Patent Application
20230136307
The disclosure relates generally to liquefied natural gas (LNG) production. More specifically, the disclosure relates to LNG production at high pressures.
This section is intended to introduce various aspects of the art, which may be associated with the present disclosure. This discussion is intended to provide a framework to facilitate a better understanding of particular aspects of the present disclosure. Accordingly, it should be understood that this section should be read in this light, and not necessarily as an admission of prior art.
Because of its clean burning qualities and convenience, natural gas has become widely used in recent years. Many sources of natural gas are located in remote areas, which are great distances from any commercial markets for the gas. Sometimes a pipeline is available for transporting produced natural gas to a commercial market. When pipeline transportation is not feasible, produced natural gas is often processed into liquefied natural gas (LNG) for transport to market.
In the design of an LNG plant, one of the most important considerations is the process for converting the natural gas feed stream into LNG. Currently, the most common liquefaction processes use some form of refrigeration system. Although many refrigeration cycles have been used to liquefy natural gas, the three types most commonly used in LNG plants today are: (1) the “cascade cycle,” which uses multiple single component refrigerants in heat exchangers arranged progressively to reduce the temperature of the gas to a liquefaction temperature; (2) the “multi-component refrigeration cycle,” which uses a multi-component refrigerant in specially designed exchangers; and (3) the “expander cycle,” which expands gas from feed gas pressure to a low pressure with a corresponding reduction in temperature. Most natural gas liquefaction cycles use variations or combinations of these three basic types.
The refrigerants used in liquefaction processes may comprise a mixture of components such as methane, ethane, propane, butane, and nitrogen in multi-component refrigeration cycles. The refrigerants may also be pure substances such as propane, ethylene, or nitrogen in “cascade cycles.” Substantial volumes of these refrigerants with close control of composition are required. Further, such refrigerants may have to be imported and stored, which impose logistics requirements, especially for LNG production in remote locations. Alternatively, some of the components of the refrigerant may be prepared, typically by a distillation process integrated with the liquefaction process.
The use of gas expanders to provide the feed gas cooling, thereby eliminating or reducing the logistical problems of refrigerant handling, is seen in some instances as having advantages over refrigerant-based cooling. The expander system operates on the principle that the refrigerant gas can be allowed to expand through an expansion turbine, thereby performing work and reducing the temperature of the gas. The low temperature gas is then heat exchanged with the feed gas to provide the refrigeration needed. The power obtained from cooling expansions in gas expanders can be used to supply part of the main compression power used in the refrigeration cycle. The typical expander cycle for making LNG operates at the feed gas pressure, typically under about 6,895 kPa (1,000 psia). Supplemental cooling is typically needed to fully liquefy the feed gas and this may be provided by additional refrigerant systems, such as secondary cooling and/or sub-cooling loops. For example, U.S. Pat. Nos. 6,412,302 and 5,916,260 present expander cycles which describe the use of nitrogen as refrigerant in the sub-cooling loop.
Previously proposed expander cycles have all been less efficient thermodynamically, however, than the current natural gas liquefaction cycles based on refrigerant systems. Expander cycles have therefore not offered any installed cost advantage to date, and liquefaction cycles involving refrigerants are still the preferred option for natural gas liquefaction.
Because expander cycles result in a high recycle gas stream flow rate and high inefficiency for the primary cooling (warm) stage, gas expanders have typically been used to further cool feed gas after it has been pre-cooled to temperatures well below −20° C. using an external refrigerant in a closed cycle, for example. Thus, a common factor in most proposed expander cycles is the requirement for a second, external refrigeration cycle to pre-cool the gas before the gas enters the expander. Such a combined external refrigeration cycle and expander cycle is sometimes referred to as a “hybrid cycle.” While such refrigerant-based pre-cooling eliminates a major source of inefficiency in the use of expanders, it significantly reduces the benefits of the expander cycle, namely the elimination of external refrigerants.
U. S. Patent Application US2009/0217701 introduced the concept of using high pressure within the primary cooling loop to eliminate the need for external refrigerant and improve efficiency, at least comparable to that of refrigerant-based cycles currently in use. The high pressure expander process (HPXP), disclosed in U. S. Patent Application US2009/0217701, is an expander cycle which uses high pressure expanders in a manner distinguishing from other expander cycles. A portion of the feed gas stream may be extracted and used as the refrigerant in either an open loop or closed loop refrigeration cycle to cool the feed gas stream below its critical temperature. Alternatively, a portion of LNG boil-off gas may be extracted and used as the refrigerant in a closed loop refrigeration cycle to cool the feed gas stream below its critical temperature. This refrigeration cycle is referred to as the primary cooling loop. The primary cooling loop is followed by a sub-cooling loop which acts to further cool the feed gas. Within the primary cooling loop, the refrigerant is compressed to a pressure greater than 1,500 psia, or more preferably, to a pressure of approximately 3,000 psia. The refrigerant is then cooled against an ambient cooling medium (air or water) prior to being near isentropically expanded to provide the cold refrigerant needed to liquefy the feed gas.
In the expander loop 102, a compression unit 108 compresses a refrigerant stream 109 (which may be a treated gas stream) to a pressure greater than or equal to about 1,500 psia, thus providing a compressed refrigerant stream 110. Alternatively, the refrigerant stream 109 may be compressed to a pressure greater than or equal to about 1,600 psia, or greater than or equal to about 1,700 psia, or greater than or equal to about 1,800 psia, or greater than or equal to about 1,900 psia, or greater than or equal to about 2,000 psia, or greater than or equal to about 2,500 psia, or greater than or equal to about 3,000 psia, thus providing compressed refrigerant stream 110. After exiting compression unit 108, compressed refrigerant stream 110 is passed to a cooler 112 where it is cooled by indirect heat exchange with a suitable cooling fluid to provide a compressed, cooled refrigerant stream 114. Cooler 112 may be of the type that provides water or air as the cooling fluid, although any type of cooler can be used. The temperature of the compressed, cooled refrigerant stream 114 depends on the ambient conditions and the cooling medium used, and is typically from about 35° F. to about 105° F. Compressed, cooled refrigerant stream 114 is then passed to an expander 116 where it is expanded and consequently cooled to form an expanded refrigerant stream 118. Expander 116 is a work-expansion device, such as a gas expander, which produces work that may be extracted and used for compression. Expanded refrigerant stream 118 is passed to a first heat exchanger 120, and provides at least part of the refrigeration duty for first heat exchanger 120. Upon exiting first heat exchanger 120, expanded refrigerant stream 118 is fed to a compression unit 122 for pressurization to form refrigerant stream 109.
Feed gas stream 106 flows through first heat exchanger 120 where it is cooled, at least in part, by indirect heat exchange with expanded refrigerant stream 118. After exiting first heat exchanger 120, the feed gas stream 106 is passed to a second heat exchanger 124. The principal function of second heat exchanger 124 is to sub-cool the feed gas stream. Thus, in second heat exchanger 124 the feed gas stream 106 is sub-cooled by sub-cooling loop 104 (described below) to produce sub-cooled stream 126. Sub-cooled stream 126 is then expanded to a lower pressure in expander 128 to form a liquid fraction and a remaining vapor fraction. Expander 128 may be any pressure reducing device, including, but not limited to a valve, control valve, Joule Thompson valve, Venturi device, liquid expander, hydraulic turbine, and the like. The sub-cooled stream 126, which is now at a lower pressure and partially liquefied, is passed to a surge tank 130 where the liquefied fraction 132 is withdrawn from the process as an LNG stream 134, which has a temperature corresponding to the bubble point pressure. The remaining vapor fraction (flash vapor) stream 136 may be used as fuel to power the compressor units.
In sub-cooling loop 104, an expanded sub-cooling refrigerant stream 138 (preferably comprising nitrogen) is discharged from an expander 140 and drawn through second and first heat exchangers 124, 120. Expanded sub-cooling refrigerant stream 138 is then sent to a compression unit 142 where it is re-compressed to a higher pressure and warmed. After exiting compression unit 142, the re-compressed sub-cooling refrigerant stream 144 is cooled in a cooler 146, which can be of the same type as cooler 112, although any type of cooler may be used. After cooling, the re-compressed sub-cooling refrigerant stream is passed to first heat exchanger 120 where it is further cooled by indirect heat exchange with expanded refrigerant stream 118 and expanded sub-cooling refrigerant stream 138. After exiting first heat exchanger 120, the re-compressed and cooled sub-cooling refrigerant stream is expanded through expander 140 to provide a cooled stream which is then passed through second heat exchanger 124 to sub-cool the portion of the feed gas stream to be finally expanded to produce LNG.
U. S. Patent Application US2010/0107684 disclosed an improvement to the performance of the HPXP through the discovery that adding external cooling to further cool the compressed refrigerant to temperatures below ambient conditions provides significant advantages which in certain situations justifies the added equipment associated with external cooling. The HPXP embodiments described in the aforementioned patent applications perform comparably to alternative mixed external refrigerant LNG production processes such as single mixed refrigerant processes. However, there remains a need to further improve the efficiency of the HPXP as well as overall train capacity. There remains a particular need to improve the efficiency of the HPXP in cases where the feed gas pressure is less than 1,200 psia.
U. S. Patent Application 2010/0186445 disclosed the incorporation of feed compression up to 4,500 psia to the HPXP. Compressing the feed gas prior to liquefying the gas in the HPXP's primary cooling loop has the advantage of increasing the overall process efficiency. For a given production rate, this also has the advantage of significantly reducing the required flow rate of the refrigerant within the primary cooling loop which enables the use of compact equipment, which is particularly attractive for floating LNG applications. Furthermore, feed compression provides a means of increasing the LNG production of an HPXP train by more than 30% for a fixed amount of power going to the primary cooling and sub-cooling loops. This flexibility in production rate is again particularly attractive for floating LNG applications where there are more restrictions than land based applications in matching the choice of refrigerant loop drivers with desired production rates.
For LNG production via an HPXP process, the refrigerant used in primary cooling loop needs to be built up during start-up procedures, and must also be made up during normal operation. In known processes, the primary cooling loop refrigerant make-up source may be feed gas or boil-off gas (BOG) from an LNG storage tank. However, the compositions of feed gas and/or BOG gas compositions could change with reservoir conditions and/or gas plant operation conditions. The changes in gaseous refrigerant composition could affect liquefaction performance, causing the process to deviate from optimum operating conditions. If using feed gas for start-up or make-up processes, the primary cooling loop refrigerant should have sufficiently low C2+ content to stay at one phase before entering the suction sides of compressors and turboexpander compressors. Furthermore, liquid pooling in the primary loop passages of the main cryogenic heat exchanger could also cause gas mal-distribution, which is undesirable for efficient operation of the main cryogenic heat exchanger. Using BOG as for start-up and make-up processes, on the other hand, could avoid the issues related to heavy components breakthrough. However, BOG is generally has much higher N2 content than feed gas. Generally, too high of a nitrogen concentration negatively impacts the effectiveness of the primary loop refrigerant. In addition, the BOG composition is very sensitive to variations in composition of light ends such as nitrogen, hydrogen, helium in the feed gas. As shown in Table 1, an increase in the nitrogen concentration by 0.2% in the feed gas would result in an increase in BOG nitrogen concentration by 2%. For these reasons, there remains a need to manage variations in the feed gas composition during normal operation—both for the light contents (i.e., nitrogen, hydrogen, helium, etc.) and the heavy contents (i.e., C2+). There is also a need to provide for efficient start-up operations of a high-pressure LNG liquefaction process.
According to disclosed aspects, a method is provided for liquefying a feed gas stream rich in methane. According to the method, The feed gas stream is provided at a pressure less than 1,200 psia. A compressed refrigerant stream with a pressure greater than or equal to 1,500 psia is provided. The compressed refrigerant stream is cooled by indirect heat exchange with an ambient temperature air or water, to produce a compressed, cooled refrigerant stream. The compressed, cooled refrigerant stream is expanded in at least one work producing expander, thereby producing an expanded, cooled refrigerant stream. Part or all of the expanded, cooled refrigerant stream is mixed with a make-up refrigerant stream in a separator, thereby condensing heavy hydrocarbon components from the make-up refrigerant stream and forming a gaseous expanded, cooled refrigerant stream. The gaseous expanded, cooled refrigerant stream is passed through a heat exchanger zone to form a warm refrigerant stream. The feed gas stream is passed through the heat exchanger zone to cool at least part of the feed gas stream by indirect heat exchange with the expanded, cooled refrigerant stream, thereby forming a liquefied gas stream. The warm refrigerant stream is compressed to produce the compressed refrigerant stream.
According to another aspect of the disclosure, a method is provided for liquefying a feed gas stream rich in methane in a system having a first heat exchanger zone and a second heat exchanger zone. A compressed refrigerant stream with a pressure greater than or equal to 1,500 psia is provided. The compressed refrigerant stream is cooled by indirect heat exchange with an ambient temperature air or water to produce a compressed, cooled refrigerant stream. The compressed, cooled refrigerant stream is directed to the second heat exchanger zone to additionally cool the compressed, cooled refrigerant stream below ambient temperature to produce a compressed, additionally cooled refrigerant stream. The compressed, additionally cooled refrigerant stream is expanded in at least one work producing expander, thereby producing an expanded, cooled refrigerant stream. Part or all of the expanded, cooled refrigerant stream is routed to at least one separator, such as a separation vessel. The expanded, cooled refrigerant stream is mixed with a make-up refrigerant gas stream, to thereby condition the make-up refrigerant gas stream by condensing heavy hydrocarbon components therefrom and producing a gaseous overhead refrigerant stream. The gaseous overhead refrigerant stream is combined with the remaining expanded, cooled refrigerant stream to form a cold primary refrigerant mixture. The cold primary refrigerant mixture is passed through the first heat exchanger zone to form a warm refrigerant stream. The warm refrigerant stream may have a temperature that is cooler by at least 5° F. of the highest fluid temperature within the first heat exchanger zone. The heat exchanger type of the first heat exchanger zone is different from the heat exchanger type of the second heat exchanger zone. The feed gas stream is passed through the first heat exchanger zone to cool at least part of the feed gas stream by indirect heat exchange with the cold primary refrigerant mixture, thereby forming a liquefied gas stream. The warm refrigerant stream is compressed to produce the compressed refrigerant stream.
According to still other aspects of the disclosure, a method is disclosed for liquefying a feed gas stream rich in methane. According to the method, the feed gas stream is provided at a pressure less than 1,200 psia. The feed gas stream is compressed to a pressure of at least 1,500 psia to form a compressed gas stream. The compressed gas stream is cooled by indirect heat exchange with an ambient temperature air or water to form a compressed, cooled gas stream. The compressed, cooled gas stream is expanded in at least one work producing expander to a pressure that is less than 2,000 psia and no greater than the pressure to which the gas stream was compressed, to thereby form a chilled gas stream. A compressed refrigerant stream with a pressure greater than or equal to 1,500 psia is provided. The compressed refrigerant stream is cooled by indirect heat exchange with an ambient temperature air or water to produce a compressed, cooled refrigerant stream. The compressed, cooled refrigerant stream is expanded in at least one work producing expander, thereby producing an expanded, cooled refrigerant stream. Part or all of the expanded, cooled refrigerant stream is routed to at least one separator, such as a separation vessel, and mixing said expanded, cooled refrigerant stream therein with a make-up refrigerant gas stream, to thereby condition the make-up refrigerant gas stream by condensing heavy hydrocarbon components therefrom and producing a gaseous overhead refrigerant stream. The gaseous overhead refrigerant stream is combined with the remaining expanded, cooled refrigerant to form a cold primary refrigerant mixture. The cold primary refrigerant mixture is passed through a heat exchanger zone to form a warm refrigerant stream. The chilled gas stream is passed through the heat exchanger zone to cool at least part of the chilled gas stream by indirect heat exchange with the cold primary refrigerant mixture, thereby forming a liquefied gas stream. The warm refrigerant stream is compressed to produce the compressed refrigerant stream.
The foregoing has broadly outlined the features of the present disclosure so that the detailed description that follows may be better understood. Additional features will also be described herein.
These and other features, aspects and advantages of the disclosure will become apparent from the following description, appending claims and the accompanying drawings, which are briefly described below.
It should be noted that the figures are merely examples and no limitations on the scope of the present disclosure are intended thereby. Further, the figures are generally not drawn to scale, but are drafted for purposes of convenience and clarity in illustrating various aspects of the disclosure.
To promote an understanding of the principles of the disclosure, reference will now be made to the features illustrated in the drawings and specific language will be used to describe the same. It will nevertheless be understood that no limitation of the scope of the disclosure is thereby intended. Any alterations and further modifications, and any further applications of the principles of the disclosure as described herein are contemplated as would normally occur to one skilled in the art to which the disclosure relates. For the sake of clarity, some features not relevant to the present disclosure may not be shown in the drawings.
At the outset, for ease of reference, certain terms used in this application and their meanings as used in this context are set forth. To the extent a term used herein is not defined below, it should be given the broadest definition persons in the pertinent art have given that term as reflected in at least one printed publication or issued patent. Further, the present techniques are not limited by the usage of the terms shown below, as all equivalents, synonyms, new developments, and terms or techniques that serve the same or a similar purpose are considered to be within the scope of the present claims.
As one of ordinary skill would appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name only. The figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. When referring to the figures described herein, the same reference numerals may be referenced in multiple figures for the sake of simplicity. In the following description and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus, should be interpreted to mean “including, but not limited to.”
The articles “the,” “a” and “an” are not necessarily limited to mean only one, but rather are inclusive and open ended so as to include, optionally, multiple such elements.
As used herein, the terms “approximately,” “about,” “substantially,” and similar terms are intended to have a broad meaning in harmony with the common and accepted usage by those of ordinary skill in the art to which the subject matter of this disclosure pertains. It should be understood by those of skill in the art who review this disclosure that these terms are intended to allow a description of certain features described and claimed without restricting the scope of these features to the precise numeral ranges provided. Accordingly, these terms should be interpreted as indicating that insubstantial or inconsequential modifications or alterations of the subject matter described and are considered to be within the scope of the disclosure. The term “near” is intended to mean within 2%, or within 5%, or within 10%, of a number or amount.
As used herein, the term “ambient” refers to the atmospheric or aquatic environment where an apparatus is disposed. The term “at” or “near” “ambient temperature” as used herein refers to the temperature of the environment in which any physical or chemical event occurs plus or minus ten degrees, alternatively, five degrees, alternatively, three degrees, alternatively two degrees, and alternatively, one degree, unless otherwise specified. A typical range of ambient temperatures is between about 0° C. (32° F.) and about 40° C. (104° F.), though ambient temperatures could include temperatures that are higher or lower than this range. While it is possible in some specialized applications to prepare an environment with particular characteristics, such as within a building or other structure that has a controlled temperature and/or humidity, such an environment is considered to be “ambient” only where it is substantially larger than the volume of heat-sink material and substantially unaffected by operation of the apparatus. It is noted that this definition of an “ambient” environment does not require a static environment. Indeed, conditions of the environment may change as a result of numerous factors other than operation of the thermodynamic engine—the temperature, humidity, and other conditions may change as a result of regular diurnal cycles, as a result of changes in local weather patterns, and the like.
As used herein, the term “compression unit” means any one type or combination of similar or different types of compression equipment, and may include auxiliary equipment, known in the art for compressing a substance or mixture of substances. A “compression unit” may utilize one or more compression stages. Illustrative compressors may include, but are not limited to, positive displacement types, such as reciprocating and rotary compressors for example, and dynamic types, such as centrifugal and axial flow compressors, for example.
“Exemplary” is used exclusively herein to mean “serving as an example, instance, or illustration.” Any embodiment or aspect described herein as “exemplary” is not to be construed as preferred or advantageous over other embodiments.
The term “gas” is used interchangeably with “vapor,” and is defined as a substance or mixture of substances in the gaseous state as distinguished from the liquid or solid state. Likewise, the term “liquid” means a substance or mixture of substances in the liquid state as distinguished from the gas or solid state.
As used herein, “heat exchange area” means any one type or combination of similar or different types of equipment known in the art for facilitating heat transfer. Thus, a “heat exchange area” may be contained within a single piece of equipment, or it may comprise areas contained in a plurality of equipment pieces. Conversely, multiple heat exchange areas may be contained in a single piece of equipment.
A “hydrocarbon” is an organic compound that primarily includes the elements hydrogen and carbon, although nitrogen, sulfur, oxygen, metals, or any number of other elements can be present in small amounts. As used herein, hydrocarbons generally refer to components found in natural gas, oil, or chemical processing facilities.
As used herein, the terms “loop” and “cycle” are used interchangeably.
As used herein, “natural gas” means a gaseous feedstock suitable for manufacturing LNG, where the feedstock is a methane-rich gas. A “methane-rich gas” is a gas containing methane (CO as a major component, i.e., having a composition of at least 50% methane by weight. Natural gas may include gas obtained from a crude oil well (associated gas) or from a gas well (non-associated gas).
The disclosed aspects provide a method for liquefying a feed gas stream, particularly one rich in methane. The method comprises: (a) providing the gas stream at a pressure less than 1,200 psia; (b) providing a compressed refrigerant with a pressure greater than or equal to 1,500 psia; (c) cooling the compressed refrigerant by indirect heat exchange with an ambient temperature air or water to produce a compressed, cooled refrigerant; (d) expanding the compressed, cooled refrigerant in at least one work producing expander thereby producing an expanded, cooled refrigerant; (e) routing part or all of the expanded, cooled refrigerant to at least one separator, such as a separation vessel, and mixing said expanded, cooled refrigerant with a make-up refrigerant gas stream, to thereby condition the make-up refrigerant gas stream by condensing excessive heavy hydrocarbon components therefrom and producing a gaseous overhead refrigerant stream; (f) combining the gaseous overhead refrigerant stream with the remaining expanded, cooled refrigerant to form a cold primary refrigerant mixture; (g) passing the cold primary refrigerant mixture through a heat exchanger zone to form a warm refrigerant; (h) passing the gas stream through the heat exchanger zone to cool at least part of the gas stream by indirect heat exchange with the cold primary refrigerant mixture, thereby forming a liquefied gas stream; and (i) compressing the warm refrigerant to produce the compressed refrigerant.
In another aspect, a method is provided for liquefying a feed gas stream, comprising: (a) providing the feed gas stream at a pressure less than 1,200 psia; (b) compressing the feed gas stream to a pressure of at least 1,500 psia to form a compressed gas stream; (c) cooling the compressed gas stream by indirect heat exchange with an ambient temperature air or water to form a compressed, cooled gas stream; (d) expanding the compressed, cooled gas stream in at least one work producing expander to a pressure that is less than 2,000 psia and no greater than the pressure to which the gas stream was compressed, to thereby form a chilled gas stream; (e) providing a compressed refrigerant stream with a pressure greater than or equal to 1,500 psia; (f) cooling the compressed refrigerant stream by indirect heat exchange with an ambient temperature air or water to produce a compressed, cooled refrigerant stream; (g) expanding the compressed, cooled refrigerant stream in at least one work producing expander, thereby producing an expanded, cooled refrigerant stream; (h) routing part or all of the expanded, cooled refrigerant stream to at least one separator, such as a separation vessel, and mixing said expanded, cooled refrigerant stream with a make-up refrigerant gas stream, to thereby condition the make-up refrigerant gas stream by condensing excessive heavy hydrocarbon components therefrom and producing a gaseous overhead refrigerant stream; (i) combining the gaseous overhead refrigerant stream with the remaining expanded, cooled refrigerant to form a cold primary refrigerant mixture; (j) passing the cold primary refrigerant mixture through a heat exchanger zone to form a warm refrigerant stream; (k) passing the chilled gas stream through the heat exchanger zone to cool at least part of the chilled gas stream by indirect heat exchange with the cold primary refrigerant mixture, thereby forming a liquefied gas stream; and (l) compressing the warm refrigerant stream to produce the compressed refrigerant stream.
In another aspect, a method is provided for liquefying a feed gas stream in a system having a first heat exchanger zone and a second heat exchanger zone, comprising: (a) providing the feed gas stream at a pressure less than 1,200 psia; (b) compressing the gas stream to a pressure of at least 1,500 psia to form a compressed gas stream; (c) cooling the compressed gas stream by indirect heat exchange with an ambient temperature air or water to form a compressed, cooled gas stream; (d) expanding the compressed, cooled gas stream in at least one work producing expander to a pressure that is less than 2,000 psia and no greater than the pressure to which the gas stream was compressed, to thereby form a chilled gas stream; (e) providing a compressed refrigerant stream with a pressure greater than or equal to 1,500 psia; (f) cooling the compressed refrigerant stream by indirect heat exchange with an ambient temperature air or water to produce a compressed, cooled refrigerant stream; (g) directing the compressed, cooled refrigerant stream to the second heat exchanger zone to additionally cool the compressed, cooled refrigerant stream below ambient temperature to produce a compressed, additionally cooled refrigerant stream; (h) expanding the compressed, additionally cooled refrigerant stream in at least one work producing expander, thereby producing an expanded, cooled refrigerant stream; (i) routing part or all of the expanded, cooled refrigerant stream to at least one separator, such as a separation vessel, and mixing said expanded, cooled refrigerant stream with a make-up refrigerant gas stream, to thereby condition the make-up refrigerant gas stream by condensing excessive heavy hydrocarbon components therefrom and producing a gaseous overhead refrigerant stream; (j) combining the gaseous overhead refrigerant stream with the remaining expanded, cooled refrigerant stream to form a cold primary refrigerant mixture; (k) passing the cold primary refrigerant mixture through the first heat exchanger zone to form a warm refrigerant stream, whereby the warm refrigerant stream has a temperature that is cooler by at least 5° F. of the highest fluid temperature within the heat exchanger zone and whereby the heat exchanger type of the first heat exchanger zone is different from the heat exchanger type of the second heat exchanger zone; (l) passing the chilled gas stream through the first heat exchanger zone to cool at least part of the chilled gas stream by indirect heat exchange with the cold primary refrigerant mixture, thereby forming a liquefied gas stream; and (m) compressing the warm refrigerant stream to produce the compressed refrigerant stream.
In still another aspect of the disclosure, a method of liquefying a feed gas stream is provided, comprising: (a) providing the feed gas stream at a pressure less than 1,200 psia; (b) providing a refrigerant stream at or near the same pressure of the feed gas stream; (c) mixing the feed gas stream with the refrigerant stream to form a second feed gas stream; (d) compressing the second feed gas stream to a pressure of at least 1,500 psia to form a compressed second feed gas stream; (e) cooling the compressed feed second gas stream by indirect heat exchange with an ambient temperature air or water to form a compressed, cooled second feed gas stream; (f) directing the compressed, cooled second feed gas stream to a second heat exchanger zone to additionally cool the compressed, cooled second gas stream below ambient temperature to produce a compressed, additionally cooled second feed gas stream; (g) expanding the compressed, additionally cooled second feed gas stream in at least one work producing expander to a pressure that is less than 2,000 psia and no greater than the pressure to which the second feed gas stream was compressed, to thereby form an expanded, cooled second feed gas stream; (h) separating the expanded, cooled second feed gas stream into a first expanded refrigerant stream and a chilled gas stream; (i) expanding the first expanded refrigerant stream in at least one work producing expander, thereby producing a second expanded refrigerant stream; (j) routing part or all of the second expanded refrigerant stream to at least one separator, such as a separation vessel, and mixing the second expanded refrigerant stream with a make-up refrigerant gas stream, to thereby condition the make-up refrigerant gas stream by condensing excessive heavy hydrocarbon components therefrom and producing a gaseous overhead refrigerant stream; (k) combining the gaseous overhead refrigerant stream with the remaining second expanded refrigerant stream to form a cold primary refrigerant mixture; (l) passing the cold primary refrigerant mixture through a first heat exchanger zone to form a first warm refrigerant stream, whereby the first warm refrigerant stream has a temperature that is cooler by at least 5° F. than the highest fluid temperature within the first heat exchanger zone and whereby the heat exchanger type of the first heat exchanger zone is different from the heat exchanger type of the second heat exchanger zone; (m) passing the chilled gas stream through the first heat exchanger zone to cool at least part of the chilled gas stream by indirect heat exchange with the second expanded refrigerant, thereby forming a liquefied gas stream; (n) directing the first warm refrigerant to the second heat exchanger zone to cool by indirect heat exchange the compressed, cooled second gas, thereby forming a second warm refrigerant; and (o) compressing the second warm refrigerant to produce the refrigerant stream.
Aspects of the disclosure may compress the gas stream to a pressure no greater than 1,600 psia and then cooling the compressed gas stream by indirect heat exchange with an ambient temperature air or water prior to directing the gas stream to the first heat exchanger zone. Aspects of the disclosure may cool the gas stream to a temperature below the ambient by indirect heat exchange within an external cooling unit prior to directing the gas stream to the first heat exchanger zone. Aspects of the disclosure may cool the compressed, cooled refrigerant to a temperature below the ambient temperature by indirect heat exchange with an external cooling unit prior to directing the compressed, cooled refrigerant to the at least one work producing expander or the second heat exchanger zone. These described additional steps may be employed singularly or in combination with each other.
All or a portion of the expanded, cooled refrigerant stream 230 is directed to a separation vessel 232. A make-up gas stream 234 is also directed to the separation vessel 232 and mixes therein with the expanded, cooled refrigerant stream 230. The rate at which the make-up gas stream 234 is added to the separation vessel 232 will depend on the rate of loss of refrigerant due to such factors as leaks from equipment seals. The mixing conditions the make-up gas stream 234 by condensing heavy hydrocarbon components (e.g., C2+ compounds) contained in the make-up gas stream 234. The condensed components accumulate in the bottom of the separator and are periodically discharged as a separator bottom stream 236 to maintain a desired liquid level in the separation vessel 232. The conditioned make-up gas stream, minus the condensed heavy hydrocarbon components, exits the separation vessel as a gaseous overhead refrigerant stream 238. The gaseous overhead refrigerant stream 238 optionally mixes with a bypass stream 230a of the expanded, cooled refrigerant stream 230, forming the refrigerant stream 205.
The heat exchanger zone 201 may include a plurality of heat exchanger devices, and in the aspects shown in
In contrast with liquefaction system 200, all of the expanded, cooled refrigerant stream 330 is directed to a separation vessel 332. A make-up gas stream 334 is also directed to the separation vessel 332 and mixes therein with the expanded, cooled refrigerant stream 330. The rate at which the make-up gas stream 334 is added to the separation vessel 332 will depend on the rate of loss of refrigerant due to such factors as leaks from equipment seals. The mixing conditions the make-up gas stream 334 by condensing heavy hydrocarbon components (e.g., C2+ compounds) contained in the make-up gas stream 334. The condensed components accumulate in the bottom of the separator and are periodically discharged as a separator bottom stream 336 to maintain a desired liquid level in the separation vessel 332. The conditioned make-up gas stream, minus the condensed heavy hydrocarbon components, exits the separation vessel as a gaseous overhead refrigerant stream 338. The gaseous overhead refrigerant stream 338 forms the refrigerant stream 305.
The heat exchanger zone 301 may include a plurality of heat exchanger devices, and in the aspects shown in
The first warm refrigerant stream 405 has a temperature that is cooler by at least 5° F., or more preferably, cooler by at least 10° F., or more preferably, cooler by at least 15° F., than the highest fluid temperature within the first heat exchanger zone 401. The second warm refrigerant stream 409 may be compressed in one or more compressors 418, 420 to a pressure greater than 1,500 psia, or more preferably, to a pressure of approximately 3,000 psia, to thereby form a compressed refrigerant stream 422. The compressed refrigerant stream 422 is then cooled against an ambient cooling medium (air or water) in a cooler 424 to produce the compressed, cooled refrigerant stream 426 that is directed to the second heat exchanger zone 410 to form a compressed, additionally cooled refrigerant stream 429. The compressed, additionally cooled refrigerant stream 429 is near isentropically expanded in an expander 428 to produce the expanded, cooled refrigerant stream 430. All or a portion of the expanded, cooled refrigerant stream 430 is directed to a separation vessel 432 where it is mixed with a make-up gas stream 434 as previously described with respect to
Liquefaction system 500 stream includes the additional steps of compressing the feed gas stream 506 in a compressor 566 and then, using a cooler 568, cooling the compressed feed gas 567 with ambient air or water to produce a cooled, compressed feed gas stream 570. Feed gas compression may be used to improve the overall efficiency of the liquefaction process and increase LNG production.
The compressed, additionally cooled second gas stream 913 is expanded in at least one work producing expander 926 to a pressure that is less than 2,000 psia, but no greater than the pressure to which the second gas stream 906a was compressed, to thereby form an expanded, cooled second gas stream 980. The expanded, cooled second gas stream 980 is separated into a first expanded refrigerant stream 905 and a chilled feed gas stream 906b. The first expanded refrigerant stream 905 may be near isentropically expanded using an expander 982 to form a second expanded refrigerant stream 905a, which is directed to a separation vessel 932. A make-up gas stream 934 is also directed to the separation vessel 932 and mixes therein with the expanded, cooled refrigerant stream 930. The rate at which the make-up gas stream 934 is added to the separation vessel 932 will depend on the rate of loss of refrigerant due to such factors as leaks from equipment seals. The mixing conditions the make-up gas stream 934 by condensing heavy hydrocarbon components (e.g., C2+ compounds) contained in the make-up gas stream 934. The condensed components accumulate in the bottom of the separator and are periodically discharged as a separator bottom stream 936 to maintain a desired liquid level in the separation vessel 932. The conditioned make-up gas stream, minus the condensed heavy hydrocarbon components, exits the separation vessel as a gaseous overhead refrigerant stream 938, which is directed to the first heat exchanger zone 901. The chilled feed gas stream 906b is directed to the first heat exchanger zone 901 where a primary cooling refrigerant (i.e., the gaseous overhead refrigerant stream 938) and a sub-cooling refrigerant (from the sub-cooling loop 904) are used to liquefy and sub-cool the chilled feed gas stream 906b to produce a sub-cooled gas stream 948, which is processed as previously described to form LNG. The sub-cooling loop 904 may be a closed refrigeration loop, preferably charged with nitrogen as the sub-cooling refrigerant. After exchanging heat with the chilled feed gas stream 906b, the gaseous overhead refrigerant stream 938 forms the first warm refrigerant stream 908. The first warm refrigerant stream 908 may have a temperature that is cooler by at least 5° F., or more preferably, cooler by at least 10° F., or more preferably, cooler by at least 15° F., than the highest fluid temperature within the first heat exchanger zone 901. The second warm refrigerant stream 909 is compressed in one or more compressors 918 and then cooled with an ambient cooling medium in an external cooling device 924 to produce the refrigerant stream 907.
Aspects of the disclosure illustrated in
The steps depicted in
Aspects of the disclosure have several advantages over the known liquefaction processes, in which feed gas must be consistently sufficiently lean to be used as make-up gas in the primary refrigerant loop. BOG, which is rich in lighter components such as nitrogen, is required as a reliable make-up gas source. But using BOG as make-up gas negatively impacts the effectiveness of the primary loop refrigerant, either by demanding higher power consumption or requiring a larger main cryogenic heat exchanger. In addition, BOG composition is very sensitive to variation in the composition of light ends (e.g., nitrogen, hydrogen, helium) in the feed gas, thereby potentially adversely impacting process stability. The disclosed aspects enable the primary refrigerant make-up gas to comprise feed gas having a wide range of compositions, from lean to rich. Taking liquefaction system 300 as an example, the size of the main cryogenic heat exchanger can be reduced 10-16% and thermal efficiency can be improved up to about 1%, when compared to a similar system using BOG as the primary refrigerant make-up gas. Such size reductions of the main cryogenic heat exchanger, which typically is one of the largest and heaviest component or vessel in an LNG liquefaction system, may greatly reduce the size and cost of LNG liquefaction plants. Additionally, the disclosed aspects offer flexibility in tuning light (e.g., N2) and heavy (e.g., C2+) contents for the primary refrigerant loop that could potentially dynamically match incoming feed from gas wells, thereby optimizing energy use or production rate. For example, the make-up gas streams could be from feed gas, N2, and LPG product streams. Their relative rates could be tuned for optimization purposes illustrated above.
Aspects of the disclosure may include any combinations of the methods and systems shown in the following numbered paragraphs. This is not to be considered a complete listing of all possible aspects, as any number of variations can be envisioned from the description above.
1. A method for liquefying a feed gas stream rich in methane, comprising:
(a) providing the feed gas stream at a pressure less than 1,200 psia;
(b) providing a compressed refrigerant stream with a pressure greater than or equal to 1,500 psia;
(c) cooling the compressed refrigerant stream by indirect heat exchange with an ambient temperature air or water, to produce a compressed, cooled refrigerant stream;
(d) expanding the compressed, cooled refrigerant stream in at least one work producing expander, thereby producing an expanded, cooled refrigerant stream;
(e) mixing part or all of the expanded, cooled refrigerant stream with a make-up refrigerant stream in a separator, thereby condensing heavy hydrocarbon components from the make-up refrigerant stream and forming a gaseous expanded, cooled refrigerant stream;
(f) passing the gaseous expanded, cooled refrigerant stream through a heat exchanger zone to form a warm refrigerant stream;
(g) passing the feed gas stream through the heat exchanger zone to cool at least part of the feed gas stream by indirect heat exchange with the expanded, cooled refrigerant stream, thereby forming a liquefied gas stream; and
(i) compressing the warm refrigerant stream to produce the compressed refrigerant stream.
2. The method of paragraph 1, further comprising:
controlling a flow rate of the make-up gas stream into the separator to maintain at least one pressure at a suction side of a compressor at a target value.
3. The method of paragraph 1 or paragraph 2, further comprising:
collecting the condensed heavy hydrocarbon components in the separator; and
discharging the condensed heavy hydrocarbon components to maintain a desired liquid level in the separator.
4. The method of any one of paragraphs 1-3, further comprising:
further cooling the liquefied gas stream within the heat exchanger zone using a sub-cooling refrigeration cycle, to thereby form a sub-cooled gas stream.
5. The method of paragraph 4, further comprising:
expanding the sub-cooled gas stream to a pressure greater than or equal to 50 psia and less than or equal to 450 psia, to produce an expanded, sub-cooled gas stream.
6. The method of paragraph 5, wherein the sub-cooled gas stream is expanded within a hydraulic turbine.
7. The method of any one of paragraphs 4-6, wherein the sub-cooling refrigeration cycle comprises a closed loop gas phase refrigeration cycle using nitrogen gas as a refrigerant.
8. The method of any one of paragraphs 1-7, further comprising:
prior to directing the feed gas stream to the heat exchanger zone, compressing the feed gas stream to a pressure no greater 1,600 psia, and then cooling it by indirect heat exchange with an ambient temperature air or water.
9. The method of any one of paragraphs 1-8, wherein the feed gas stream is cooled to a temperature below an ambient temperature by indirect heat exchange within an external cooling unit prior to directing the feed gas stream to the heat exchanger zone.
10. The method of any one of paragraphs 1-9, wherein the compressed, cooled refrigerant stream is cooled to a temperature below the ambient temperature by indirect heat exchange within an external cooling unit prior to expanding the compressed, cooled refrigerant stream in the at least one work producing expander.
11. The method of any one of paragraphs 1-10, wherein the make-up gas stream comprises a portion of the feed gas stream, a boil-off gas obtained from the liquefied gas stream, or any combination thereof.
12. The method of any one of paragraphs 1-11, wherein the make-up gas stream comprises a mixture of methane with at least one component having a molecular weight heavier or lighter than methane.
13. The method of paragraph 12, wherein the make-up gas stream comprises methane and one or more of nitrogen and liquefied petroleum gas.
14. A method for liquefying a feed gas stream rich in methane in a system having a first heat exchanger zone and a second heat exchanger zone, comprising:
(a) providing a compressed refrigerant stream with a pressure greater than or equal to 1,500 psia;
(b) cooling the compressed refrigerant stream by indirect heat exchange with an ambient temperature air or water to produce a compressed, cooled refrigerant stream;
(c) directing the compressed, cooled refrigerant stream to the second heat exchanger zone to additionally cool the compressed, cooled refrigerant stream below ambient temperature to produce a compressed, additionally cooled refrigerant stream;
(d) expanding the compressed, additionally cooled refrigerant stream in at least one work producing expander, thereby producing an expanded, cooled refrigerant stream;
(e) routing part or all of the expanded, cooled refrigerant stream to at least one separator, such as a separation vessel, and mixing said expanded, cooled refrigerant stream with a make-up refrigerant gas stream, to thereby condition the make-up refrigerant gas stream by condensing heavy hydrocarbon components therefrom and producing a gaseous overhead refrigerant stream;
(f) combining the gaseous overhead refrigerant stream with the remaining expanded, cooled refrigerant stream to form a cold primary refrigerant mixture;
(g) passing the cold primary refrigerant mixture through the first heat exchanger zone to form a warm refrigerant stream, whereby the warm refrigerant stream has a temperature that is cooler by at least 5° F. of the highest fluid temperature within the heat exchanger zone, and wherein a heat exchanger type of the first heat exchanger zone is different from a heat exchanger type of the second heat exchanger zone;
(h) passing the feed gas stream through the first heat exchanger zone to cool at least part of the feed gas stream by indirect heat exchange with the cold primary refrigerant mixture, thereby forming a liquefied gas stream; and
(i) compressing the warm refrigerant stream to produce the compressed refrigerant stream.
15. The method of paragraph 14, further comprising:
controlling a flow rate of the make-up gas stream into the separator to maintain at least one pressure at a suction side of a compressor at a target value.
16. The method of paragraph 14 or paragraph 15, further comprising:
collecting the condensed heavy hydrocarbon components in the separator; and
discharging the condensed heavy hydrocarbon components to maintain a desired liquid level in the separator.
17. The method of any one of paragraphs 14-16, further comprising:
further cooling the liquefied gas stream within the first heat exchanger zone using a sub-cooling refrigeration cycle, to thereby form a sub-cooled gas stream.
18. The method of paragraph 17, further comprising:
expanding the sub-cooled gas stream to a pressure greater than or equal to 50 psia and less than or equal to 450 psia, to produce an expanded, sub-cooled gas stream.
19. The method of paragraph 18, wherein the sub-cooled gas stream is expanded within a hydraulic turbine.
20. The method of any one of paragraphs 17-19, wherein the sub-cooling refrigeration cycle comprises a closed loop gas phase refrigeration cycle using nitrogen gas as a refrigerant.
21. The method of any one of paragraphs 14-20, further comprising:
prior to directing the feed gas stream to the heat exchanger zone, compressing the feed gas stream to a pressure no greater 1,600 psia, cooling the feed gas stream by indirect heat exchange with an ambient temperature air or water, and then expanding the feed gas stream in a work-producing expander.
22. The method of any one of paragraphs 14-21, wherein the feed gas stream is cooled to a temperature below an ambient temperature by indirect heat exchange within an external cooling unit prior to directing the feed gas stream to the heat exchanger zone.
23. The method of any one of paragraphs 14-22, wherein the compressed, cooled refrigerant stream is cooled to a temperature below the ambient temperature by indirect heat exchange within an external cooling unit prior to expanding the compressed, cooled refrigerant stream in the at least one work producing expander.
24. The method of any one of paragraphs 14-23, wherein the make-up gas stream comprises a portion of the feed gas stream, a boil-off gas obtained from the liquefied gas stream, or any combination thereof.
25. The method of any one of paragraphs 14-24, wherein the make-up gas stream comprises a mixture of methane with at least one component having a molecular weight heavier or lighter than methane.
26. The method of paragraph 25, wherein the make-up gas stream comprises methane and one or more of nitrogen and liquefied petroleum gas.
27. A method for liquefying a feed gas stream rich in methane, comprising:
(a) providing the feed gas stream at a pressure less than 1,200 psia;
(b) compressing the feed gas stream to a pressure of at least 1,500 psia to form a compressed gas stream;
(c) cooling the compressed gas stream by indirect heat exchange with an ambient temperature air or water to form a compressed, cooled gas stream;
(d) expanding the compressed, cooled gas stream in at least one work producing expander to a pressure that is less than 2,000 psia and no greater than the pressure to which the gas stream was compressed, to thereby form a chilled gas stream;
(e) providing a compressed refrigerant stream with a pressure greater than or equal to 1,500 psia;
(f) cooling the compressed refrigerant stream by indirect heat exchange with an ambient temperature air or water to produce a compressed, cooled refrigerant stream;
(g) expanding the compressed, cooled refrigerant stream in at least one work producing expander, thereby producing an expanded, cooled refrigerant stream;
(h) routing part or all of the expanded, cooled refrigerant stream to at least one separator, and mixing said expanded, cooled refrigerant stream therein with a make-up refrigerant gas stream, to thereby condition the make-up refrigerant gas stream by condensing heavy hydrocarbon components therefrom and producing a gaseous overhead refrigerant stream;
(i) combining the gaseous overhead refrigerant stream with the remaining expanded, cooled refrigerant to form a cold primary refrigerant mixture;
(j) passing the cold primary refrigerant mixture through a heat exchanger zone to form a warm refrigerant stream;
(k) passing the chilled gas stream through the heat exchanger zone to cool at least part of the chilled gas stream by indirect heat exchange with the cold primary refrigerant mixture, thereby forming a liquefied gas stream; and
(l) compressing the warm refrigerant stream to produce the compressed refrigerant stream.
28. The method of paragraph 27, further comprising:
controlling a flow rate of the make-up gas stream into the separator to maintain at least one pressure at a suction side of a compressor at a target value.
29. The method of paragraph 27 or paragraph 28, further comprising:
collecting the condensed heavy hydrocarbon components in the separator; and
discharging the condensed heavy hydrocarbon components to maintain a desired liquid level in the separator.
30. The method of any one of paragraphs 27-29, further comprising:
further cooling the liquefied gas stream within the first heat exchanger zone using a sub-cooling refrigeration cycle, to thereby form a sub-cooled gas stream.
31. The method of paragraph 30, further comprising:
expanding the sub-cooled gas stream to a pressure greater than or equal to 50 psia and less than or equal to 450 psia, to produce an expanded, sub-cooled gas stream.
32. The method of paragraph 31, wherein the sub-cooled gas stream is expanded within a hydraulic turbine.
33. The method of any one of paragraphs 30-32, wherein the sub-cooling refrigeration cycle comprises a closed loop gas phase refrigeration cycle using nitrogen gas as a refrigerant.
34. The method of any one of paragraphs 27-33, wherein the compressed, cooled refrigerant stream is cooled to a temperature below the ambient temperature by indirect heat exchange within an external cooling unit prior to expanding the compressed, cooled refrigerant stream in the at least one work producing expander.
35. The method of any one of paragraphs 27-34, wherein the make-up gas stream comprises a portion of the feed gas stream, a boil-off gas obtained from the liquefied gas stream, or any combination thereof.
36. The method of any one of paragraphs 27-35, wherein the make-up gas stream comprises a mixture of methane with at least one component having a molecular weight heavier or lighter than methane.
37. The method of paragraph 36, wherein the make-up gas stream comprises methane and one or more of nitrogen and liquefied petroleum gas.
It should be understood that the numerous changes, modifications, and alternatives to the preceding disclosure can be made without departing from the scope of the disclosure. The preceding description, therefore, is not meant to limit the scope of the disclosure. Rather, the scope of the disclosure is to be determined only by the appended claims and their equivalents. It is also contemplated that structures and features in the present examples can be altered, rearranged, substituted, deleted, duplicated, combined, or added to each other.
This application claims the priority benefit of U.S. Provisional Application No. 62/721,367, “Managing Make-Up Gas Composition Variation for a High Pressure Expander Process,” filed Aug. 22, 2018; U.S. Provisional Application No. 62/565,725, “Natural Gas Liquefaction by a High Pressure Expansion Process”, filed Sep. 29, 2017; U.S. Provisional Application No. 62/565,733, “Natural Gas Liquefaction by a High Pressure Expansion Process,” filed Sep. 29, 2017; and U.S. Provisional Application No. 62/576,989, “Natural Gas Liquefaction by a High Pressure Expansion Process Using Multiple Turboexpander Compressors”, filed Oct. 25, 2017, the disclosures of which are incorporated by reference herein in their entireties for all purposes. This application is related to U.S. Provisional Application No. 62/721,375, “Primary Loop Start-up Method for a High Pressure Expander Process”; and U.S. Provisional Application No. 62/721,374, “Heat Exchanger Configuration for a High Pressure Expander Process and a Method of Natural Gas Liquefaction Using the Same,” having common ownership and filed on an even date, the disclosures of which are incorporated by reference herein in their entireties for all purposes.
| Number | Date | Country | |
|---|---|---|---|
| 62721367 | Aug 2018 | US |
| Number | Date | Country | |
|---|---|---|---|
| Parent | 16526441 | Jul 2019 | US |
| Child | 18066369 | US |
