1. Technical Field of the Invention
The present invention relates to the recovery of natural gas liquids, such as propane and ethane, from liquefied natural gas (LNG) streams by means of cold utilization.
2. Description of Prior Art
The supply of LNG varies considerably in composition, depending upon the source of the stream. This composition variation is particularly noticeable in the receiving terminals in the U.S. As a result of this variation, once the LNG is processed, the heating value of the revaporized LNG, or residue gas, from such processes also varies significantly. At times, the residue gas stream produced is lean without significant amounts of relatively heavier compounds, such as ethane and similar compounds. Other times, the residue gas stream can be too high in heating value for residue gas pipelines. Pipelines have specifications that have a maximum allowable heating value, or BTU content, for residue gas streams. If the heating value exceeds the maximum allowable heating value, components contributing to the high BTU content have to be removed or the pipeline operator can reject the residue gas.
Many processes have been developed to separate liquefied natural gas into a methane-rich overhead stream and a bottoms stream containing components such as C2 and heavier hydrocarbons. Examples can be found in U.S. Pat. No. 3,837,172 issued to Markbreiter (“the Markbreiter patent”), U.S. Pat. No. 5,114,451 issued to Rambo (“the Rambo patent”), and U.S. Pat. No. 6,510,706 issued to Stone et al. (“the Stone patent”).
The Markbreiter patent shows a process for separating liquefied natural gas in a fractionation column to yield a methane-enriched overhead stream and a bottoms stream that contains C2 and heavier hydrocarbons. Difficulties encountered with the process of Markbreiter include a lack of flexibility in the process to account for varying feed compositions. The Markbreiter process can result in an overhead stream, which is delivered as a vapor stream, with an unacceptably high amount of C2, which can result in rejection of the gas. Since the overhead stream is delivered in vapor form, it is necessary to compress the vapor to deliver it at the conditions of the pipeline.
The Rambo patent shows a process for separating liquefied natural gas in which a portion of a methane-enriched overhead stream from a fractionation column is re-fed to the column as reflux, while the remaining portion of the overhead stream is recovered as a vapor product stream. As with Markbreiter, additional compression steps are required to deliver the vapor at the conditions of the pipeline.
The Stone patent shows a process for removing ethane and heavier components as a liquid NGL product from a pressurized LNG stream. The Stone patent defines the pressurized LNG stream as being pressurized up to a pressure where its bubble point is equivalent to about −170° F. The Stone patent specifically describes the recovery of NGL from pressurized LNG (PLNG). A split is provided for the feed stream to provide cold reflux to the fractionation column. The cold reflux stream is pressurized so that its bubble point temperature is about −170° F., as opposed to conventional LNG processes having a bubble point about −260° F., which reduces separation efficiency within the fractionation column.
A need exists for a flexible process that will control or decrease the heating value of the residue gas produced from typical LNG processes. It would be advantageous to provide a process that will increase the amount of natural gas liquids that are recovered from LNG streams, while decreasing the heating value of the residue gas stream produced by revaporizing the lean LNG stream. It would also be advantageous to provide a process in which the product is delivered at similar conditions as the LNG feed to minimize the intervention in existing terminals and reduce the energy required to supply the gas at pipeline conditions.
The present invention advantageously provides a process and apparatus to control and decrease heating value of residue gas that is produced from natural gas liquids recovery processes. The process and apparatus additionally provides an increase in the amount of natural gas liquids that are recovered simultaneously with the reduction of the residue gas heating value.
An LNG feed stream received from the atmospheric cryogenic storage tanks is boosted to a pressure that will make re-liquefaction of the product possible later, and then heated in a first, or primary, exchanger in a heat exchanger train, preferably to the bubble point temperature of the feed stream. The feed stream is then split, with a first portion of the feed stream being sent to a tower as a first tower feed stream to a tower.
The tower is preferably a demethanizer or a deethanizer. More specifically the tower preferably is a reboiled absorber that preferably includes a bottom heat source. The bottom heat source can be a kettle reboiler, a thermosyphon reboiler, a plate-fin exchanger, an internal reboiler, a side-reboiler, and combinations thereof. An example plate-fin exchanger is a brazed aluminum exchanger. Other types of bottom heat sources will be known to those skilled in the art and are to be considered within the scope of the present invention.
A secondary portion of the feed stream is heated further in a secondary exchanger in a heat exchanger train and then sent as a second tower feed stream to the tower. A substantial difference in enthalpy content and in temperature exists between the first portion and the secondary portion of the feed stream once the second tower feed stream is heated. The differences in enthalpy content of the two split streams provide the unique ability to control the amount of separation achieved in the tower as the enthalpy difference provides a driving force for separation. It is preferable for the first feed stream to be fed to the tower at a higher location than the second feed stream. The first portion of the feed stream is fed to the top of the tower in this configuration. The tower produces an overhead stream and a natural gas liquids stream. The overhead stream is at least partially condensed by contact with the feed stream in the heat exchanger train to form a residue LNG stream. The natural gas liquids, such as C2+ compounds, that are recovered from the process are substantially contained within the natural gas liquids stream. The primary and secondary heaters can be part of one heat exchanger, such as an LNG heat exchanger.
As an alternate embodiment, the feed stream can be split prior to being heated. A first portion of the feed stream is sent directly to the tower as a first tower feed stream, while a secondary portion is heated and then sent to the tower as a second feed stream. It is preferable for the first tower feed stream to be fed to the tower at a higher location than the second tower feed stream. This alternate embodiment simplifies the heating requirements since only one heat exchanger with one heating path is required, but more than one can be used.
The result of both embodiments of the natural gas liquids recovery process is a decrease in the heating value of the residue gas LNG stream. The reduced heating value of the residue gas stream keeps the gas within the pipeline specifications. The recovery of natural gas liquids, such as C2+ compounds, provides a valuable source of revenue. Both embodiments are believed to be equally effective, with the second embodiment requiring less capital costs since less process equipment is needed.
In addition to the processes embodiments provided, the apparatus used to perform the process embodiments is also advantageously provided. The apparatus preferably includes a first pump, a first heat exchanger, a means for splitting the feed stream, optionally a second heat exchanger, a tower, and a second pump. The tower can be a deethanizer or a demethanizer depending upon the desired NGL products and composition of the feed stream. The second heat exchanger is not required in the second apparatus embodiment. A means for revaporizing the residue LNG stream can also be provided.
So that the manner in which the features, advantages and objects of the invention, as well as others that will become apparent, may be understood in more detail, more particular description of the invention briefly summarized above may be had by reference to the embodiment thereof that are illustrated in the appended drawings, which form a part of this specification. It is to be noted, however, that the drawings illustrate only a preferred embodiment of the invention and are therefore not to be considered limiting of the invention's scope as it may admit to other equally effective embodiments.
For simplification of the drawings, figure numbers are the same in
The term “natural gas liquid” refers to hydrocarbons found in natural gas that can be extracted or isolated as liquefied petroleum gas and natural gasoline. When natural gas is produced, it contains methane and other light hydrocarbons that are separated in a gas processing plant. The natural gas liquids components recovered during processing include C2+ compounds, such as ethane, propane, and butane, as well as heavier hydrocarbons. The products, known as natural gas liquids (NGL), can be used as fuel or raw materials in industrial production.
In this embodiment of the present invention, the heat exchanger train 19 preferably contains two exchangers, a first exchanger 20 and a second exchanger 24. The feed stream 18, which is subcooled, is heated to its bubble point temperature in first exchanger 20 by heat exchange contact with a cooled overhead stream 30. The higher feed stream 18 is split into a first portion and a secondary portion. The first portion is fed to a tower 28 as a first tower feed stream 22. The step of splitting feed stream 18 into a first and second tower feed stream 22, 26 includes first tower feed stream 22 being in a range of about 5% to about 50% of feed stream 18 and second tower feed stream 26 being in a range of about 50% to about 95% of feed stream 18. Overhead stream 30 preferably has a methane concentration in a range of about 85 wt. % to about 99 wt. %.
The secondary portion of feed stream 18 is further warmed in second exchanger 24 by heat exchange contact with overhead stream 30. Second tower feed stream 26 is heated or warmed so that there is a substantial difference in the enthalpy content of first tower feed stream 22 and second tower feed stream 26. The differences in enthalpy content of the two split streams provide the unique ability to control the amount of separation achieved in the tower as this enthalpy difference provides a driving force for separation. As can be seen in Table 1, the substantial difference in enthalpy content can be in a range of about 75 Btu/lb to about 150 Btu/lb. Additionally, a substantial difference in temperatures also exists between the two streams 22, 26. The temperature difference between the two streams is preferably in a range of about 25° F. to about 50° F. In all embodiments of this invention, first and second exchangers 20, 24 can be a single multi-path exchanger, a plurality of individual heat exchangers, or combinations thereof. The warmed feed stream exits the second exchanger 24 as a second tower feed stream 26. Second tower feed stream 26 is preferably sent to tower 28 below the first tower feed stream 22.
Tower 28 is preferably a reboiled absorber that uses a bottom heat source, such as a bottoms reboiler 34, to maintain specification of a residue gas stream. Other examples of suitable bottom heat sources include a kettle reboiler, a thermosyphon reboiler, a plate-fin exchanger, an internal reboiler, a side-reboiler, and combinations thereof. An example plate-fin exchanger is a brazed aluminum exchanger. Other types of bottom heat sources will be known to those skilled in the art and are to be considered within the scope of the present invention. A reboiled absorber typically contains a stripping section and an absorption section within the same tower. Bottoms reboiler 34 uses a heating medium stream to provide heat to tower 28. The heating medium can be steam or a heat transfer fluid. Other examples of heating medium will also be known to those skilled in the art and are to be considered within the scope of the present invention.
In tower 28, the rising vapors in a reboiler reflux stream are at least partially condensed by intimate contact with falling liquids from first and second tower feed streams 22, 26 thereby producing overhead stream 30. The condensed liquids descend down tower 28 and are removed as a natural gas liquids stream 29, which contains a majority of the natural gas liquids recovered from feed stream 10. Natural gas liquids stream 29 is sent to bottoms reboiler 34. A portion of natural gas liquids stream 29 is drawn from bottoms reboiler 34 as a natural gas liquids stream 32.
The net heating value of the process is optimized by increasing the recovery of natural gas liquids, while simultaneously decreasing the heating value of the residue gas stream, which is formed by revaporizing residue LNG stream 36. This configuration allows the degrees of separation to be controlled so tower 28 is flexible enough to handle various feed compositions of the LNG feed stream, while improving specifications of residue LNG stream 36. The control of the split of the two streams that are being fed as first and second feed streams to the tower provides a means to control the degree of separation. The differences in enthalpy content of the two split streams provide the unique ability to control the amount of separation achieved in the tower. A predetermined enthalpy difference drives the amount of separation achieved.
Overhead stream 30 is a lean residue gas stream that is sent to second exchanger 24 and is cooled by heat exchange contact with second tower feed stream 26 to produce a cooled tower overhead stream. The step of warming second tower feed stream 26 provides at least a portion of the cooling required for cooling tower overhead stream 30. Overhead stream 30 is further cooled in first exchanger 20 preferably by heat exchange contact with feed stream 18. The condensed liquid from the overhead stream 30 forms a residue LNG stream 36 that is sent, typically by pumping with main pumps 27, for revaporization to produce a residue gas stream. The residue gas stream produced from the residue LNG stream 36 has a reduced heating value in order to meet pipeline specifications for heating values of residue gas streams.
The apparatus to perform the process illustrated in
First pump 16 is used to supply and pump feed stream 10. First heat exchanger 20 warms feed stream 10 to produce a warm feed stream 18, while simultaneously cooling an overhead stream 30. The means for splitting warm feed stream 18 splits warm feed stream 18 into a first tower feed stream 22 and a second tower feed stream 26. Second heat exchanger 24 warms second tower feed stream 26, while simultaneously cooling tower bottoms tower stream 30. Tower 28 receives first tower feed stream 22 and second tower feed stream 26 and produces an overhead stream 30 and a bottoms tower stream 29. Tower 28 preferably includes a reboiled absorber, which preferably includes a bottoms reboiler 34.
Both embodiments of the present invention provide for the decrease in residue gas heating value and increase in the amount of the recovered natural gas liquids. This alternate embodiment 5′ has a simplified heat exchanger train 19′, as opposed to the heat exchanger train 19 shown in
As an advantage of this invention, the residue gas streams are able to remain below the heating value specification required in most pipelines. The heating value that is removed from the residue gas stream, which is produced from the residue LNG stream 36, is captured by the increase in the amount recovered of the natural gas liquids from the rich LNG feed stream 10. Since natural gas liquids streams contain valuable compounds, particularly when sales prices of the compounds are high, it is advantageous to recover more of these compounds from rich LNG streams.
While the invention has been shown or described in only some of its forms, it should be apparent to those skilled in the art that it is not so limited, but is susceptible to various changes without departing from the scope of the invention.
For example, various means of heat exchange can be used to supply the bottoms reboiler with heat. The reboiler can be more than one exchanger or be a single multi-pass exchanger. Equivalent types of reboilers will be known to those skilled in the art. As another example, a separate stripper and absorber can be used instead of a reboiled absorber.
This application claims the benefit of a provisional application having U.S. Ser. No. 60/406,502, filed on Aug. 28, 2002, which hereby is incorporated by reference in its entirety.
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Number | Date | Country | |
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60406502 | Aug 2002 | US |