the second construction cost is exceeded per unit of the maximum feed throughput.   7. The method of claim 6, wherein the LNG liquefaction plant includes at least one of the processing unit module types in parallel and having a plurality of substantially equal sized processing unit modules.   10. The method of claim 9, wherein the LNG liquefaction plant comprises at least one processing unit module type having processing unit modules in parallel and formed in a plurality of substantially equal shapes.   7. The method of claim 6, wherein the third processing unit module type comprises a third processing unit module sized to substantially maximize processing efficiency.   The first processing unit module is configured with a first type of device, the second processing unit module is configured with a second processing unit type, and the third processing unit module is configured with a third type. 7. The method according to claim 6, comprising a processing device type of:   13. The method of claim 12, wherein at least some of the device types are formed with substantially equal shapes.   14. The method of claim 13, wherein at least some of the device types are formed with substantially equal sizes.   7. The method of claim 6, wherein the maximum feed capacity of the first processing unit module type differs from the capacity of the second processing unit module type by more than 10%.   16. The method of claim 15, wherein the second processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   16. The method of claim 15, wherein the first processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   17. The method of claim 16, wherein the second processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the first processing unit module type.   The method of claim 17, wherein the first processing unit module type has a maximum feed capacity of less than 80% of the maximum feed capacity of the second processing unit module type.   16. The method of claim 15, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   16. The method of claim 15, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   7. The method of claim 6, wherein the LNG liquefaction plant comprises a liquefaction unit, the liquefaction unit being composed of one or more cryogenic heat exchangers and a plurality of similar role refrigerant compressors.   24. The method of claim 22, wherein at least two of the plurality of compressors are arranged in parallel.   24. The method of claim 23, wherein the liquefaction unit comprises a plurality of cryogenic heat exchangers having a similar role, the cryogenic heat exchangers being arranged in parallel.   25. The method of claim 24, wherein each of the plurality of compressors is in fluid communication with two or more cryogenic heat exchangers.   26. The method of claim 25, wherein the liquefaction unit is configured in a shape such that each of the plurality of compressors can be placed in fluid connection with any of the cryogenic heat exchangers.   27. The method of claim 26, wherein the plurality of cryogenic heat exchangers includes one or more modular heat exchangers.   28. The method of claim 27, wherein the plurality of cryogenic heat exchangers include one or more plate-fin heat exchangers.   28. The method of claim 27, wherein the plurality of cryogenic heat exchangers include one or more spiral heat exchangers.   The LNG liquefaction plant has a plant maximum feedstock throughput and a plant minimum feedstock throughput, wherein the plant minimum feedstock throughput is 75% or less of the plant maximum feedstock throughput. the method of.   32. The method of claim 30, wherein the plant minimum feed capacity is 65% or less of the plant maximum feed capacity.   32. The method of claim 31, wherein the plant minimum feed capacity is 55% or less of the plant maximum feed capacity.   7. The method of claim 6, wherein at least one of the processing unit module types comprises a variable speed compressor, a variable speed expander, or a combination thereof.   The method of claim 6, wherein the plant maximum feedstock throughput exceeds 4 million tonnes per year.   35. The method of claim 34, wherein the plant maximum feedstock throughput exceeds 6 million tonnes per year.   The method of claim 1, wherein the LNG liquefaction plant comprises three or more integrated processing unit module types.   38. The method of claim 36, wherein the LNG liquefaction plant comprises four or more integrated processing unit module types. LNG liquefaction plant design method,
A) Identifying a plurality of processing unit module types included in the LNG liquefaction plant, wherein the plurality of processing unit module types are at least a first processing unit module type and a second processing unit module type Including:
B) determining a first maximum processing efficiency for the first processing unit module of the first processing unit module type and a second maximum processing efficiency for the second processing unit module of the second processing unit module type; and
C) one or more first processing unit modules comprising a step of designing the LNG liquefaction plant, the LNG liquefaction plant design having a size that substantially satisfies the first maximum processing efficiency; And one or more second processing unit modules having a size that substantially satisfies the second maximum processing efficiency.   40. The method of claim 38, wherein the substantial satisfaction of the maximum processing efficiency is within 25% of the actual maximum processing efficiency.   40. The method of claim 39, wherein the substantial satisfaction of the maximum processing efficiency is within 15% of the actual maximum processing efficiency.   41. The method of claim 40, wherein the substantial satisfaction of the maximum processing efficiency is within 10% of the actual maximum processing efficiency.   42. The maximum processing efficiency is the processing unit module capacity size for each processing unit module type that minimizes the life cycle cost of all processing unit modules per unit of processing unit module capacity. Method.   42. The method of claim 41, wherein the LNG liquefaction plant design further comprises a third processing unit module type comprised of one or more third processing unit modules.   42. The method of claim 41, wherein a maximum feed capacity of the second processing unit module type is at least equal to a maximum feed capacity of the first processing unit module type.   The first and second processing unit module types have first and second construction costs per unit of maximum feedstock throughput, and the first construction cost per unit of maximum feedstock throughput is 45. The method of claim 44, wherein the second construction cost is exceeded per unit of the maximum feedstock throughput.   44. The method of claim 43, wherein the LNG liquefaction plant design includes at least one processing unit module type having a plurality of substantially equal sized processing unit modules in parallel.   47. The method of claim 46, wherein the LNG liquefaction plant design includes at least one processing unit module type having processing unit modules in parallel and formed in a plurality of substantially equal shapes.   44. The method of claim 43, wherein the third processing unit module type comprises a third processing unit module sized to substantially maximize processing efficiency.   The first processing unit module is configured with a first apparatus type, the second processing unit module is configured with a second processing apparatus type, and the third processing unit module is configured with a third apparatus type. 44. The method of claim 43, wherein the method comprises a processor type.   50. The method of claim 49, wherein at least some of the device types are formed with substantially equal shapes.   51. The method of claim 50, wherein at least some of the device types are formed with substantially equal sizes.   44. The method of claim 43, wherein the maximum feed capacity of the first processing unit module type differs from the capacity of the second processing unit module type by more than 10%.   53. The method of claim 52, wherein the second processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   53. The method of claim 52, wherein the first processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   54. The method of claim 53, wherein the second processing unit module type has a maximum feed capacity of less than 80% of the maximum feed capacity of the first processing unit module type.   55. The method of claim 54, wherein the first processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the second processing unit module type.   53. The method of claim 52, wherein at least two of the processing unit module types have a maximum feed capacity of less than 85% of the maximum feed capacity of the first processing unit module type.   53. The method of claim 52, wherein at least two of the processing unit module types have a maximum feed capacity of less than 85% of the maximum feed capacity of the second processing unit module type.   44. The method of claim 43, wherein the LNG liquefaction plant design includes a liquefaction unit, wherein the liquefaction unit is comprised of one or more cryogenic heat exchangers and a plurality of similar role refrigerant compressors. .   60. The method of claim 59, wherein at least two of the plurality of compressors are arranged in parallel.   61. The method of claim 60, wherein the liquefaction unit comprises a plurality of cryogenic heat exchangers having a similar role, wherein the cryogenic heat exchangers are arranged in parallel.   64. The method of claim 61, wherein each of the plurality of compressors is in fluid communication with two or more cryogenic heat exchangers.   64. The method of claim 62, wherein the liquefaction unit is formed in a shape such that each of the plurality of compressors can be placed in fluid connection with any of the cryogenic heat exchangers.   64. The method of claim 63, wherein the plurality of cryogenic heat exchangers includes one or more modular heat exchangers.   65. The method of claim 64, wherein the plurality of cryogenic heat exchangers include one or more plate-fin heat exchangers.   65. The method of claim 64, wherein the plurality of cryogenic heat exchangers includes one or more spiral heat exchangers.   44. The LNG liquefaction plant design has a plant maximum feedstock throughput and a plant minimum feedstock throughput, wherein the plant minimum feedstock throughput is no more than 75% of the plant maximum feedstock throughput. The method described.   68. The method of claim 67, wherein the plant minimum feed capacity is 65% or less of the plant maximum feed capacity.   69. The method of claim 68, wherein the plant minimum feed capacity is 55% or less of the plant maximum feed capacity.   44. The method of claim 43, wherein at least one of the processing unit module types comprises a variable speed compressor, a variable speed expander, or a combination thereof.   44. The method of claim 43, wherein the plant maximum feedstock throughput exceeds 4 million tonnes per year.   72. The method of claim 71, wherein the plant maximum feedstock throughput exceeds 6 million tonnes per year.   44. The method of claim 43, wherein the LNG liquefaction plant design comprises two or more integrated processing unit module types.   74. The method of claim 73, wherein the LNG liquefaction plant design comprises three or more integrated processing unit module types.   75. The method of claim 74, wherein the LNG liquefaction plant design comprises four or more integrated processing unit module types. A method for designing an expanded LNG liquefaction plant capacity that has the maximum feed capacity of existing plants,
A) preparing an existing configuration of the LNG liquefaction plant, wherein the LNG liquefaction plant includes a plurality of processing unit module types;
B) determining the first processing unit module type that requires ancillary maximum feed throughput and increasing the existing plant maximum feed throughput;
C) determining the maximum processing efficiency of the first processing unit module of the first processing unit module type; and
D) designing an expanded LNG liquefaction plant, the design comprising adding one or more first processing unit modules having a size that substantially satisfies the maximum processing efficiency. A method as described above, characterized.   77. The method of claim 76, wherein the substantial satisfaction of the maximum processing efficiency is within 25% of the actual maximum processing efficiency.   78. The method of claim 77, wherein the substantial satisfaction of the maximum processing efficiency is within 15% of the actual maximum processing efficiency.   79. The method of claim 78, wherein the substantial satisfaction of the maximum processing efficiency is within 10% of the actual maximum processing efficiency.   80. The maximum processing efficiency is the processing unit module capacity size for each processing unit module type that minimizes the life cycle cost of all processing unit modules per unit of processing unit module capacity. Method.   The LNG liquefaction plant design further comprises a second processing unit module type comprising one or more second processing unit modules and a third processing unit module comprising one or more third processing unit modules. 81. The method of claim 80, also comprising a processing unit module type.   84. The method of claim 81, wherein the maximum feed capacity of the second processing unit module type is at least equal to the maximum feed capacity of the first processing unit module type.   The first and second processing unit module types have first and second construction costs per unit of maximum feedstock throughput, and the first construction cost per unit of maximum feedstock throughput is 84. The method of claim 82, wherein the second build cost per unit of the maximum feedstock throughput is exceeded.   82. The method of claim 81, wherein the LNG liquefaction plant design includes at least one processing unit module type having a plurality of substantially equal sized processing unit modules in parallel.   85. The method of claim 84, wherein the LNG liquefaction plant design includes at least one processing unit module type having processing unit modules that are in parallel and formed in a plurality of substantially equal shapes.   82. The method of claim 81, wherein the third processing unit module type comprises a third processing unit module sized to substantially maximize processing efficiency.   The first processing unit module is configured with a first apparatus type, the second processing unit module is configured with a second processing apparatus type, and the third processing unit module is configured with a third apparatus type. 82. The method of claim 81, wherein the method comprises a processor type.   90. The method of claim 87, wherein at least some of the device types are formed with substantially equal shapes.   90. The method of claim 88, wherein at least some of each of the device types are formed with substantially equal sizes.   82. The method of claim 81, wherein the maximum feed capacity of the first processing unit module type differs from the capacity of the second processing unit module type by more than 10%.   93. The method of claim 90, wherein the second processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   94. The method of claim 90, wherein the first processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   92. The method of claim 91, wherein the second processing unit module type has a maximum feed capacity of less than 80% of the maximum feed capacity of the first processing unit module type.   94. The method of claim 92, wherein the first processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the second processing unit module type.   93. The method of claim 90, wherein at least two of the processing unit module types have a maximum feed capacity of less than 85% of the maximum feed capacity of the first processing unit module type.   92. The method of claim 90, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   82. The method of claim 81, wherein the LNG liquefaction plant design includes a liquefaction unit, the liquefaction unit being composed of one or more cryogenic heat exchangers and a plurality of similar role refrigerant compressors. .   98. The method of claim 97, wherein at least two of the plurality of compressors are arranged in parallel.   99. The method of claim 98, wherein the liquefaction unit comprises a plurality of cryogenic heat exchangers having a similar role, wherein the cryogenic heat exchangers are arranged in parallel.   100. The method of claim 99, wherein each of the plurality of compressors is in fluid communication with two or more cryogenic heat exchangers.   101. The method of claim 100, wherein the liquefaction unit is formed in a shape such that each of the plurality of compressors can be placed in fluid connection with any of the cryogenic heat exchangers.   102. The method of claim 101, wherein the plurality of cryogenic heat exchangers includes one or more modular heat exchangers.   105. The method of claim 102, wherein the plurality of cryogenic heat exchangers include one or more plate-fin heat exchangers.   105. The method of claim 102, wherein the plurality of cryogenic heat exchangers includes one or more spiral heat exchangers.   The LNG liquefaction plant design has a plant maximum feedstock throughput and a plant minimum feedstock throughput, wherein the plant minimum feedstock throughput is 75% or less of the plant maximum feedstock throughput. The method described.   106. The method of claim 105, wherein the plant minimum feed capacity is 65% or less of the plant maximum feed capacity.   107. The method of claim 106, wherein the plant minimum feed capacity is 55% or less of the plant maximum feed capacity.   86. The method of claim 85, wherein at least one of the processing unit module types comprises a variable speed compressor, a variable speed expander, or a combination thereof.   92. The method of claim 81, wherein the plant maximum feedstock throughput exceeds 4 million tonnes per year.   110. The method of claim 109, wherein the plant maximum feedstock throughput exceeds 6 million tons per year.   82. The method of claim 81, wherein the LNG liquefaction plant design comprises two or more integrated processing unit module types.   112. The method of claim 111, wherein the LNG liquefaction plant design comprises three or more integrated processing unit module types.   113. The method of claim 112, wherein the LNG liquefaction plant design comprises four or more integrated processing unit module types. A plurality of processing unit module types, wherein the plurality of processing unit module types are composed of one or more first processing unit modules and a first processing unit module type and two or more integrated At least a second processing unit module type comprising a second processing unit module, wherein at least one first processing unit module and at least one second processing unit module are each substantially Is a method of operating an LNG liquefaction plant, which is formed in a size that takes the maximum processing capacity,
A) measuring the first plant feed rate,
B) determining the number of processing unit modules of each processing unit module type required to satisfy the first plant feedstock processing rate;
C) putting each processing unit module of each processing unit module type into operation, as required to meet at least the number of steps B) determined in the first plant feedstock processing rate; and
D) A process as described above, comprising the step of producing LNG.   115. The method of claim 114, wherein the substantially maximum processing efficiency is within 25% of an actual maximum processing efficiency.   116. The method of claim 115, wherein the substantially maximum processing efficiency is within 15% of the actual maximum processing efficiency.   117. The method of claim 116, wherein the substantial maximum processing efficiency is within 10% of the actual maximum processing efficiency.   118. The maximum processing efficiency is the capacity size of the processing unit module for each processing unit module type that minimizes the life cycle cost of all processing unit modules per unit of processing unit module capacity. Method.   118. The method of claim 117, wherein the LNG liquefaction plant further comprises a third processing unit module type comprised of one or more third processing unit modules.   118. The method of claim 117, wherein the maximum feed capacity of the second processing unit module type is at least equal to the maximum feed capacity of the first processing unit module type.   The first and second processing unit module types have first and second construction costs per unit of maximum feedstock throughput, and the first construction cost per unit of maximum feedstock throughput is 121. The method of claim 120, wherein the second construction cost per unit of the maximum feedstock throughput is exceeded.   118. The method of claim 117, wherein the LNG liquefaction plant comprises at least one processing unit module type in parallel and having a plurality of substantially equal sized processing unit modules.   123. The method of claim 122, wherein the LNG liquefaction plant comprises at least one processing unit module type having processing unit modules in parallel and formed in a plurality of substantially equal shapes.   119. The method of claim 119, wherein the third processing unit module type comprises a third processing unit module sized to substantially maximize processing efficiency.   The first processing unit module is configured with a first apparatus type, the second processing unit module is configured with a second processing apparatus type, and the third processing unit module is configured with a third apparatus type. 120. The method of claim 119, wherein the method comprises a processor type.   126. The method of claim 125, wherein at least some of the device types are formed with substantially equal shapes.   127. The method of claim 126, wherein at least some of the device types are formed with substantially equal sizes.   120. The method of claim 119, wherein the maximum feed capacity of the first processing unit module type differs from the capacity of the second processing unit module type by more than 10%.   129. The method of claim 128, wherein the second processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   129. The method of claim 128, wherein the first processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   129. The method of claim 129, wherein the second processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the first processing unit module type.   131. The method of claim 130, wherein the first processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the second processing unit module type.   129. The method of claim 128, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   129. The method of claim 128, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   120. The method of claim 119, wherein the LNG liquefaction plant comprises a liquefaction unit, wherein the liquefaction unit is comprised of one or more cryogenic heat exchangers and a plurality of similar role refrigerant compressors.   135. The method of claim 135, wherein at least two of the plurality of compressors are arranged in parallel.   138. The method of claim 136, wherein the liquefaction unit comprises a plurality of cryogenic heat exchangers having a similar role, wherein the cryogenic heat exchangers are arranged in parallel.   138. The method of claim 137, wherein each of the plurality of compressors is in fluid communication with two or more cryogenic heat exchangers.   138. The method of claim 138, wherein the liquefaction unit is formed in a shape such that each of the plurality of compressors can be placed in fluid connection with any of the cryogenic heat exchangers.   140. The method of claim 139, wherein the plurality of cryogenic heat exchangers include one or more modular heat exchangers.   143. The method of claim 140, wherein the plurality of cryogenic heat exchangers include one or more plate-fin heat exchangers.   143. The method of claim 140, wherein the plurality of cryogenic heat exchangers includes one or more spiral heat exchangers.   120. The LNG liquefaction plant has a plant maximum feedstock throughput and a plant minimum feedstock throughput, wherein the plant minimum feedstock throughput is 75% or less of the plant maximum feedstock throughput. the method of.   145. The method of claim 143, wherein the plant minimum feed capacity is 65% or less of the plant maximum feed capacity.   145. The method of claim 144, wherein the plant minimum feed capacity is 55% or less of the plant maximum feed capacity.   120. The method of claim 119, wherein at least one of the processing unit module types comprises a variable speed compressor, a variable speed expander, or a combination thereof.   120. The method of claim 119, wherein the plant maximum feedstock throughput exceeds 4 million tonnes per year.   148. The method of claim 147, wherein the plant maximum feedstock throughput exceeds 6 million tonnes per year.   120. The method of claim 119, wherein the LNG liquefaction plant comprises two or more integrated processing unit module types.   150. The method of claim 149, wherein the LNG liquefaction plant comprises three or more integrated processing unit module types.   161. The method of claim 150, wherein the LNG liquefaction plant comprises four or more integrated processing unit module types. And E) determining a second plant feedstock processing rate;
F) determining the number of processing unit modules of each processing unit module type required to meet the second plant feedstock processing rate; and
G) placing each processing unit module of each processing unit module type, which is required to satisfy at least the number of the second plant feed material processing rates determined in step (F), into operation; 120. The method of claim 119, further comprising: A method for producing LNG using an LNG liquefaction plant, wherein the LNG liquefaction plant is constituted by a plurality of processing unit module types, and each of the plurality of processing unit module types is constituted by one or more processing unit modules. The method comprising:
A) providing at least one original processing unit module for each processing unit module type included in the plurality of processing unit module types, wherein one or more original processing unit modules are each substantive Is formed to a size that maximizes the processing efficiency, resulting in a first-stage LNG liquefaction plant,
B) providing one or more additional processing unit modules for one or more processing unit module types included in the first stage LNG liquefaction plant, wherein the additional processing unit modules are Integrated with the raw processing unit module within the processing unit module mold, resulting in a second stage LNG liquefaction plant, and
C) producing the LNG from the second stage LNG liquefaction plant.   154. The method of claim 153, wherein the substantial maximum processing efficiency is within 25% of the actual maximum processing efficiency.   157. The method of claim 154, wherein the substantially maximum processing efficiency is within 15% of the actual maximum processing efficiency.   165. The method of claim 155, wherein the substantially maximum processing efficiency is within 10% of the actual maximum processing efficiency.   157. The maximum processing efficiency is the processing unit module capacity size for each processing unit module type that minimizes the life cycle cost of all processing unit modules per unit of processing unit module capacity. Method.   157. The method of claim 156, wherein the LNG liquefaction plant further comprises a third processing unit module type comprised of one or more third processing unit modules.   157. The method of claim 156, wherein a maximum feed capacity of the second processing unit module type is at least equal to a maximum feed capacity of the first processing unit module type.   The first and second processing unit module types have first and second construction costs per unit of maximum feedstock throughput, and the first construction cost per unit of maximum feedstock throughput is 160. The method of claim 159, wherein the second build cost per unit of the maximum feedstock throughput is exceeded.   157. The method of claim 156, wherein the LNG liquefaction plant comprises at least one processing unit module type having a plurality of substantially equal sized processing unit modules in parallel.   164. The method of claim 161, wherein the LNG liquefaction plant comprises at least one processing unit module type having processing unit modules in parallel and formed in a plurality of substantially equal shapes.   159. The method of claim 158, wherein the third processing unit module type comprises a third processing unit module sized to substantially maximize processing efficiency.   The first processing unit module is configured with a first apparatus type, the second processing unit module is configured with a second processing apparatus type, and the third processing unit module is configured with a third apparatus type. 159. The method of claim 158, comprising a processor type.   165. The method of claim 164, wherein at least some of the device types are formed with substantially equal shapes.   166. The method of claim 165, wherein at least some of the device types are formed with substantially equal sizes.   159. The method of claim 158, wherein the maximum feed capacity of the first processing unit module type differs from the capacity of the second processing unit module type by more than 10%.   168. The method of claim 167, wherein the second processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   168. The method of claim 167, wherein the first processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   171. The method of claim 168, wherein the second processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the first processing unit module type.   170. The method of claim 169, wherein the first processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the second processing unit module type.   168. The method of claim 167, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   168. The method of claim 167, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   159. The method of claim 158, wherein the LNG liquefaction plant comprises a liquefaction unit, wherein the liquefaction unit is comprised of one or more cryogenic heat exchangers and a plurality of similar function refrigerant compressors.   175. The method of claim 174, wherein at least two of the plurality of compressors are arranged in parallel.   175. The method of claim 175, wherein the liquefaction unit comprises a plurality of cryogenic heat exchangers having a similar role, wherein the cryogenic heat exchangers are arranged in parallel.   177. The method of claim 176, wherein each of the plurality of compressors is in fluid communication with two or more cryogenic heat exchangers.   179. The method of claim 177, wherein the liquefaction unit is configured in a shape such that each of the plurality of compressors can be placed in fluid connection with any of the cryogenic heat exchangers.   181. The method of claim 178, wherein the plurality of cryogenic heat exchangers include one or more modular heat exchangers.   180. The method of claim 179, wherein the plurality of cryogenic heat exchangers include one or more plate-fin heat exchangers.   180. The method of claim 179, wherein the plurality of cryogenic heat exchangers includes one or more spiral heat exchangers.   158. The LNG liquefaction plant has a plant maximum feedstock throughput and a plant minimum feedstock throughput, wherein the plant minimum feedstock throughput is 75% or less of the plant maximum feedstock throughput. the method of.   183. The method of claim 182, wherein the plant minimum feed capacity is 65% or less of the plant maximum feed capacity.   183. The method of claim 183, wherein the plant minimum feedstock throughput is 55% or less of the plant maximum feedstock throughput.   159. The method of claim 158, wherein at least one of the processing unit module types comprises a variable speed compressor, a variable speed expander, or a combination thereof.   159. The method of claim 158, wherein the plant maximum feedstock throughput exceeds 4 million tonnes per year.   187. The method of claim 186, wherein the plant maximum feedstock throughput exceeds 6 million tonnes per year.   159. The method of claim 158, wherein the LNG liquefaction plant comprises two or more integrated processing unit module types.   191. The method of claim 188, wherein the LNG liquefaction plant comprises three or more integrated processing unit module types.   189. The method of claim 189, wherein the LNG liquefaction plant comprises four or more integrated processing unit module types. A method for producing liquefied natural gas, comprising:
A) preparing an LNG liquefaction plant having a plurality of product sizes and including a processing unit module type, wherein the LNG liquefaction plant has a first plant maximum feed capacity;
B) At least one of the processing unit module types having the product size, but less than all of them, expands the maximum feedstock processing capacity to 10% of the first plant maximum feedstock processing capacity. Achieving a second plant maximum feedstock throughput that is greater than or equal to%; and
C) producing the LNG in the LNG liquefaction plant after starting the expansion step (B).   The processing unit module type having the product size is an acid gas removal contactor unit, a dehydration unit, a deethanization unit, a cryogenic heat exchanger unit, a refrigerant compressor unit, a nitrogen exclusion unit, a liquefaction unit, a helium recovery unit, 191. The method of claim 191, selected from and combinations thereof.   At least one first processing unit module type, and one or more second processing unit modules, wherein the processing unit module type having the product size is composed of one or more first processing unit modules. Comprising a second processing unit module type, wherein at least one of the first processing unit modules and at least one of the second processing unit modules has its substantially maximum processing efficiency. 193. The method of claim 192, wherein the method is made in such a size.   194. The method of claim 193, wherein the substantial maximum processing efficiency is within 25% of the actual maximum processing efficiency.   195. The method of claim 194, wherein the substantial maximum processing efficiency is within 15% of the actual maximum processing efficiency.   196. The method of claim 195, wherein the substantial maximum processing efficiency is within 10% of the actual maximum processing efficiency.   196. The maximum processing efficiency is the processing unit module capacity size for each processing unit module type that minimizes the life cycle cost of all processing unit modules per unit of processing unit module capacity. Method.   196. The method of claim 196, wherein the LNG liquefaction plant further comprises a third processing unit module type comprised of one or more third processing unit modules.   196. The method of claim 196, wherein the maximum feed capacity of the second processing unit module type is at least equal to the maximum feed capacity of the first processing unit module type.   The first and second processing unit module types have first and second construction costs per unit of maximum feedstock throughput, and the first construction cost per unit of maximum feedstock throughput is 199. The method of claim 199, wherein the second construction cost is exceeded per unit of the maximum feedstock throughput.   196. The method of claim 196, wherein the LNG liquefaction plant comprises at least one processing unit module type having a plurality of substantially equal sized processing unit modules in parallel.   202. The method of claim 201, wherein the LNG liquefaction plant comprises at least one of the processing unit module types having processing unit modules that are in parallel and formed in a plurality of substantially equal shapes.   199. The method of claim 198, wherein the third processing unit module type comprises a third processing unit module sized to substantially maximize processing efficiency.   The first processing unit module is configured with a first apparatus type, the second processing unit module is configured with a second processing apparatus type, and the third processing unit module is configured with a third apparatus type. 199. The method of claim 198, comprising a processor type.   205. The method of claim 204, wherein at least some of the device types are formed with substantially equal shapes.   206. The method of claim 205, wherein at least some of the device types are formed with substantially equal sizes.   200. The method of claim 199, wherein the maximum feed capacity of the first processing unit module type differs from the second processing unit module type by more than 10%.   207. The method of claim 207, wherein the second processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   207. The method of claim 207, wherein the first processing unit module type has a maximum feed capacity of less than 85% of the maximum feed capacity of the second processing unit module type.   209. The method of claim 208, wherein the second processing unit module type has a maximum feed capacity of less than 80% of the maximum feed capacity of the first processing unit module type.   209. The method of claim 209, wherein the first processing unit module type has a maximum feed capacity of less than 80% of the maximum feed capacity of the second processing unit module type.   207. The method of claim 207, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   207. The method of claim 207, wherein at least two of the processing unit module types have a maximum feed capacity of less than 85% of the maximum feed capacity of the second processing unit module type.   199. The method of claim 198, wherein the LNG liquefaction plant comprises a liquefaction unit, wherein the liquefaction unit is comprised of one or more cryogenic heat exchangers and a plurality of similar role refrigerant compressors.   224. The method of claim 214, wherein at least two of the plurality of compressors are arranged in parallel.   215. The method of claim 215, wherein the liquefaction unit comprises a plurality of cryogenic heat exchangers having a similar role, wherein the cryogenic heat exchangers are arranged in parallel.   226. The method of claim 216, wherein each of the plurality of compressors is in fluid communication with two or more cryogenic heat exchangers.   218. The method of claim 217, wherein the liquefaction unit is configured in a shape such that each of the plurality of compressors can be placed in fluid connection with any of the cryogenic heat exchangers.   222. The method of claim 218, wherein the plurality of cryogenic heat exchangers includes one or more module heat exchangers.   224. The method of claim 219, wherein the plurality of cryogenic heat exchangers include one or more plate-fin heat exchangers.   223. The method of claim 219, wherein the plurality of cryogenic heat exchangers include one or more spiral heat exchangers.   198. The LNG liquefaction plant has a plant maximum feedstock throughput and a plant minimum feedstock throughput, wherein the plant minimum feedstock throughput is no more than 75% of the plant maximum feedstock throughput. the method of.   223. The method of claim 222, wherein the plant minimum feed capacity is 65% or less of the plant maximum feed capacity.   224. The method of claim 223, wherein the plant minimum feed capacity is 55% or less of the plant maximum feed capacity.   199. The method of claim 198, wherein at least one of the processing unit module types comprises a variable speed compressor, a variable speed expander, or a combination thereof.   199. The method of claim 198, wherein the plant maximum feedstock throughput exceeds 4 million tonnes per year.   226. The method of claim 226, wherein the plant maximum feedstock throughput exceeds 6 million tonnes per year.   119. The method of claim 118, wherein the LNG liquefaction plant comprises two or more integrated processing unit module types.   229. The method of claim 228, wherein the LNG liquefaction plant comprises three or more integrated processing unit module types.   229. The method of claim 229, wherein the LNG liquefaction plant comprises four or more integrated processing unit module types. A method for producing liquefied natural gas using an LNG liquefaction plant, wherein the LNG liquefaction plant is composed of a plurality of processing unit module types, each of the plurality of processing unit module types being one or more processing unit modules And the method comprises:
A) providing at least one raw processing unit module for each processing unit module type included in the plurality of processing unit module types, resulting in a first stage LNG liquefaction plant;
B) producing a first LNG from the first stage LNG liquefaction plant;
C) Build one or more additional processing unit modules for one or more processing unit module types included in the first stage LNG liquefaction plant, while the manufacturing stage (B) Completing at least one part;
D) placing the one or more additional processing unit modules in operation, wherein the additional processing unit modules are integrated with the original processing unit module within the processing unit module mold, resulting in Giving a second stage LNG liquefaction plant; and
E) The above method, comprising the step of producing a second LNG from the second stage LNG liquefaction plant.   234. The method of claim 231, wherein said actuating step D is operated and said step B produces a first LNG.   234. The method of claim 231, wherein said actuating step D is at least partially run and said step B produces a first LNG.   231. The method of claim 231, wherein the actuating step D is at least partially run and the step B does not produce a first LNG.   234. The method of claim 234, wherein the actuating step D is at least partially in operation and does not produce a first LNG in step B for less than 10 days.   231. The method of claim 231, wherein at least one of the additional processing unit modules is sized to take each substantially maximum processing efficiency.   237. The method of claim 236, wherein the substantial maximum processing efficiency is within 25% of the actual maximum processing efficiency.   240. The method of claim 237, wherein the substantially maximum processing efficiency is within 15% of the actual maximum processing efficiency.   238. The method of claim 238, wherein the substantially maximum processing efficiency is within 10% of the actual maximum processing efficiency.   239. The maximum processing efficiency is the size of the processing unit module capability for each processing unit module type that minimizes the total processing unit module life cycle cost per unit of processing unit module capability. The method described.   245. The method of claim 240, wherein the original and additional processing unit modules are formed in substantially equal shapes.   242. The method of claim 241, wherein the raw processing unit module is configured with a raw device type and the additional processing unit module is configured with an additional processing device type.   243. The method of claim 242, wherein at least some of the device types are formed in substantially equal shapes.   244. The method of claim 243, wherein at least some of the device types are formed with substantially equal sizes.   254. The method of claim 244, wherein the LNG liquefaction plant comprises a liquefaction unit, the liquefaction unit being composed of one or more cryogenic heat exchangers and a plurality of similar role refrigerant compressors.   254. The method of claim 245, wherein at least two of the plurality of compressors are arranged in parallel.   246. The method of claim 246, wherein the liquefaction unit includes a plurality of cryogenic heat exchangers having a similar role, wherein the cryogenic heat exchangers are arranged in parallel.   247. The method of claim 247, wherein each of the plurality of compressors is in fluid communication with two or more cryogenic heat exchangers.   253. The method of claim 248, wherein the liquefaction unit is configured in a shape such that each of the plurality of compressors can be placed in fluid connection with any of the cryogenic heat exchangers.   249. The method of claim 249, wherein the plurality of cryogenic heat exchangers includes one or more module heat exchangers.   253. The method of claim 250, wherein the plurality of cryogenic heat exchangers include one or more plate-fin heat exchangers.   253. The method of claim 250, wherein the plurality of cryogenic heat exchangers include one or more spiral heat exchangers.   245. The LNG liquefaction plant has a plant maximum feedstock throughput and a plant minimum feedstock throughput, wherein the plant minimum feedstock throughput is 75% or less of the plant maximum feedstock throughput. the method of.   244. The method of claim 243, wherein the plant minimum feedstock throughput is 65% or less of the plant maximum feedstock throughput.   254. The method of claim 253, wherein the plant minimum feed capacity is 55% or less of the plant maximum feed capacity.   245. The method of claim 244, wherein at least one of the processing unit module types comprises a variable speed compressor, a variable speed expander, or a combination thereof.   245. The method of claim 244, wherein the plant maximum feedstock throughput exceeds 4 million tonnes per year.   258. The method of claim 257, wherein the plant maximum feedstock throughput exceeds 6 million tonnes per year.   245. The method of claim 244, wherein the LNG liquefaction plant comprises two or more integrated processing unit module types.   259. The method of claim 259, wherein the LNG liquefaction plant comprises three or more integrated processing unit module types.   262. The method of claim 260, wherein the LNG liquefaction plant comprises four or more integrated processing unit module types.   One or more processing unit module types having a product size having a high construction cost and one or more processing unit module types having a product size having a low construction cost, and having at least one of the low construction costs, A processing unit module type with a product size has a maximum feed material processing capacity of at least 110% of the maximum feed material processing capacity of a processing unit module type with a product size of at least one of the high construction costs LNG liquefaction plant.   The processing unit module type with the product size of the high construction cost is not less than 1.25 times the total construction cost per unit of the maximum feed material processing capacity of the processing unit module type with the product size of the low construction cost, 263. An LNG liquefaction plant according to claim 262, having a total construction cost per unit of maximum feedstock throughput.   262. The LNG liquefaction plant of claim 262, wherein the low build cost, process unit module type with product size is selected from an acid gas removal unit, a dehydration unit, a fractionation unit, a nitrogen exclusion unit, and a helium recovery unit.   262. The LNG liquefaction plant of claim 262, wherein the high construction cost, processing unit module type with product size is selected from an installation facility unit, a refrigerant compressor unit, a cryogenic heat exchanger unit, and a liquefaction unit.   A first processing unit module type, and one or more integrated second processing unit modules, wherein the processing unit module type having the product size is composed of one or more first processing unit modules; At least a second processing unit module type, wherein at least one of the first processing unit modules and at least one of the second processing unit modules are each substantially maximum processing. 262. The method of claim 262, wherein the method is made in a size that is efficient.   273. The method of claim 266, wherein the substantially maximum processing efficiency is within 25% of the actual maximum processing efficiency.   268. The method of claim 267, wherein the substantially maximum processing efficiency is within 15% of the actual maximum processing efficiency.   268. The method of claim 268, wherein the substantially maximum processing efficiency is within 10% of the actual maximum processing efficiency.   269. The maximum processing efficiency is the size of the processing unit module capability for each processing unit module type that minimizes the life cycle cost of all processing unit modules per unit of processing unit module capability. the method of.   269. The method of claim 269, wherein the LNG liquefaction plant further comprises a third processing unit module type comprised of one or more third processing unit modules.   269. The method of claim 269, wherein the maximum processing capacity of the second processing unit module type is at least equal to the maximum processing capacity of the first processing unit module type.   The first and second processing unit module types have first and second construction costs per unit of maximum feedstock throughput, and the first construction cost per unit of maximum feedstock throughput is 273. The method of claim 272, wherein the second construction cost is exceeded per unit of the maximum feedstock throughput.   269. The method of claim 269, wherein the LNG liquefaction plant comprises at least one of the processing unit module types in parallel and having a plurality of substantially equal sized processing unit modules.   274. The method of claim 274, wherein the LNG liquefaction plant comprises at least one processing unit module type having processing unit modules in parallel and formed in a plurality of substantially equal shapes.   278. The method of claim 271, wherein the third processing unit module type comprises a third processing unit module that is sized to provide substantially maximum processing efficiency.   The first processing unit module is configured with a first apparatus type, the second processing unit module is configured with a second processing apparatus type, and the third processing unit module is configured with a third apparatus type. 272. The method of claim 271, comprising a processor type.   277. The method of claim 277, wherein at least some of the device types are formed with substantially equal shapes.   278. The method of claim 278, wherein at least some of the device types are formed with substantially equal sizes.   278. The method of claim 271, wherein the maximum feed capacity of the first processing unit module type differs from the capacity of the second processing unit module type by more than 10%.   280. The method of claim 280, wherein the second processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   280. The method of claim 280, wherein the first processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   292. The method of claim 281, wherein the second processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the first processing unit module type.   283. The method of claim 282, wherein the first processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the second processing unit module type.   290. The method of claim 280, wherein at least two of the processing unit module types have a maximum feed capacity of less than 85% of the maximum feed capacity of the first processing unit module type.   280. The method of claim 280, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   278. The method of claim 271, wherein the LNG liquefaction plant comprises a liquefaction unit, the liquefaction unit being composed of one or more cryogenic heat exchangers and a plurality of similar role refrigerant compressors.   288. The method of claim 287, wherein at least two of the plurality of compressors are arranged in parallel.   288. The method of claim 288, wherein the liquefaction unit comprises a plurality of cryogenic heat exchangers having a similar role, wherein the cryogenic heat exchangers are arranged in parallel.   290. The method of claim 289, wherein each of the plurality of compressors is in fluid communication with two or more cryogenic heat exchangers.   290. The method of claim 290, wherein the liquefaction unit is formed in a shape such that each of the plurality of compressors can be placed in fluid connection with any of the cryogenic heat exchangers.   292. The method of claim 291, wherein the plurality of cryogenic heat exchangers includes one or more module heat exchangers.   292. The method of claim 292, wherein the plurality of cryogenic heat exchangers include one or more plate-fin heat exchangers.   292. The method of claim 292, wherein the plurality of cryogenic heat exchangers includes one or more spiral heat exchangers.   271. The LNG liquefaction plant has a plant maximum feedstock throughput and a plant minimum feedstock throughput, wherein the plant minimum feedstock throughput is 75% or less of the plant maximum feedstock throughput. the method of.   302. The method of claim 295, wherein the plant minimum feedstock throughput is 65% or less of the plant maximum feedstock throughput.   303. The method of claim 296, wherein the plant minimum feed capacity is 55% or less of the plant maximum feed capacity.   278. The method of claim 271, wherein at least one of the processing unit module types comprises a variable speed compressor, a variable speed expander, or a combination thereof.   278. The method of claim 271, wherein the plant maximum feedstock throughput exceeds 4 million tonnes per year.   302. The method of claim 299, wherein the plant maximum feedstock throughput exceeds 6 million tons per year.   278. The method of claim 271, wherein the LNG liquefaction plant comprises two or more integrated processing unit module types.   302. The method of claim 301, wherein the LNG liquefaction plant comprises three or more integrated processing unit module types.   330. The method of claim 302, wherein the LNG liquefaction plant comprises four or more integrated processing unit module types. A method for producing liquefied natural gas comprising the following steps:
A) preparing an LNG liquefaction plant including a plurality of processing unit module types, wherein the LNG liquefaction plant has at least one first refrigerant circuit, and the first refrigerant circuit is at least one first refrigerant circuit. The first refrigerant compressor service type is composed of one or more first raw refrigerant compressors in parallel, and the LNG liquefaction plant has a maximum plant supply. Has material processing capability;
B) Expanding the plant maximum feed capacity of the LNG liquefaction plant by adding at least one additional first refrigerant compressor to the first refrigerant compressor service type, wherein the additional The first refrigerant compressor is integrated with one or more of the original first refrigerant compressors in the first refrigerant compressor service type; and
C) producing the LNG in the LNG liquefaction plant after the start of the expansion step (B).   305. The method of claim 304, wherein the at least one first raw refrigerant compressor and the at least one additional first refrigerant compressor are of substantially equal size.   302. The method of claim 305, wherein at least one of the first raw refrigerant compressor and at least one of the additional first refrigerant compressors are substantially equal and mechanically formed.   307. The method of claim 306, wherein the first raw refrigerant compressor comprises a plurality of first refrigerant compressors, and the plurality of first raw refrigerant compressors has a maximum overall throughput.   307. The method of claim 307, wherein the maximum overall throughput is less than that of the largest commercially available compressor.   307. The method of claim 307, wherein each of the plurality of first raw refrigerant compressors has a processing capacity less than that of the largest commercially available compressor.   307. The method of claim 307, wherein the first raw refrigerant compressor comprises an electrically driven compressor.   307. The method of claim 306, wherein the first raw refrigerant compressor comprises a gas turbine driven compressor.   The first refrigerant circuit further includes one or more plate-fin heat exchangers, wherein the plate-fin heat exchangers pass through natural heat exchange with the refrigerant compressed by the first refrigerant compressor. 307. The method of claim 306, suitable for cooling a gas stream.   312. The method of claim 312, wherein the one or more plate-fin heat exchangers comprise a plurality of plate-fin heat exchangers arranged in a cooling box.   The first refrigerant circuit further includes one or more spiral heat exchangers through which the natural gas stream passes through heat exchange with the refrigerant compressed by the first refrigerant compressor. 306. The method of claim 306, suitable for cooling.   The processing unit module type is composed of one or more first processing unit modules, a first processing unit module type, and one or more integrated second processing unit modules; At least a second processing unit module type, wherein at least one of the first processing unit modules and at least one of the second processing unit modules has a respective maximum processing efficiency. 305. The method of claim 304, wherein the method is made in size.   315. The method of claim 315, wherein the substantial maximum processing efficiency is within 25% of the actual maximum processing efficiency.   330. The method of claim 316, wherein the substantial maximum processing efficiency is within 15% of the actual maximum processing efficiency.   317. The method of claim 317, wherein the substantially maximum processing efficiency is within 10% of the actual maximum processing efficiency.   318. The maximum processing efficiency is the size of the processing unit module capability for each processing unit module type that minimizes the total processing unit module life cycle cost per unit of processing unit module capability. The method described.   321. The method of claim 318, wherein the LNG liquefaction plant further comprises a third processing unit module type, comprising one or more third processing unit modules.   342. The method of claim 318, wherein the maximum processing capacity of the second processing unit module type is at least equal to the maximum processing capacity of the first processing unit module type.   The first and second processing unit module types have first and second construction costs per unit of maximum feedstock throughput, and the first construction cost per unit of maximum feedstock throughput is 321. The method of claim 321, wherein the second construction cost is exceeded per unit of the maximum feedstock throughput.   319. The method of claim 318, wherein the LNG liquefaction plant comprises at least one processing unit module type having a plurality of substantially equal sized processing unit modules in parallel.   323. The method of claim 323, wherein the LNG liquefaction plant includes at least one of the processing unit module types having processing unit modules that are in parallel and formed in a plurality of substantially equal shapes.   332. The method of claim 320, wherein the third processing unit module type comprises a third processing unit module sized to substantially maximize processing efficiency.   The first processing unit module is configured with a first apparatus type, the second processing unit module is configured with a second processing apparatus type, and the third processing unit module is configured with a third apparatus type. 332. The method of claim 320, wherein the method comprises a processor type.   327. The method of claim 326, wherein at least some of the device types are formed with substantially equal shapes.   327. The method of claim 327, wherein at least some of the device types are formed with substantially equal sizes.   332. The method of claim 320, wherein the maximum feed capacity of the first processing unit module type differs from the capacity of the second processing unit module type by more than 10%.   343. The method of claim 329, wherein the second processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   345. The method of claim 329, wherein the first processing unit module type has a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   340. The method of claim 330, wherein the second processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the first processing unit module type.   331. The method of claim 331, wherein the first processing unit module type has a maximum feed capacity that is less than 80% of the maximum feed capacity of the second processing unit module type.   329. The method of claim 329, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the first processing unit module type.   345. The method of claim 329, wherein at least two of the processing unit module types have a maximum feed capacity that is less than 85% of the maximum feed capacity of the second processing unit module type.   332. The method of claim 320, wherein the LNG liquefaction plant comprises a liquefaction unit, the liquefaction unit being composed of one or more cryogenic heat exchangers and a plurality of refrigerant compressors with similar roles.   327. The method of claim 326, wherein at least two of the plurality of compressors are arranged in parallel.   337. The method of claim 337, wherein the liquefaction unit includes a plurality of cryogenic heat exchangers having a similar role, wherein the cryogenic heat exchangers are arranged in parallel.   338. The method of claim 338, wherein each of the plurality of compressors is in fluid communication with two or more cryogenic heat exchangers.   348. The method of claim 339, wherein the liquefaction unit is formed in a shape such that each of the plurality of compressors can be placed in fluid connection with any of the cryogenic heat exchangers.   340. The method of claim 340, wherein the plurality of cryogenic heat exchangers include one or more modular heat exchangers.   342. The method of claim 341, wherein the plurality of cryogenic heat exchangers include one or more plate-fin heat exchangers.   342. The method of claim 341, wherein the plurality of cryogenic heat exchangers include one or more spiral heat exchangers.   335. The LNG liquefaction plant has a plant maximum feedstock throughput and a plant minimum feedstock throughput, wherein the plant minimum feedstock throughput is 75% or less of the plant maximum feedstock throughput. the method of.   347. The method of claim 344, wherein the plant minimum feedstock throughput is 65% or less of the plant maximum feedstock throughput.   346. The method of claim 346, wherein the plant minimum feed capacity is 55% or less of the plant maximum feed capacity.   341. The method of claim 320, wherein at least one of the processing unit module types comprises a variable speed compressor, a variable speed expander, or a combination thereof.   335. The method of claim 320, wherein the plant maximum feedstock throughput exceeds 4 million tonnes per year.   347. The method of claim 348, wherein the plant maximum feedstock throughput exceeds 6 million tons per year.   332. The method of claim 320, wherein the LNG liquefaction plant comprises two or more integrated processing unit module types.   356. The method of claim 350, wherein the LNG liquefaction plant comprises three or more integrated processing unit module types.   361. The method of claim 351, wherein the LNG liquefaction plant comprises four or more integrated processing unit module types. A method for producing liquefied natural gas using an LNG liquefaction plant, wherein the LNG liquefaction plant includes a plurality of processing unit module types, and each of the plurality of processing unit module types includes one or more processing unit modules. Including the following steps:
A) providing at least one raw processing unit module for each processing unit module type included in the plurality of processing unit module types to provide a first stage LNG liquefaction plant;
B) Providing a second stage LNG liquefaction plant by providing at least one second processing unit module for each processing unit module type included in the plurality of processing unit module types;
C) integrating two or more of each processing unit module type with one or more of the original processing unit modules and one or more of the second processing unit modules; and
And D) producing the LNG from the LNG liquefaction plant after the integration step (C) is started.   The integration step C includes integrating one or more original processing unit modules and one or more second processing unit modules of each of three or more processing unit module types. 354. The method of claim 353, comprising.   The integration step C includes integrating one or more original processing unit modules and one or more second processing unit modules of each of four or more processing unit module types. 354. The method of claim 354, comprising:   The integration step C includes the step of integrating all the one or more original processing unit modules and the one or more second processing unit modules of the plurality of processing unit module types. 356. The method of claim 355.   356. The method of claim 353, wherein the second processing unit module is sized to take its substantially maximum processing efficiency.   360. The method of claim 357, wherein the substantially maximum processing efficiency is within 25% of the actual maximum processing efficiency.   359. The method of claim 358, wherein the substantial maximum processing efficiency is within 15% of the actual maximum processing efficiency.   363. The method of claim 359, wherein the substantial maximum processing efficiency is within 10% of the actual maximum processing efficiency.   360. The maximum processing efficiency is the size of the processing unit module capacity for each processing unit module type that minimizes the life cycle cost of all processing unit modules per unit of processing unit module capacity. The method described.   365. The method of claim 360, wherein the original and second processing unit modules of the same processing unit module type are formed in substantially equal shapes.   363. The method of claim 362, wherein the raw processing unit module is configured with an original equipment type and the second processing unit module is configured with a second processing equipment type.   363. The method of claim 363, wherein at least some of the device types are formed with substantially equal shapes.   364. The method of claim 364, wherein at least some of the device types are formed with substantially equal sizes.   368. The method of claim 365, wherein the LNG liquefaction plant comprises a liquefaction unit, the liquefaction unit being composed of one or more cryogenic heat exchangers and a plurality of similar role refrigerant compressors.   366. The method of claim 366, wherein at least two of the plurality of compressors are arranged in parallel.   367. The method of claim 367, wherein the liquefaction unit includes a plurality of cryogenic heat exchangers having a similar role, wherein the cryogenic heat exchangers are arranged in parallel.   371. The method of claim 368, wherein each of the plurality of compressors is in fluid communication with two or more cryogenic heat exchangers.   369. The method of claim 369, wherein the liquefaction unit is formed in a shape such that each of the plurality of compressors can be placed in fluid connection with any of the cryogenic heat exchangers.   370. The method of claim 370, wherein the plurality of cryogenic heat exchangers includes one or more module heat exchangers.   371. The method of claim 371, wherein the plurality of cryogenic heat exchangers include one or more plate-fin heat exchangers.   371. The method of claim 371, wherein the plurality of cryogenic heat exchangers include one or more spiral heat exchangers.   363. The LNG liquefaction plant has a plant maximum feedstock throughput and a plant minimum feedstock throughput, wherein the plant minimum feedstock throughput is not more than 75% of the plant maximum feedstock throughput. the method of.   374. The method of claim 374, wherein the plant minimum feedstock throughput is 65% or less of the plant maximum feedstock throughput.   375. The method of claim 375, wherein the plant minimum feedstock throughput is 55% or less of the plant maximum feedstock throughput.   365. The method of claim 360, wherein at least one of the processing unit module types comprises a variable speed compressor, a variable speed expander, or a combination thereof.   363. The method of claim 360, wherein the plant maximum feedstock throughput exceeds 4 million tonnes per year.   379. The method of claim 378, wherein the plant maximum feedstock throughput exceeds 6 million tons per year.   The method according to any one of the preceding claims, wherein the LNG liquefaction plant comprises one or more internally integrated processing unit modules.   The LNG liquefaction plant according to any one of the preceding claims, wherein the LNG liquefaction plant comprises one or more internally integrated processing unit modules.   A method according to any one of the preceding claims, wherein the LNG liquefaction plant comprises two or more partially integrated processing unit modules.   The LNG liquefaction plant according to any one of the preceding claims, wherein the LNG liquefaction plant comprises two or more processing unit modules integrated in parallel.   A plurality of processing unit module types and two or more integrated processing unit module types, wherein the plurality of processing unit module types comprise one or more first processing unit modules Comprising at least one second processing unit module type comprised of a first processing unit module type and two or more integrated second processing unit modules. An LNG liquefaction plant, wherein the first processing unit module and the at least one second processing unit module are each sized to obtain a substantially maximum processing efficiency.

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