KR20180064471A - Integrated Cooling and Liquefaction Modules in Hydrocarbon Processing Plants - Google Patents

Abstract

The present invention relates to a method of treating natural gas producing liquefied natural gas using integrated cooling and liquefaction modules. Natural gas is cooled in a first array of one or more heat exchangers using a first refrigerant from a first refrigerant circuit, and the first refrigerant is compressed in a first compressor. The second refrigerant from the second refrigerant circuit is cooled and partially condensed using the first refrigerant in the second array of one or more heat exchangers located in the integrated cooling and liquefaction module. The partially condensed second refrigerant is separated into a liquid phase and a vapor phase using a refrigerant separator located in an integrated cooling and liquefaction module. The natural gas is liquefied to produce LNG in a third array of one or more heat exchangers using the vapor phase and liquid phase of the partially condensed second refrigerant.

Description

Integrated Cooling and Liquefaction Modules in Hydrocarbon Processing Plants

Cross-reference to related application

This application is related to U.S. Provisional Patent Application No. 62 / 237,842, filed October 6, 2015, entitled " Integrated Cooling and Liquefaction Module in a Hydrocarbon Processing Plant ", the entire contents of which are incorporated herein by reference. Claim priority.

The present invention generally relates to the field of hydrocarbon handling and treatment plants. More particularly, the present invention relates to the efficient construction and operation of hydrocarbon handling and processing plants such as LNG processing plants.

This section is intended to introduce various aspects of the art which may be related to the present invention. This description is intended to provide a framework for a better understanding of certain aspects of the invention. Accordingly, it is to be understood that this section must be read in this light and not necessarily to the prior art.

As competition for LNG production contracts becomes more intense, the need to improve the profitability of future LNG projects is increasing significantly. To this end, LNG producers can identify and optimize key cost drivers and efficiencies applicable to each project. In order to carry out projects economically in a location where costs are high and site labor productivity is low, the scope and scale of field work required to construct and commission LNG plants must be minimized. Modularization technology is used to address this problem by changing the area from being built in the field to a specialized fabrication yard. However, for large LNG projects, modularization of the construction scope can still result in significant site integration costs. The previous modularization solution involved dividing as many LNG plants into modules, pre-fabricating the modules at the manufacturing site and transporting the modules to the operating site, where the modules were to form LNG plants . This solution can require considerable labor at the site, which can be financially understood when the labor cost is low at the site. However, for labor sites with high labor costs, this solution increases labor costs and is too costly to build an LNG plant. Therefore, the plant construction industry recognizes the need to remove additional work from the plant site in comparison with other modular methods currently being developed in the industry.

1 is a schematic diagram of an LNG production facility 10 in accordance with the known principles. The feed gas in the feed gas line 12 is precooled in a first cooler 14 using a first coolant such as propane. The feed gas is then cooled and liquefied in the main cryogenic heat exchanger 16 using mixed refrigerant. The liquefied natural gas is expanded in a hydraulic turbine 18 or similar expansion device and stored in the LNG storage tank 20. A boil-off gas compressor 22 compresses the liquefied natural gas before it is transported from the LNG storage tank 20.

The first refrigerant and the mixed refrigerant circulate through separate refrigerant loops. The first refrigerant loop is compressed in one or more compressors (24a, 24b) and is further processed (a) in a desuperheater for cooling the hot vapor to saturated vapor, (b) in a condenser for condensing the saturated vapor in liquid form (C) cooled in a sub-cooler. Functions (a) - (c) are shown in FIG. 1 by cooler element 28. The first refrigerant cooled and liquefied at this point is substantially in liquid form. A first portion of the liquefied first refrigerant is directed to a first cooler 14 where the first refrigerant precools the feed gas in the feed gas line 12 as described above. A second portion of the liquefied first refrigerant is sent to a second cooler 30 wherein the first refrigerant precools the mixed refrigerant. The first refrigerant, now substantially in vapor form, is sent from the first cooler 14 and the second cooler 30 to the compressors 24a and 24b, and the first coolant loop is repeated.

In the mixed refrigerant loop, the mixed refrigerant leaving the main cryogenic heat exchanger 16 is in a vapor state and flows through a series of compressors 32a, 32b, 34a, 34b and inter-stage coolers 36a , 36b, 38a, 38b. The mixed refrigerant exiting the discharge coolers 38a, 38b is sent to the second cooler 30 where it is further cooled by the second portion of the first refrigerant. The mixed refrigerant is then sent to a combined refrigerant separator 40 which separates and outputs the mixed refrigerant liquid stream (line 42) and the mixed refrigerant vapor stream (line 44). All of the lines 42 and 44 are connected to the main cryogenic heat exchanger 16 where the cooled refrigerant cools and liquefies the cooled inlet gas sent from the first cooler 14. The mixed refrigerant exiting the main cryogenic heat exchanger 16 is substantially in a vapor state and is sent to the compressors 32a and 32b to continue the mixed refrigerant loop. In the LNG production facility 10, the compressors 24a, 32a and 34a are connected to a common shaft 46a and are powered by the turbine assembly 48a. Similarly, compressors 24b, 32b and 34b are connected to common shaft 46b and are powered by turbine assembly 48b. Other compressor and driver configurations as known to those skilled in the art can be developed.

Figure 2 shows a known layout of an LNG production facility 200, which may be referred to as an LNG train. The LNG train 200 includes a plurality of processing modules 202a, 202b, 202c, 202d arranged along a central pipe hanger 204. The processing modules 202a-d are coupled to a plurality of pipes that guide the utility stream, the injection gas, the resulting product and byproducts as needed, and any functional units within the pipe hanger through conduits. The processing modules include an acidic gas removal unit for removing CO ₂ and H ₂ S molecules from the injection gas to a very low level required to prevent freezing in downstream cooling and liquefaction units; A dewatering unit for removing water molecules from the injection gas to a very low level necessary to prevent freezing in downstream cooling and liquefaction units; From the injection gas below the level necessary to prevent freezing in the downstream cooling and liquefaction units, and the like heavy hydrocarbon trapping device (heavy hydrocarbon capture, HHC), or heavy hydrocarbon removal unit that removes the C ₆ ⁺ molecule. Additionally, the refrigeration processing module 206 includes one or more inlet gas propane coolers 14 and one or more mixed refrigerant coolers 30, as shown in FIG. The liquefaction processing module 208 includes lines 42 and 44 connected to the main cryogenic heat exchanger 16 which can be located adjacent to the liquefied processing module 208 as well as the mixed refrigerant separator 40. Each processing module is preassembled at a manufacturing yard or other external manufacturing location, transported to the operating site of the LNG train, and connected to each other to construct a completed LNG train.

The LNG train 200 shown in Figure 2 illustrates a known attempt to modularize the gas treatment plant design and is characterized by the installation of processing modules along the central pipe hanger 204, The piping connection is routed through the central pipe hanger 204. The central pipe hanger can be formed by pipe hanger segments or modules that are built at the manufacturing site, transported to the operating site, and assembled together at the site of operation. However, this modularization strategy results in a significant number of pipe connections at the interface between the processing modules and the central pipe hanger. Connecting the pipe connections at the site is labor intensive. In addition, all the lines connecting the two processing modules, such as the refrigeration processing module 206 and the liquefaction processing module 208, must pass through the central pipe hanger to do so, and each of the central pipe hanger segments At the connection there will be at least two field connections. Since there may be significant connections between the freezing process module 206 and the liquefaction process module 208, connecting these two modules at the operating site can result in considerable time and cost. There is a need for a hydrocarbon treatment plant design that minimizes such assembly costs.

The present invention provides a method of treating natural gas producing liquefied natural gas (LNG) using an integrated cooling and liquefaction module. Natural gas is cooled in a first array of one or more heat exchangers using a first refrigerant from a first refrigerant circuit, and the first refrigerant is compressed in a first compressor. The second refrigerant from the second refrigerant circuit is compressed in the second compressor. The compressed second refrigerant is cooled and partially condensed using a first refrigerant in a second array of one or more heat exchangers located in an integrated cooling and liquefaction module. The partially condensed second refrigerant is separated into a liquid phase and a vapor phase using a refrigerant separator located in an integrated cooling and liquefaction module. The natural gas producing LNG in the third array of one or more heat exchangers using the vapor phase and liquid phase of the partially condensed second refrigerant is liquefied.

The present invention also relates to a refrigerant circuit comprising: a first refrigerant circuit; A first refrigerant configured to circulate in the first refrigerant circuit; A first compressor configured to compress the first refrigerant; A first array of one or more heat exchangers configured to cool the hydrocarbon stream using the first refrigerant; A second refrigerant circuit; A second refrigerant configured to circulate in the second refrigerant circuit; A second compressor configured to compress the second refrigerant; A second array of one or more heat exchangers configured to cool and partially condense the compressed second refrigerant using the first refrigerant; A refrigerant separator configured to separate the partially condensed second refrigerant into a liquid phase and a vapor phase; A third array of one or more heat exchangers configured to liquefy the hydrocarbon stream using the vapor phase and liquid phase of the partially condensed second refrigerant; And an integrated cooling and liquefaction module in which a second array of the at least one heat exchanger and the refrigerant separator are located.

The foregoing is a broad summary of features of the present invention in order that the following detailed description can be better understood. Additional features will also be described in the detailed description.

These and other features, aspects, and advantages of the present invention will become apparent from the following description, the claims, and the accompanying drawings, which will be briefly described below.
1 is a schematic diagram of an LNG liquefaction process in accordance with known principles;
2 is a plan view of an LNG train in accordance with known principles;
3 is a schematic diagram of an LNG liquefaction process according to the disclosed embodiment;
4 is a plan view of an LNG train in accordance with the disclosed aspect;
5 is a top plan view of an integrated cooling and liquefaction module in accordance with the disclosed aspects.
6 is a top plan view of an integrated cooling and liquefaction module according to the disclosed aspects.
7 is a top plan view of an integrated cooling and liquefaction module in accordance with the disclosed aspect;
8 is a top plan view of an integrated cooling and liquefaction module in accordance with the disclosed aspects.
9 illustrates a method of designing an LNG train in accordance with known principles;
It should be noted that the drawings are only examples, and no limitation to the scope of the invention is thereby intended. In addition, the drawings are not drawn to scale and are shown in the drawings for purposes of convenience and clarity in illustrating various aspects of the present invention.

For purposes of understanding the principles of the invention, reference will be made to the features shown in the drawings, and specific language will be used to describe it. It will nevertheless be understood that no limitation of the scope of the invention is intended. Any alterations and further modifications as herein described and any further application of the principles of the invention are contemplated as would normally occur to one skilled in the art. It will be apparent to those skilled in the art that certain features not relevant to the invention may not be shown in the drawings for clarity.

Initially, for ease of reference, certain terms used in the present application and their meanings used in this context are presented. Unless the terms used herein are defined below, the broadest definition should be given to a person skilled in the art to give at least one printed matter or a term as reflected in the issued patent. Furthermore, the present technology is not limited by the use of the following terms, as all equivalents, synonyms, new developments, and terms or descriptions providing the same or similar purpose are considered to be within the scope of the present claims.

As one of ordinary skill in the art will appreciate, different persons may refer to the same features or components with different names. This document is not intended to distinguish between different components or features. The drawings are not necessarily scale. Certain features and elements may be shown in exaggerated or schematic form in the figures, and some details of conventional elements may not be shown for clarity and brevity. Referring to the drawings described herein, the same reference numerals may be referred to in the several figures for the sake of simplicity. In the following description and claims, the words "comprising" and "comprising" are used in a non-limiting sense and therefore should be construed to mean "including but not limited to.

The singular < RTI ID = 0.0 > term < / RTI > does not necessarily imply only one, but rather is inclusive and non-limiting and may optionally include a plurality of such elements.

The terms "acidic gas" and "sour gas" refer to any gas that is dissolved in water to produce an acidic solution. Non-limiting examples of acid gases include hydrogen sulfide (H ₂ S), carbon dioxide (CO ₂ ), or sulfur dioxide (SO ₂ ), or mixtures thereof.

As used herein, the terms "about," " about, "" substantially, "and similar terms are conventional and are intended to have a broad meaning in concert with the usage accepted by the skilled artisan. Those of ordinary skill in the art will appreciate that these terms are intended to be illustrative only and not to limit the scope of such features to the exact numerical range provided, It should be understood that it was intended. Accordingly, these terms are to be construed as indicating that substantial or minor changes or modifications of the above-described subject matter are considered to be within the scope of the present invention.

The term "heat exchanger " refers to a device designed to efficiently transfer or" exchange "heat from one material to another. Exemplary heat exchanger configurations include, but are not limited to, co-current or countercurrent heat exchangers, indirect heat exchangers (e.g., spiral wound heat exchangers, plate-fin heat exchangers such as brazed aluminum plate- heat exchangers, shell and tube heat exchangers, etc.), direct contact heat exchangers, or combinations thereof.

The phrases "gas stream "," vapor stream ", and "liquid stream" may refer to situations where gases, vapors and liquids are respectively present in the streams, For example, gas may also be present in a "liquid stream ". In some instances, the terms "gas stream" and "vapor stream" may be used interchangeably.

The present invention relates to systems and methods for the standardized design and construction of hydrocarbon handling and processing plants such as LNG trains. In one aspect, a significant number of connections between modules and / or processing units can be eliminated by placing many or all of the components associated with cooling and liquefying natural gas in a single processing module. The integrated cooling and liquefaction module is either completely or significantly constructed at the manufacturing site remote from the operating site of the hydrocarbon handling and processing plant and then transported to the operating site where the integrated cooling and liquefaction module is connected to the hydrocarbon handling and processing plant Lt; / RTI > In one aspect, at least a portion of the remainder of the hydrocarbon handling and processing plant is made up of modules that are also assembled or manufactured at the manufacturing site, transported to the operating site, and assembled at the site of operation to form the hydrocarbon handling and processing plant. The integrated cooling and liquefaction module may be connected to one or more of the remaining modules of the hydrocarbon handling and processing plant.

Figures 3-5 of the present invention show various aspects of the system and method as compared to known LNG plant layouts. 3 is a schematic diagram of an LNG production facility 300 in accordance with the known principles. The feed gas in the feed gas line 312 is precooled in the first cooler 314 using a first coolant such as propane. The feed gas is then cooled and liquefied in the main cryogenic heat exchanger 316 using mixed refrigerant. The liquefied natural gas is expanded in a hydraulic turbine 318 or similar expansion device and stored in the LNG storage tank 320. Boiling gas compressor 322 compresses the liquefied natural gas leaving / leaving LNG storage tank 320.

The first refrigerant and the mixed refrigerant circulate through separate refrigerant loops. The first refrigerant loop is compressed in one or more compressors (324a, 324b) and is further processed in a condenser that condenses (a) high temperature steam into saturated steam, (b) saturated steam in liquid form, c) cooled in the subcooler. Functions (a) - (c) are shown in FIG. 3 by cooler element 328. The first refrigerant cooled and liquefied at this point is substantially in liquid form. A first portion of the liquefied first refrigerant is sent to a first cooler 314 where the first refrigerant precools the feed gas in the feed gas line 312 as described above. A second portion of the liquefied first refrigerant is sent to a second cooler 330 where the first refrigerant precools the mixed refrigerant. The first refrigerant, now substantially in vapor form, is sent from first cooler 314 and second cooler 330 to compressors 324a and 324b, and the first coolant loop is repeated.

In the mixed refrigerant loop, the mixed refrigerant leaving the main cryogenic heat exchanger 316 is in a vapor state and flows through a series of compressors 332a, 332b, 334a, 334b and interstage coolers and discharge coolers 336a, 336b, 338a, 338b Lt; / RTI > and cooled. The mixed refrigerant exiting the discharge coolers 338a, 338b is sent to the second cooler 330 where it is further cooled by the second portion of the first refrigerant. The mixed refrigerant is then sent to a combined refrigerant separator 340 which separates and outputs the mixed refrigerant liquid stream (line 342) and the mixed refrigerant vapor stream (line 344). All of the lines 342 and 344 are connected to the main cryogenic heat exchanger 316 where the refrigerant cools and liquefies the cooled inlet gas sent from the first cooler 314. The mixed refrigerant exiting the main cryogenic heat exchanger 316 is substantially in a vapor state and is sent to compressors 332a and 332b to continue the mixed refrigerant loop. In LNG production facility 310, compressors 324a, 332a and 334a are connected to a common shaft 346a and are powered by turbine assembly 348a. Similarly, compressors 324b, 332b and 34b are connected to a common shaft 346b and are powered by turbine assembly 348b. Other compressor and driver configurations as known to those skilled in the art can be developed.

FIG. 4 illustrates a layout of an LNG production facility 400, which may be referred to as an LNG train, in accordance with the disclosed aspects. The LNG train 400 includes a plurality of processing modules 402a, 402b, 402c, 402d disposed along a central pipe hanger 404. Each processing module is preassembled at a production yard or other external manufacturing location, transported to the operating site of the LNG train, and connected to each other to construct a completed LNG train. The processing modules 402a-d are interconnected with any functional units within the pipe hanger through a plurality of pipes and conduits that guide the injection gas and, if necessary, the product and byproducts as needed. The processing modules include an acidic gas removal unit for removing CO ₂ and H ₂ S molecules from the injection gas to a very low level required to prevent freezing in downstream cooling and liquefaction units; A dewatering unit for removing water molecules from the injection gas to a very low level required to prevent freezing in downstream cooling and liquefaction units; From the injection gas below the level necessary to prevent freezing in the downstream cooling and liquefaction units, and the like heavy hydrocarbon trapping device (HHC), or heavy hydrocarbon removal unit that removes the C ₆ ⁺ molecule.

In one aspect, the integrated refrigeration and liquefaction module 406 includes one or more injection gas propane coolers 314 and one or more mixed refrigerant coolers 330. The integrated refrigeration and liquefaction module 406 is also connected to the main cryogenic heat exchanger 316 which may be located on or adjacent to the integrated refrigeration and liquefaction module 406 as well as the combined refrigerant separator 340. [ 344 and 342, respectively. Additional arrays of cooling elements, such as fin fan coolers, are located with the inlet gas propane coolers 314, mixed refrigerant coolers 330, and / or the main cryogenic heat exchanger 316. Additionally, all piping, valve devices, tools, and auxiliary components associated with the inlet gas propane cooler 314, mixed refrigerant cooler 330, mixed refrigerant separator 340, and / or the main cryogenic heat exchanger 316, And / or other articles may be located on or in the integrated cooling and liquefaction module 406. [ The integrated cooling and liquefaction module 406 may also include one or more hydraulic turbines 318 for isentropic expansion of the LNG and / or one or more hydraulic turbines for isentropic expansion of the mixed refrigerant. The arrangement shown in Figs. 4 and 5 is similar to the arrangement shown in Fig. 4, except that the previously-required labor intensive piping connection (not shown) is required to be performed at the moving site to connect the feed gas propane chiller 14 to the main cryogenic heat exchanger 16 via the central pipe hanger 202 Lt; / RTI > Instead, cooled injected gas exiting the injection gas propane cooler 314 is directly connected to the main cryogenic heat exchanger 316 on or adjacent to the integrated cooling and liquefaction module 406. This arrangement also removes the pipe connections required to be made at the operating site to connect the mixed refrigerant propane coolers 30 to the combined refrigerant separator 40 through the central pipe hanger 202. The mixed refrigerant exiting the mixed refrigerant propane cooler 330 is directly connected to the high pressure mixed refrigerant separator 340 located with the mixed refrigerant propane cooler 30 on the integrated refrigeration and liquefaction module 406.

Figures 6-8 illustrate additional aspects of the invention that illustrate various alternative arrangements for integrated cooling and liquefaction modules. Figure 6 shows an integrated cooling and liquefaction module 606, in which the inlet gas propane coolers 614 are mounted on a separation module 607. This embodiment results in a lower number of connections required to be made at the moving site, compared to known arrangements, although such an embodiment may be less efficient than the arrangement shown in Figs. 4-5. FIG. 6 also illustrates how the main cryogenic heat exchanger 616 can be attached to the integrated cooling and liquefaction module 606. Such attachment can occur at the site of the operation or at a site remote from the site of operation. FIG. 7 illustrates additional components of the LNG train that may be included in the integrated cooling and liquefaction module 706. FIG. The scrub column 760 may be installed to remove heavy hydrocarbon components from the feed gas prior to liquefaction in the main cryogenic heat exchanger 716. The propane accumulator 762 may be configured to be used as a buffer reservoir for the condensed propane refrigerant. The propane subcooler heat exchanger 764, which may perform one or more of the functions represented by the cooler element 330, may also be installed on the integrated cooling and liquefaction module 706. Some or all of these additional components may be included in the integrated cooling and liquefaction module in any combination. Further, the arrangement of the components including these additional components on the integrated cooling and liquefaction module can be done to minimize the amount of piping between the components on the integrated cooling and liquefaction module, Is only an example of such an arrangement. 8 illustrates an integrated cooling and liquefaction module 806 in which the mixed refrigerant separator 840 is integral with or closely connected to the mixed refrigerant coolers 830. [ In one embodiment, the length of the piping connecting the mixed refrigerant cooler 830 and the mixed refrigerant separator 840 is less than 10 m. Incorporating or incorporating mixed refrigerant cooler 830 and mixed refrigerant separator 840 as described herein provides significant cost savings and reduction in LNG plant design as compared to known LNG plant designs, The two components are typically located in separate modules and even on both sides of the central pipe hanger.

An advantage of the disclosed aspects is a reduction in the number of connections required to be made at the operating site, a reduction in the overall number of processing modules, and the associated cost savings. Additional benefits are realized by the scheduling and logistics synergies associated with the reconfigured layout shown in FIGS. 4-8, and the opportunity to perform more pre-commissioning of cooling and liquefaction process systems at the manufacturing site rather than at the operational site.

FIG. 9 illustrates a method 900 for processing natural gas to produce liquefied natural gas (LNG) using an integrated cooling and liquefaction module according to the disclosed aspects. In step 902, natural gas is cooled in a first array of one or more heat exchangers using a first refrigerant from a first refrigerant circuit, wherein the first refrigerant is compressed in a first compressor. In step 904, the second refrigerant from the second refrigerant circuit is compressed in the second compressor. In step 906, the compressed second refrigerant is cooled and partially condensed using the first refrigerant in the second array of one or more heat exchangers located in the integrated refrigeration and liquefaction module. In step 908, the partially condensed second refrigerant is separated into a liquid phase and a vapor phase using a refrigerant separator located in an integrated cooling and liquefaction module. In step 910, the natural gas is liquefied in a third array of one or more heat exchangers using the vapor phase and liquid phase of the partially condensed second refrigerant to produce LNG.

The steps shown in Figure 9 are provided for illustrative purposes only, and the specific steps may not be required to perform the method of the present invention. Moreover, FIG. 9 does not show all the steps that can be performed. The claims, and only the claims, define the system and methodology of the present invention.

The disclosed embodiments can be used for hydrocarbon management activities. &Quot; Hydrocarbon management "or" managing hydrocarbons ", as used herein, is intended to include hydrocarbon extraction, hydrocarbon production, hydrocarbon exploration, potential hydrocarbon resource identification, well location, well oil injection and / or extraction rate determination, The placement and / or braking of hydrocarbon resources, previous hydrocarbon management decisions, and review of other hydrocarbon-related activities or activities. The term "hydrocarbon management" may also be used for sequestration of CO ₂ , such as injection or storage of hydrocarbons or CO ₂ , e.g., storage evaluation, development planning, and storage management. The disclosed methods and techniques may be used to extract hydrocarbons from areas below the surface of the water and / or to treat hydrocarbons. Hydrocarbons and contaminants can be extracted from the reservoir and treated. Hydrocarbons and contaminants can be treated in an LNG plant, for example, as described herein. Other hydrocarbon extraction activities, and more generally other hydrocarbon management activities, may be performed according to known principles.

It should be understood that numerous changes, modifications, and alternatives to the prior art may be made without departing from the scope of the present invention. Therefore, the above description is not meant to limit the scope of the invention. Rather, the scope of the present invention is determined only by the appended claims and their equivalents. It is also contemplated that the structures and features in these examples may be altered, rearranged, substituted, deleted, duplicated, combined, or added to one another.

Claims (33)

A method of treating natural gas producing liquefied natural gas (LNG) using an integrated cooling and liquefaction module,
(a) cooling the natural gas from a first refrigerant circuit in a first array of one or more heat exchangers using a first refrigerant compressed in a first compressor;
(b) compressing the second refrigerant from the second refrigerant circuit in the second compressor;
(c) cooling and partially condensing the compressed second refrigerant using a first refrigerant in a second array of one or more heat exchangers located in the integrated refrigeration and liquefaction module;
(d) separating the partially condensed second refrigerant into a liquid phase and a vapor phase using a refrigerant separator located in the integrated refrigeration and liquefaction module; And
(e) liquefying the natural gas to produce LNG in a third array of one or more heat exchangers using the vapor phase and liquid phase of the partially condensed second refrigerant. 2. The method of claim 1, wherein the first array of one or more heat exchangers is located in the integrated cooling and liquefaction module. A refrigerant separator according to any one of the preceding claims, wherein the refrigerant separator comprises at least one of the at least one heat exchanger and the at least one heat exchanger, wherein the length of the process piping connecting the inlet of the refrigerant separator and the outlet of the heat exchanger closest to the second array of the at least one heat exchanger is less than 10 m And a second array of one heat exchanger. 4. The method of claim 1, wherein the third array of at least one heat exchanger is located in the integrated cooling and liquefaction module. The method of any one of claims 1 to 4, further comprising coupling the third array of heat exchangers to the integrated cooling and liquefaction module at a moving site. 6. The method of claim 1, wherein the third array of at least one heat exchanger is installed in a separate module from the integrated cooling and liquefaction module and is connected to the integrated cooling and liquefaction module at an operating site. 7. The method of any one of claims 1 to 6, further comprising removing heavy hydrocarbon components from the natural gas using scrub columns installed in the integrated cooling and liquefaction module prior to step (e). 8. The method of any one of claims 1 to 7, further comprising the step of isentropically expanding the liquid stream of the partially condensed liquid refrigerant in the integrated cooling and liquefaction module. 9. The method according to any one of claims 1 to 8, further comprising the step of isentropically expanding the LNG in the integrated cooling and liquefaction module. 10. The integrated cooling and liquefaction module of claim 1 to 9, wherein components (a) provide end-flashing of LNG and / or (b) components for nitrogen rejection ≪ / RTI > 11. The method according to any one of the preceding claims, further comprising the step of, in the integrated cooling and liquefaction module, comprising an accumulator vessel providing a buffer liquid storage for the first refrigerant ≪ / RTI > 12. The method of any one of claims 1 to 11, wherein the subcooling heat exchanger providing subcooling of the first refrigerant is included in the integrated refrigeration and liquefaction module. 13. The process according to any one of claims 1 to 12, wherein the first refrigerant is propane and / or propylene and the second refrigerant is a mixed refrigerant comprising methane, ethane and / or ethylene and propane and / or propylene. 14. The method of any one of claims 1 to 13, further comprising positioning a fourth array of one or more heat exchangers in the integrated cooling and liquefaction module. 15. The method according to any one of claims 1 to 14, further comprising the step of disposing an array of piping on the integrated cooling and liquefaction module, the array of piping being connected to the LNG facility where the integrated cooling and liquefaction module is located And to connect the components on the integrated cooling and liquefaction module to the other modules. 16. The method according to any one of claims 1 to 15, further comprising the step of disposing an array of piping on the integrated cooling and liquefaction module, wherein the array of piping is connected to the LNG facility where the integrated cooling and liquefaction module is located And to connect the components on the first additional module to the second additional module in the LNG facility. As a hydrocarbon processing plant,
A first refrigerant circuit;
A first refrigerant configured to circulate in the first refrigerant circuit;
A first compressor configured to compress the first refrigerant;
A first array of one or more heat exchangers configured to cool the hydrocarbon stream using the first refrigerant;
A second refrigerant circuit;
A second refrigerant configured to circulate in the second refrigerant circuit;
A second compressor configured to compress the second refrigerant;
A second array of one or more heat exchangers configured to cool and partially condense the compressed second refrigerant using the first refrigerant;
A refrigerant separator configured to separate the partially condensed second refrigerant into a liquid phase and a vapor phase;
A third array of one or more heat exchangers configured to liquefy the hydrocarbon stream using the vapor phase and liquid phase of the partially condensed second refrigerant; And
A second array of said at least one heat exchanger, and an integrated cooling and liquefaction module in which said refrigerant separator is located. 18. The hydrocarbon processing plant of claim 17, wherein the hydrocarbon stream is natural gas and the liquefied hydrocarbon stream is liquefied natural gas (LNG). 19. The hydrocarbon processing plant as claimed in claim 17 or 18, wherein the first array of the at least one heat exchanger is located in the integrated cooling and liquefaction module. 20. The system of claim 17, further comprising process piping connecting the refrigerant separator to a second array of at least one heat exchanger, wherein the inlet of the refrigerant separator and the second array of at least one heat exchanger Wherein the process piping connecting the outlet of the nearest heat exchanger is less than 10 m long. 21. A hydrocarbon processing plant according to any one of claims 17 to 20, wherein the third array of the at least one heat exchanger is located in the integrated cooling and liquefaction module. 22. A hydrocarbon processing plant as claimed in any one of claims 17 to 21, wherein the third array of heat exchangers is connected to the integrated cooling and liquefaction module at a moving site. 23. A hydrocarbon processing plant according to any one of claims 17 to 22, further comprising a second module in which a third array of the at least one heat exchanger is installed, and a second module separate from the integrated cooling and liquefaction module. 24. The hydrocarbon processing plant of claims 17 to 23, further comprising a scrub column located in said integrated cooling and liquefaction module, wherein said scrub column is configured to remove heavy hydrocarbon components from said hydrocarbon stream. 25. A method according to any one of claims 17 to 24, further comprising the steps of: introducing into the integrated refrigeration and liquefaction module a hydrocarbon comprising an isentropic expansion component configured to isentropically expand the liquid stream of the partially condensed liquid refrigerant, Processing plant. 26. A hydrocarbon processing plant according to any one of claims 17 to 25, further comprising an isentropic expansion component positioned in the integrated cooling and liquefaction module and configured to isentropically expand the liquefied hydrocarbon stream. 26. The method of claim 17, further comprising the steps of: (a) end-flashing LNG and / or (b) nitrogen rejection, Wherein the components are located in the integrated cooling and liquefaction module. 28. A method according to any one of claims 17 to 27, further comprising an accumulator vessel providing a buffer liquid storage for said first refrigerant, And a hydrocarbon processing plant located in the liquefaction module. 28. The hydrocarbon processing plant of claims 17 to 28, further comprising a sub-cooling heat exchanger configured to provide sub-cooling of the first refrigerant, wherein the sub-cooling heat exchanger is located in the integrated cooling and liquefaction module. 30. A hydrocarbon processing plant according to any one of claims 17 to 29, wherein the first refrigerant is propane and / or propylene and the second refrigerant is a mixed refrigerant comprising methane, ethane and / or ethylene and propane and / or propylene. 32. The hydrocarbon processing plant of Claims 17 to 30, further comprising the step of positioning a fourth array of one or more heat exchangers located in said integrated cooling and liquefaction module. 32. A method according to any one of claims 17 to 31, further comprising an array of piping arranged on the integrated cooling and liquefaction module, the array of piping being connected to a hydrocarbon treatment facility where the integrated cooling and liquefaction module is located And to connect the components on the integrated cooling and liquefaction module to the other modules. 33. A method according to any one of claims 17 to 32, further comprising an array of piping on the integrated cooling and liquefaction module, the array of piping comprising a first addition in the hydrocarbon processing facility where the integrated cooling and liquefaction module is located And connect components on the module to a second additional module in the hydrocarbon processing facility.

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