JP2015166670A - natural gas liquefaction - Google Patents

Abstract

PROBLEM TO BE SOLVED: To provide a process for processing natural gas stream or other methane-rich gas stream at a low cost so as to produce both liquefied natural gas (LNG) stream of high purity methane and liquid stream mainly including carbon hydride heavier than methane.SOLUTION: The process for liquefying natural gas 50 in conjunction with producing liquid stream 41 containing predominantly hydrocarbons heavier than methane is provided. In the process, natural gas stream 31 to be liquefied is partially cooled, expanded to intermediate pressure 14, 15, and supplied to a distillation column 19. It is preferable that bottom product material 41 from the distillation column 19 contains the majority of any hydrocarbon heavier than methane that otherwise reduce the purity of liquefied natural gas. Residual gas stream 37 from the distillation column 19 is compressed to attain a high intermediate pressure 16, cooled under pressurize and condensed 60, and then expanded to low pressure low to form liquefied natural gas stream 50.

Description

The present invention relates to a method of treating natural gas or other methane-rich gas streams to produce a high purity liquefied natural gas (LNG) stream of methane and a liquid stream primarily comprising hydrocarbons heavier than methane.

  Natural gas is usually recovered from wells drilled in underground reservoirs. Natural gas is usually predominantly methane, ie methane constitutes at least 50 mole percent of natural gas. Depending on the particular underground reservoir, natural gas also contains relatively small amounts of heavy hydrocarbons such as ethane, propane, butane, pentane, as well as water, hydrogen, nitrogen, carbon dioxide and other gases.

Most natural gas is handled in gaseous form. The most common means for transporting natural gas from a source to a gas processing plant and from there to a natural gas consumer is the high pressure gas transport pipeline. However, in many cases it has been considered necessary and / or desirable to liquefy natural gas for transport or use. In remote areas, for example, there are often no pipeline facilities that allow for easy transportation of natural gas to the market. In such a case, since the specific volume of LNG is very low with respect to the natural gas in a gaseous state, the transportation cost can be greatly reduced by transporting the LNG using a cargo ship and a transportation truck.

Another case where natural gas liquefaction is preferred is when used as automotive fuel. In metropolitan areas, many buses, taxis and trucks could have been powered by LNG if economical LNG sources were available. Vehicles that are fueled with such LNG are less likely to be polluted by the air due to the ability to burn natural gas fuel cleanly compared to similar vehicles powered by gasoline and diesel engines that burn high molecular weight hydrocarbons. Quite few. In addition, if LNG is of high purity (that is, methane purity of 95% or higher), methane has a lower carbon: hydrogen ratio than all other hydrocarbon fuels, so carbon dioxide produced (warming gas) The amount is quite small.

The present invention typically liquefies natural gas and at the same time a liquid stream composed primarily of hydrocarbons heavier than methane, such as natural gas liquid (NGL) composed of ethane, propane, butane and heavier hydrocarbon components. ), Liquefied petroleum gas (LPG) composed of propane, butane and heavier hydrocarbon components, or a condensate composed of butane and heavier hydrocarbon components as a by-product . Two key advantages for the production of by-product liquid streams: the LNG produced is of high methane purity, and the by-product liquid is a useful product that can be used for many other purposes. There is. Typical analytical results for a natural gas stream to be treated according to the present invention are approximately 84.2% methane, 7.9% ethane and other C ₂ components, 4.9% propane and other C ₃ components, 1.0% isobutane on a mole percent basis. 1.1% normal butane, 0.8% pentane, with the balance being nitrogen and carbon dioxide. Gases containing sulfur may also be included.

Many methods are known for liquefying natural gas. For example, for the investigation of many such processes, Finn, Adrian J., Grant L. Johnson and Terry R. Tomlinson, “LNG Technology for Offshore and Mid-Scale Plants”, Proceedings of the Seventy-Ninth Annual Convention of the Gas Processors Association, pp. 429-450, Atlanta, Georgia, March 13-15, 2000 and Kikkawa, Yoshitsugi, Masaaki Ohnishi, and Noriyoshi Nozawa, “Optimize the Power System of Baseload LNG Plant”, Proceedings of the Eightieth Annual Convention of the Gas Process Association, San Antonio, Texa
s, March 12-14, 2001. U.S. Pat. Nos. 4,445,917; 4,525,185; 4,545,795; 4,755,200; 5,291,736; 5,363,655; 5,365,740
No. 5,600,969; No. 5,615,561; No. 5,651,269; No. 5,755,114; No. 5,893,274; No. 6,014,869; No. 6,062,041; No. 6,119,479; No. 6,125,653; No. 6,250,105 No. 6,269,655B1; No. 6,272,882B1; No. 6,308,531B1; No. 6,324,867B1 and No. 6,347,532B1 also describe related processes. These methods typically involve purifying, cooling, condensing and expanding natural gas (by removing water and laborious compounds such as carbon dioxide and sulfur compounds). Natural gas cooling and condensation can be accomplished by various methods. “Cascade refrigeration” utilizes heat exchange between natural gas and several types of refrigerant (refrigerant) having a low boiling point in the order of propane, ethane and methane. Alternatively, this heat exchange can be performed using one type of refrigerant by evaporating the refrigerant at several different pressure levels. In “multi-component refrigeration”, heat exchange between one or more refrigerant fluids composed of several refrigerant components and natural gas is used instead of various single refrigerant components. Natural gas expansion can be done either enthalpy (for example using Joule-Thomson expansion) and isentropic [for example using a work-expansion turbine].

Regardless of the method used to liquefy the natural gas stream, most of the hydrocarbons heavier than methane typically must be removed before liquefying the methane-rich stream. The reasons for this hydrocarbon removal stage are numerous, such as the calorific value of the LNG stream must be controlled and the value of its heavy hydrocarbon component as a product itself. Surprisingly, little attention has been paid to the efficiency of this hydrocarbon removal step to date.

In accordance with the present invention, by carefully integrating the hydrocarbon removal stage into the LNG liquefaction process, it is possible to produce LNG and individual heavy hydrocarbon liquid products with significantly less energy than conventional processes. Although applicable at low pressures, the present invention is particularly advantageous when the feed gas is treated in the range of 400-1500 psia [2,758-10,342 kPa (a)] or higher.

FIG. 1 is a flow chart of a natural gas liquefaction plant adapted to simultaneously produce NGL according to the present invention. FIG. 2 is a pressure-enthalpy phase diagram for methane used to illustrate the advantages of the present invention over the conventional process. FIG. 3 is a flowchart of another natural gas liquefaction plant adapted to simultaneously produce NGL according to the present invention. FIG. 4 is a flowchart of another natural gas liquefaction plant adapted to simultaneously produce LPG according to the present invention. FIG. 5 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce condensate according to the present invention. FIG. 6 is a flowchart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 7 is a flowchart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 8 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 9 is a flowchart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 10 is a flowchart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 11 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 12 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 13 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 14 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 15 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 16 is a flowchart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 17 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 18 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 19 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 20 is a flowchart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention. FIG. 21 is a flow chart of another natural gas liquefaction plant adapted to simultaneously produce a liquid stream according to the present invention.

In the above description of the drawings, a table summarizing the flow rates calculated for representative process conditions is provided. In this table, flow rate values (mol / hour) are rounded to the nearest whole number for convenience. The total stream speed shown in the table is usually greater than the sum of the stream flow rates of the hydrocarbon components since it includes all non-hydrocarbon components. The indicated temperature is an approximate value rounded to the nearest temperature. Process design calculations performed for the purpose of comparing the illustrated processes are based on the assumption that there is no heat loss from ambient to process or from process to ambient. The quality of commercially available thermal insulation materials assumes this assumption to be very reasonable and can usually be implemented by one skilled in the art.
For convenience, process parameters are reported in both conventional British Standard units and International Unit System (SI) units. The molar flow rates in the table can be interpreted as pound moles / hour or kilogram moles / hour. The energy consumption reported as horsepower (HP) and / or 1000 British thermal units / hour (MBTU / Hr) corresponds to the specified molar flow rate in lbmol / hour. The energy consumption reported as kilowatts (kW) corresponds to a defined molar flow rate in kilogram mol / hour. The production rate reported as pounds per hour (Lb / Hr) corresponds to the specified molar flow rate in pounds mole / hour. The production rate reported as kilogram / hour (kg / Hr) corresponds to the prescribed molar flow rate in kilogram mole / hour.

Example 1
Referring to FIG. 1, we begin with a description of the process according to the present invention. In this figure, it is desirable to produce an NGL byproduct that contains most of the ethane and heavy components in the natural gas feed stream. In this simulation of the present invention, the inlet gas is 90 ° F [32 ° C] as stream 31.
And enter the plant at 1285psia [8,860kPa (a)]. If the inlet gas contains certain concentrations of carbon dioxide and / or sulfur compounds that interfere with the product stream and do not meet specifications, these compounds suitably pretreat (not shown) the feed gas To remove. Furthermore, this feed stream is usually dehydrated so that hydrates (ice) do not form under cryogenic conditions. For this purpose, solid desiccants have usually been used.

Supply stream 31 at -68 ° F [-55 ° C] with refrigerant stream and demethanizer side
It is cooled in the heat exchanger 10 by heat exchange with a reboiler (demethanizer side reboiler) liquid. It should be noted that in all cases, heat exchanger 10 is a group of individual heat exchangers, or a representative example of a single multi-pass heat exchanger, or any combination thereof. (Determining whether to use more than one heat exchanger for the indicated cooling facility depends on many factors including, but not limited to, inlet gas flow rate, heat exchanger size, stream temperature, etc.) Cooling stream 31a enters separator 11 at −30 ° F. [−34 ° C.] and 1278 psia [8,812 kPa (a)], where vapor (stream 32) is separated from condensed liquid (stream 33).

Steam (stream 32) from separator 11 is split into two streams 34 and 36. Stream 34 containing about 20% of the total vapor is mixed with condensed liquid, stream 33 to form stream 35.
The mixed stream 35 passes through the heat exchanger 13 in a heat exchange relationship with the refrigerant stream 71e,
Stream 35a is cooled and substantially condensed. Substantially condensed stream 35a is then flash expanded through a suitable expansion device, such as expansion valve 14, at -120 ° F [-85 ° C] to produce an operating pressure of fractionation tower 19 (approximately 465 psia [3,206 pKa (a )]). During expansion, the stream partially evaporates and the entire stream is cooled. In the process shown in FIG. 1, the expansion stream 35b leaving the expansion valve 14 reaches a temperature of −122 ° F. [−86 ° C.] and is fed to the intermediate feed position of the demethanization section 19b of the fractionation tower 19. Is done.

The remaining 80% of the steam from the separator 11 (stream 36) enters the expansion work machine 15, where mechanical energy is removed from this portion of the high pressure feed. Machine 15 expands this vapor substantially isentropically from about 1278 psia [8,812 kPa (a)] to the column operating pressure, and expands the expansion stream 36 a to a temperature of about −103 ° F. [−75 ° C.]. Cool by. Normally available expanders are recoverable on the order of 80-85% of the theoretically available work with ideal isentropic expansion. The recovered work is often used to drive a stretch compressor (eg, item 16) that can be used, for example, to recompress the overhead gas (stream 38). The expanded and partially condensed stream 36a is distilled into the distillation column 19 at the lower intermediate column feed point.
To supply as a feed material.

The demethanizer in fractionator 19 is a conventional distillation column that includes a plurality of vertically arranged trays, one or more packed beds, or a combination of trays and packing materials. As often seen in natural gas processing plants, this fractionator may consist of two compartments. Upper compartment 19a is a separator where the upper feed is divided into a vapor and a liquid portion, respectively, and the vapor rising from the lower distillation or demethanization compartment 19b (if any) is the vapor portion of the upper feed. To form a cold demethanizer top vapor (stream 37) which exits the top at -135 ° F [-93 ° C]. The lower demethanization section 19b contains trays and / or fillers and provides the necessary contact between the descending liquid and the ascending vapor. The demethanization section also includes one or more reboilers (eg, reboiler 20) that heat and vaporize a portion of the liquid descending the column to provide stripping vapor that rises up the column. The liquid product stream 41 exits the bottom of the column at 115 ° F. [46 ° C.] based on a typical specification with a methane: ethane ratio of 0.020: 1 on a bottom product molar basis.

The demethanizer top steam (stream 37) is warmed to 90 ° F. [32 ° C.] by heat exchanger 24, and a portion of the warm demethanizer top steam is withdrawn and supplied as plant fuel gas (stream 48). (The amount of fuel gas that must be extracted is determined primarily by the fuel required for the engine and / or turbine that drives the plant gas compressor, such as refrigerant compressors 64, 66, and 68 in this embodiment, for example. Remaining steam at the top of the warm demethanizer tower (stream)
38) is compressed by a compressor 16 driven by expansion machines 15, 61 and 63. After cooling to 100 ° F. [38 ° C.] with a discharge cooler 25, stream 38b is −123 in heat exchanger 24 by cross exchange with cold demethanizer tower top steam, stream 37.
Cool to ° F [-86 ° C].

Stream 38c then enters heat exchanger 60 and is further cooled by refrigerant stream 71d. After cooling to an intermediate temperature, stream 38c is divided into two parts. The first part, stream 49, is further cooled to -257 ° F [-160 ° C] in heat exchanger 60 to condense and subcool, and the stream enters expansion work machine 61, where mechanical energy Is removed from the stream. The machine 61 expands the liquid stream 49 from a pressure of about 562 spia [3,878 kPa (a)] to a LNG storage pressure (15.5 spia [107 kPa (a)]), slightly above atmospheric pressure, substantially isentropically. The stream 49a expanded by the expansion work is cooled to a temperature of about −258 ° F. [−161 ° C.] and directed to the LNG storage tank 62 to hold the LNG product (stream 50).

Another portion of stream 39, stream 38c is withdrawn from the heat exchanger at -160 ° F [-107 ° C] and flash expanded to the operating pressure of fractionator 19 with a suitable expansion device such as expansion valve 17. In the process shown in FIG. 1, since there is no evaporation in the expansion stream 39a, the temperature drops slightly to −161 ° F. [−107 ° C.] and exits the expansion valve 17. The expanded stream 39a is then fed to the separator section 19a in the upper region of the fractionator 19. The separated liquid then becomes the upper feed to the demethanization section 19b.

All cooling of streams 35 and 38c is provided by a closed circulation cooling loop. The working fluid for this cycle is a mixture of hydrocarbon and nitrogen, and the composition of this mixture provides the required refrigerant temperature while condensing at the proper pressure using available cooling media. Adjusted as needed. In this case, since it is assumed that the water is condensed using the cooling water, a refrigerant mixture composed of nitrogen, methane, ethane, propane and heavier hydrocarbons is used in the process simulation of FIG. The composition of the stream is approximately mole percent, 7.5% nitrogen, 41.0% methane, 41.5% ethane and 10.0% propane, with the remainder being heavier hydrocarbons.

Refrigerant stream 71 leaves effluent cooler 69 at 100 ° F. [38 ° C.] and 607 psia [4,185 kPa (a)]. This stream enters the heat exchanger 10, is cooled to -31 ° F [-35 ° C], and is partially condensed by the partially warmed expanded refrigerant stream 71f and other refrigerant streams. For the simulation of FIG. 1, it was assumed that these other refrigerant streams were commercial quality propane refrigerants at various temperature and pressure levels. The partially condensed refrigerant stream 71a is then further -114 ° F [81 by the partially warmed expanded refrigerant stream 71e.
The heat exchanger 13 is entered to allow the refrigerant (stream 71b) to partially subcool. This refrigerant is further subcooled to −257 ° F. [−160 ° C.] in the heat exchanger 60 by the expanded refrigerant stream 71d. This supercooled liquid stream 71c enters the expansion work machine 63 where as the stream expands substantially isentropically to a pressure of about 586 psia [4,040 kPa (a)] to about 34 psia [234 kPa (a)]. Energy is extracted from the stream. During expansion, a portion of the stream evaporates and cools the entire stream to -263 ° F [-164 ° C] (stream 71d). The expanded stream 71d then enters the heat exchangers 60, 13 and 10 where it is vaporized and superheated as stream 38c, stream 35 and refrigerant (streams 71, 71a and 71b).
Cool down.

The superheated refrigerant vapor (stream 71 g) leaves the heat exchanger 10 at 93 ° F. [34 ° C.] and is compressed to 617 psia [4,254 kPa (a)] in three stages. The three compression stages (refrigerant compressors 64, 66 and 68) are each driven by a reserve power source and proceed to the coolers (outflow coolers 65, 67 and 69) to remove the heat of compression. The compressed stream 71 from the effluent cooler 69 returns to the heat exchanger 10 to complete the cycle.
A summary of the stream flow rate and energy consumption of the process shown in FIG. 1 is shown in the following table.

LNG production process efficiencies are typically compared using the required “specific power consumption”, which is the ratio of the total cooling compression power to the total liquid production rate. Specific power consumption public information regarding conventional processes for producing LNG ranges from 0.168 HP-Hr / Lb [0.276 kW / -hour / kg] to 0.182 HP-Hr / Lb [0.300 kW / -hour / kg]. This shows 340 LNG plant annually
This is thought to be based on the daily operating factors. On this same basis, the specific power consumption of the embodiment of FIG. 1 of the present invention is 0.161 HP-Hr / Lb [0.265 kW / -hour / kg], which is 4 to 13% more efficient than the conventional process. doing. Furthermore, the specific power consumption of the conventional process is not an NGL (C ₂ and heavier hydrocarbons) liquid stream as shown in this embodiment of the invention, but LPG (C ₃ and which heavier hydrocarbons) or condensate (C ₄ and only needs to be noted that the base to be manufactured simultaneously hydrocarbons) liquid streams which heavier. Conventional processes require significant cooling power to simultaneously produce NGL streams instead of LPG streams or condensate streams.

There are two main factors that contribute to the superior efficiency of the present invention. The first factor can be understood by examining the thermodynamics of the liquefaction process when applied to a high pressure gas stream as discussed in this example. Since the main component of this stream is methane, the thermodynamic properties of methane can be used for the purpose of comparing the liquefaction process used in the conventional process with the cycle used in the present invention. FIG. 2 includes a pressure-enthalpy phase diagram for methane. In most conventional liquefaction cycles, the gas stream is all cooled, at the same time the stream is at high pressure (pass AB), then the stream expands (pass BC) and the pressure in the LNG storage vessel (slightly above atmospheric pressure). become. In this expansion stage, an expansion work machine can be used, which can usually recover on the order of 75-80% of the work theoretically available with ideal isentropic expansion. For simplicity, the complete isentropic expansion is shown in FIG. Nevertheless, the enthalpy reduction provided by this expansion work is rather small because the constant entropy line is almost vertical in the liquid region of the phase diagram.

This is contrasted with the liquefaction cycle of the present invention. After partial cooling at high pressure (pass A-A '), this gas stream is subjected to expansion work to an intermediate pressure (pass A'-A ") (again, for simplicity, full isentropic expansion is performed. The remaining cooling (shown) is performed at intermediate pressure (pass A "-B ') and then the stream is expanded to the pressure of the LNG storage vessel (pass B'-C). Since the line of constant entropy rope is provided by the gas phase region of the phase diagram, the first expansion work stage of the present invention (
The path A'-A ") provides a significant enthalpy reduction. Thus, the total amount of cooling required by the present invention (the sum of the paths A-A 'and A"-B') is equal to the cooling required in the conventional process. Less than (pass AB) and requires less cooling power to liquefy into a gas stream.

The second factor responsible for the superior efficiency of the present invention is the successful operation of hydrocarbon distillation systems at low operating pressures. The hydrocarbon removal step in most conventional processes is usually carried out at high pressure using a scrub column that uses a cold hydrocarbon liquid as the adsorption stream to remove heavy hydrocarbons from the incoming gas stream. . Since a significant fraction of methane and ethane is simultaneously adsorbed from the gas stream, which must then be stripped from the adsorbed liquid and cooled to become part of the LNG product, the scrub column is operated at high pressure. It is not very efficient to operate. In the present invention, the hydrocarbon removal step is carried out at an intermediate pressure, where gas-liquid equilibration is much more convenient and the desired heavy hydrocarbons can be recovered very efficiently in the by-product liquid stream.
Example 2
If more ethane contained in the feed gas can be recovered in the LNG product according to the standards for LNG products, the simple aspect of the present invention can be used. FIG. 3 shows such another embodiment. The inlet gas composition and conditions considered in the process shown in FIG. 3 are the same as those in FIG. Thus, the process of FIG. 3 can be compared to the embodiment shown in FIG.

In the process simulation of FIG. 3, the inlet gas cooling, separation and expansion scheme for the NGL recovery section is essentially the same as that used in FIG. Inlet gas is stream 31
Enter the plant at 90 ° F [32 ° C] and 1285psia [8,860kPa (a)], and at -35 ° F [-37 ° C] by heat exchange between the refrigerant stream and the demethanizer side reboiler liquid (stream 40) To be cooled. This cooling stream 31a is -30 ° F [-34 ° C] and 1278 psia [8,812 kPa (a)].
At which the vapor (stream 32) is separated from the condensed liquid (stream 33).

Steam (stream 32) from separator 11 is split into two streams 34 and 36. Stream 34 containing about 20% of the total vapor is mixed with stream 33 of condensed liquid to form stream 35. The mixed stream 35 is cooled through the heat exchanger 13 in a heat exchange relationship using the refrigerant stream 71e, and is substantially condensed into the stream 35a. This substantially condensed stream 35a is -120 ° F [-85 ° C] and is passed through a suitable expansion device such as expansion valve 14 to the operating pressure of fractionation column 19 (approximately 465 psia [3,206 kPa (a)] ) Inflate the flash. During expansion, part of the stream is vaporized and the entire stream is cooled. In the process shown in FIG. 3, the expansion stream 35 b leaving the expansion valve 14 reaches a temperature of −122 ° F. [−86 ° C.] and is fed to the separator section in the upper region of the fractionator 19. The liquid separated in this becomes the upper feed to the demethanization section in the lower region of the fractionator 19.

The remaining 80% of steam from the separator 11 (stream 36) enters the expansion work machine 15, where mechanical energy is removed from this portion of the high pressure feed. This machine 15 expands steam substantially isentropically from a pressure of about 1278 psia [8,812 kPa (a)] to the operating pressure of the tower, and the expansion work causes expansion stream 36a to be about −103 ° F. [−75 ° C.]. Cool to the temperature of. This expansion,
A partially condensed stream 36a is fed to the distillation column 19 as a feed at an intermediate column feed point.

The cold demethanizer top vapor (stream 37) exits the top of fractionator 19 at -123 ° F [-86 ° C]. The liquid product stream 41 has a methane to ethane ratio of 0.020: 1 on a molar basis of the bottom product.
Exit the bottom of the tower at 118 ° F [48 ° C], based on the typical specifications.

The demethanizer top vapor (stream 37) is warmed to 90 ° F. [32 ° C.] by heat exchanger 24, and then a portion (stream 48) is withdrawn and used as plant fuel gas. The remainder of the warm demethanizer tower top vapor (stream 49) is compressed by the compressor 16. After cooling to 100 ° F [38 ° C] with a discharge cooler, the stream 49b is further -112 ° F [-80 ° C in the heat exchanger 24 by exchange with the cold demethanizer tower top steam, stream 37 Cool down.

Stream 49c then enters heat exchanger 60 and is further cooled to −257 ° F. [−160 ° C.] with refrigerant stream 71d to condense and supercool this stream, and the stream enters expansion work machine 61; Here mechanical energy is extracted from the stream. Machine 61 expands liquid stream 49d substantially isentropically from about 583 psia [4,021 kPa (a)] to a LNG storage pressure just above atmospheric pressure (15.5 psia [107 kPa (a)]). This expansion work cools the expanded stream 49e to about −258 ° F. (−161 ° C.) and is directed to the LNG storage tank 62 (stream 50) where the LNG product stream 50 is retained.

As with the process of FIG. 1, all cooling of streams 35 and 49c is provided by a closed system cooling loop. The composition of the stream used as the working fluid in the process cycle of FIG. 3 was approximately mole percent 7.5% nitrogen, 40.0% methane, 42.5% ethane and 10.0% propane, with the balance being heavy hydrocarbons. Refrigerant stream 71 leaves effluent cooler 69 at 100 ° F. [38 ° C.] and 607 psia [4,185 kPa (a)]. This enters the heat exchanger 10 and is cooled to -31 ° F [-35 ° C]
It is partially condensed by the partially warmed expanded refrigerant stream 71f and by other refrigerant streams. For the simulation of FIG. 3, these other refrigerant streams were assumed to be commercial quality propane refrigerants at various temperature and pressure levels. The partially condensed refrigerant stream 71a is then further cooled to −121 ° F. [−85 ° C.] by the partially warmed expanded refrigerant stream 71e to condense and supercool the refrigerant (stream 71b). .
This refrigerant is further subcooled to −257 ° F. [−160 ° C.] in the heat exchanger 60 by the expanded refrigerant stream 71d. This supercooled liquid stream 71c enters the expansion work machine 63 where it mechanically expands substantially isentropically from a pressure of about 586 psia [4,040 kPa (a)] to about 34 psia [234 kPa (a)]. Energy is extracted from the stream. During expansion, a portion of the stream is vaporized and the entire stream is cooled to -263 ° F [-164 ° C] (stream 71d). This expanded stream 71d then enters heat exchangers 60, 13 and 10 where it is vaporized and superheated.
The stream 49c, the stream 35, and the refrigerant (streams 71, 71a, and 71b) are cooled.

  The superheated refrigerant vapor (stream 71 g) leaves the heat exchanger 10 at 93 ° F. [34 ° C.] and is compressed to 617 psia [4,254 kPa (9)] in three stages. The three compression stages (refrigerant compressors 64, 66 and 68) are each driven by an additional power source to remove the heat of compression following the coolers (outflow coolers 65, 67 and 69). This compressed stream from effluent cooler 69 returns to heat exchanger 10 to complete the system.

  A summary of the stream flow rate and energy consumption of the process shown in FIG. 3 is shown in the following table.

Assuming that the LNG production plant has an operating factor of 340 days per year, the specific power consumption of the embodiment of FIG. 3 of the present invention is 0.153 HP-Hr / Lb [0.251 kW-Hr / Kg]. Compared to the conventional process, the improvement efficiency is 10-20% for the embodiment of FIG. As already mentioned in the embodiment of FIG. 1, this improved efficiency is possible in the context of the present invention in that NGL by-products are produced rather than condensed by-products or LPG produced by conventional processes.

Compared to the embodiment of FIG. 1, the embodiment of FIG. 3 of the present invention requires about 5% less power per unit of liquid produced. Thus, for a given amount of available compression power, the embodiment of FIG.
Because less C ₂ and heavy hydrocarbons can be recovered in the by-products, about 5% more natural gas may be liquefied than the embodiment of FIG. The choice between the embodiment of FIG. 1 and the embodiment of FIG. 3 for a particular application is usually NGL (since the calorific value of LNG produced by the embodiment of FIG. 1 is lower than that produced by the embodiment of FIG. 3). Determined by the monetary value of heavy hydrocarbons in the product versus its corresponding value in the LNG product or by the calorific value specification for the LNG product.
Example 3
If all ethane contained in the feed gas can be recovered in the LNG product according to LNG product specifications, or if there is no market for liquid by-products containing ethane, as shown in FIG. Another aspect of the invention can be used to produce an LPG byproduct stream. The inlet gas composition and conditions studied in the process shown in FIG. 4 are the same as those in FIGS. Therefore, the process of FIG. 4 can be compared to the embodiment shown in FIGS.

In the process simulation of FIG. 4, the inlet gas enters the plant at 90 ° F. [32 ° C.] and 1285 psia [8,860 kPa (a)] as stream 31 and the refrigerant stream and flash separation at −46 ° F. [−43 ° C.]. It is cooled in the heat exchanger 10 by heat exchange with the liquid in the vessel (stream 33a). This cooling stream 31a enters the separator 11 at -1 ° F [-18 ° C] and 1278 psia [8,812 kPa (a)], where it separates the vapor (stream 32) from the condensed liquid (stream 33).

Steam (stream 32) from separator 11 enters expansion work machine 15, where mechanical energy is removed from this portion of the high pressure feed. This machine 15 expands the vapor substantially isentropically from a pressure of about 1278 psia [8,812 kPa (a)] to a pressure of about 440 psia [3,034 kPa (a)] (the operating pressure of the separator / adsorption tower 18). The expansion stream 32a is cooled to a temperature of about −81 ° F. [−63 ° C.] by expansion work. The expanded and partially condensed stream 32a is fed to the adsorption section 18b in the lower region of the separator / adsorption tower 18. The liquid portion of the expanded stream mixes with liquid descending from the adsorption section, and the mixed liquid stream 40 exits the bottom of the separator / adsorption tower 18 at -86 ° F [-66 ° C]. The vapor portion of the expanded stream rises through the adsorption section and contacts the descending cold liquid to condense and absorb C ₃ and heavy components.

Separator / adsorption tower 18 is a conventional distillation column that includes a plurality of vertically spaced trays, one or more packed beds, or a combination of trays and packing materials. As is common in natural gas processing plants, the separator / adsorption tower may consist of two compartments. The upper compartment 18a is a separator, where all the vapor contained in the upper feed is separated from its corresponding liquid portion, where the vapor rising from the lower distillation or adsorption compartment 18b is the vapor portion of the upper feed Mix with (if any) to form a cold distillation stream 37 that exits the top of the column.
The lower adsorption compartment 18b contains trays and / or fillers and provides the necessary contact between the descending liquid and the ascending vapor to condense and adsorb the C ₃ and heavy components.

The mixed liquid stream 40 from the bottom of the separator / adsorption tower 18 is transported by pump 26 to heat exchanger 13 where it cools the deethanizer tower top (stream 42) and refrigerant (stream 71a). , It (stream 40a) is heated. The mixed liquid stream is heated to −24 ° F. [−31 ° C.], partially vaporized stream 40b, and then fed to deethanizer 19 as an intermediate column feed. The separator liquid (stream 33) is flash expanded by the expansion valve 12 slightly above the operating pressure of the deethanizer 19, and the stream 33 is cooled to -46 ° F [-43 ° C] before entering as described above. Cool the feed gas. The 85 ° F. [29 ° C.] stream 33b now enters the deethanizer 19 at the lower intermediate column feed point. In the deethanizer, streams 40b and 33b is its methane and C ₂ components are stripped. The tower 19 deethanizer operating at about 453 psia [3,123 kPa (a)] can be a conventional distillation column that includes multiple vertically spaced trays, one or more packed beds, or a combination of trays and packing materials. is there. This deethanizer tower may consist of an upper separator section 19a and a lower deethanization section 19b, in which all vapors contained in the upper feed are transferred to their corresponding liquid parts. And the vapor coming from the lower distillation or deethanization section 19b is mixed with the vapor portion (if any) of the upper feed to form a distillation stream 42 exiting the top of the column; lower deethanization Combining section 19 contains trays and / or fillers and provides the necessary contact between the descending liquid and the ascending vapor. The deethanization section 19b also includes one or more reboilers (e.g., reboiler 20) that heat and vaporize a portion of the liquid at the bottom of the column to provide stripping vapor, which flows up the column. Strip the liquid product, stream 41, of methane and C ₂ components. A typical specification for the bottom liquid product is an ethane to propane ratio of 0.020: 1 on a molar basis. The liquid product stream 41 exits the bottom of the deethanizer at 214 ° F. [101 ° C.].

The operating pressure in the deethanizer 19 is kept slightly above the operating pressure in the separator / adsorption tower 18. This allows deethanizer tower top vapor (stream 42) to flow through heat exchanger 13 and then into the upper section of separator / adsorption tower 18. In heat exchanger 13, at -19 ° F [-28 ° C], the top of the deethanizer column is led to a heat exchange relationship with the mixed liquid stream (stream 40a) from the bottom of the separator / adsorption column 18 to flush the refrigerant stream 71e. Stream to -89 ° F [-67
° C] (stream 42a) and partially condensed. This partially condensed stream enters the reflux drum 22 where the condensed liquid (stream 44) is separated from the uncondensed vapor (stream 43). Stream 43 is mixed with a distilled vapor stream (stream 37) leaving the upper region of the separator / adsorber to form a cold residue gas stream 47. Condensed liquid (stream 44) is pumped to high pressure by pump 23 and at the same time the stream is split into two parts. One partial stream 45 is transported to the upper separator section of the separator / adsorption tower 18 and functions as a cold liquid in contact with the vapor rising in the adsorption section. The other is fed as a reflux stream 46 to the deethanizer 19 and flows to the upper feed point at -89 ° F [-67 ° C].

The cold residue gas (stream 47) is heated in the heat exchanger 24 from −94 ° F. [−70 ° C.] to 94 ° F. [34 ° C.], and a part (stream 48) is withdrawn to become plant fuel gas. Function as. The remainder of the warm residue gas (stream 49) is compressed by the compressor 16. After cooling to 100 ° F [38 ° C] in effluent cooler 25, stream 49b is further cooled to -78 ° F [-61 ° C] in heat exchanger 24 by cold residue gas, stream 47 interchanged To do.

Stream 49c then enters heat exchanger 60 and is further cooled to −255 ° F. [−160 ° C.] by refrigerant stream 71d to condense and subcool the stream so that it enters expansion work machine 61 where the machine Energy is extracted from the stream. This machine 61 expands the liquid stream 49d from a pressure of approximately 648 psia [4,465 kPa (a)] to a LNG storage pressure slightly above atmospheric pressure (15.5 psia [107 kPa (a)]) substantially isentropically. Let This expansion work cools the expansion stream 49c to a temperature of about −256 ° F. [−160 ° C.] to produce an LNG product (stream 50).
To the LNG storage tank 62 holding the

Similar to the process of FIGS. 1 and 3, the closed cycle cooling loop provides most of the cooling of stream 42 and all of the cooling of stream 49c. The composition of the stream used as the working fluid in the cycle for the process of FIG. 4 is approximately 8.7% nitrogen, 30.0% methane, 45.8% ethane and 11.0% propane with the balance being heavy hydrocarbons. Refrigerant stream 71 leaves effluent cooler 69 at 100 ° F. [38 ° C.] and 607 psia [4,185 kPa (a)]. This enters the heat exchanger 10 and is cooled to -17 ° F [-27 ° C] and is partially condensed by the partially warmed expanded refrigerant 71f and by other refrigerant streams. For the simulation of FIG. 4, it is assumed that these other refrigerant streams are commercial quality propane refrigerants at three different temperature and pressure levels. The partially condensed refrigerant stream 71a is then passed through the heat exchanger 13
And is further cooled to -89 ° F [-67 ° C] by the partially warmed expanded refrigerant stream 71e to further condense the refrigerant (stream 71b). This refrigerant is fully condensed and subcooled to -255 ° F [-160 ° C] in the heat exchanger 60 by the expanded refrigerant stream 71d. As the supercooled liquid stream 71c enters the expansion work machine 63 where it mechanically expands substantially isenthalpy from a pressure of about 586 psia [4,040 kPa (a)] to about 34 psia [234 kPa (a)]. Energy is extracted from the stream. During expansion, a portion of the stream is vaporized and the entire stream is cooled to -264 ° F [-164 ° C] (stream 71d). The expanded stream 71d is then heat exchanger 60
, 13 and 10 again, and as it is vaporized and superheated, stream 49c, stream 42
And the refrigerant (streams 71, 71a and 71b) is cooled.

  Superheated refrigerant vapor (stream 71 g) leaves heat exchanger 10 at 90 ° F. [32 ° C.] and is compressed to 617 psia [4,254 kPa (a)] in three stages. The three compression stages (refrigerant compressors 64, 66 and 68) are each driven by an additional power source and remove the heat of compression following the coolers (outflow coolers 65, 67 and 69). The compressed stream 71 from the effluent cooler 69 returns to the heat exchanger 10 to complete the system.

  A summary of the stream flow rate and energy consumption of the process shown in FIG. 4 is shown in the following table.

  Assuming that the LNG production plant has an operating factor of 340 days per year, the specific power consumption of the embodiment of FIG. 4 of the present invention is 0.143 HP-Hr / Lb [0.236 kW-Hr / Kg]. Compared to the conventional process, the improvement efficiency is 17-27% for the embodiment of FIG.

Compared to the embodiment of FIGS. 1 and 3, the embodiment of FIG. 4 of the present invention is 6% per unit of liquid produced.
~ 11% lower power is required. Thus, for a given amount of available compression power, the embodiment of FIG. 4 is about 6% more natural gas than the embodiment of FIG. 1 by recovering C ₃ and heavy hydrocarbons as LPG by-products, or About 11% more natural gas can be liquefied than in the embodiment of FIG. The choice between the embodiment of FIG. 4 and the embodiment of FIG. 1 or FIG. 3 for a particular application is shown in FIG.
And the calorific value of LNG produced by the embodiment of FIG. 3 is usually lower than that produced by the embodiment of FIG. 4), usually the monetary value of heavy hydrocarbons in the NGL product versus its corresponding in the LNG product. Determined by value or by calorific value specification for LNG products.
Example 4
If ethane and propane contained in the feed gas can all be recovered in the LNG product according to the LNG product specifications, or if there is no market for liquid by-products containing ethane and propane, it is shown in FIG. Other embodiments of the invention as described can be used to produce a condensate byproduct stream. The inlet gas composition and conditions studied in the process shown in FIG. 5 are the same as those in FIGS. Thus, the process of FIG.
Can be compared with the embodiment shown in FIG.

In the simulation of the process of FIG. 5, the inlet gas enters the plant as stream 31 at 90 ° F. [32 ° C.] and 1285 psia [8,860 kPa (a)], cooled by the heat exchanger 10 with the refrigerant stream, and −37 ° F. The high pressure separator liquid is flushed at [−38 ° C.] (stream 33b) and the intermediate pressure separator liquid is flushed at −37 ° F. [−38 ° C.]. This cooling stream 31a enters the separator 11 at −30 ° F. [−34 ° C.] and 1278 psia [8,812 kPa (a)], where the vapor (stream 32) is condensed liquid (
Separated from stream 33).

Steam (stream 32) from separator 11 enters expansion work machine 15, where mechanical energy is removed from this portion of the high pressure feed. The machine 15 substantially expands the vapor 32a from the pressure of about 1278 psia [8,812 kPa (a)] to a pressure of about 635 psia [4,378 kPa (a)] and expands the stream 32a expanded by the expansion work. Cool to -83 ° F [-64 ° C]. The expanded and partially condensed stream 32a enters the separator 18, where the vapor (stream 42) is separated from the condensed liquid (stream 39). The intermediate pressure separator liquid (stream 39) is flash expanded by the expansion valve 17 slightly above the operating pressure of the depropanizer 19, and the stream 39 is cooled to -108 ° F [-78 ° C] (stream 49a Then, the stream enters the heat exchanger 13 and is heated as the residual gas stream 49, the refrigerant stream 71a and the heat exchanger 10 are cooled as described above, and the incoming feed gas is cooled. The -15 ° F [-26 ° C] stream 39c enters the depropanizer 19 at the upper intermediate column feed point.

The condensed liquid from the high pressure separator 11, the stream 33, is flushed and expanded slightly above the operating pressure of the depropanizer 19 by the expansion valve 12, and the stream 33 is cooled to −93 ° F. (−70 ° C.) ( The stream 33a), the stream enters the heat exchanger 13 and is heated as the residual gas stream 49, the refrigerant stream 71a, the heat exchanger are cooled as described above, and the incoming feed gas is cooled. The 50 ° F. [10 ° C.] stream 33c enters the depropanizer 19 at the lower intermediate column feed point. The depropanizer, stripped stream 39c and 33c methane, the C ₂ component and the C ₃ components. The depropanizer tower 19 operating at about 385 psia [2,654 kPa (a)] is a conventional distillation comprising a plurality of vertically spaced trays, one or more packed beds, or a combination of trays and packing materials. Column. This depropanizer tower may consist of two sections, an upper separator section 19a and a lower depropanization section 19b. In the upper separator section 19a, all of the above contained in the upper feed is separated from its corresponding liquid portion, and the vapor rising from the lower distillation or depropanization section 19b is the vapor portion (if any) of the upper feed. To form a distillation stream 37 exiting the top of the column. The lower depropanization section 19b contains trays and / or fillers and provides the necessary contact between the descending liquid and the ascending vapor. This depropanization section 19b also includes one or more reboilers (eg, reboiler 20), which heat and vaporize a portion of the liquid at the bottom of the column to produce a liquid product of methane, C ₂ and C ₃ components. , Providing stripping vapor ascending the column for stripping stream 41; A typical specification for the bottom liquid product is a propane to butane ratio of 0.020: 1 on a volume basis.
It is. The liquid product stream 41 exits the bottom of the deethanizer at 286 ° F. [141 ° C.].

The overhead distillation stream 37 exits the depropanizer 19 at 36 ° F. [2 ° C.] and is cooled and partially condensed in the reflux condenser 21 by commercial quality propane refrigerant. Partially condensed stream 37a exits reflux drum 22 at 2 ° F. [−17 ° C.], where condensed liquid (stream 44) is separated from uncondensed vapor (stream 43). The condensed liquid (stream 44) is pumped to the upper supply point of depropanizer 19 as reflux stream 44a.

The uncondensed vapor (stream 43) from the reflux drum 22 is warmed to 94 ° F. [34 ° C.] in the heat exchanger 24, and then a portion (stream 48) is withdrawn to become plant fuel gas. Residue of warm steam (
The stream 38) is compressed by the compressor 16. After cooling to 100 ° F. [38 ° C.] in effluent cooler 25, stream 38b is converted to 15 ° F [− in heat exchanger 24 by exchange with cold steam, stream 43.
9 ° C].

Stream 38c is then mixed with intermediate pressure separator vapor (stream 42) to form cold residue gas stream 49. Stream 49 enters heat exchanger 13 and is cooled from -38 ° F [-39 ° C] to -102 ° F [-74 ° C] by the separator liquid (streams 39a and 33a) and by refrigerant stream 71e as described above. Is done. The partially condensed stream 49a then enters the heat exchanger 60 and is further cooled to -254 ° F [-159 ° C] by the refrigerant stream 75d to condense and subcool, after which the stream enters the expansion work machine 61. There, mechanical energy is removed from the stream. Machine 61 expands liquid stream 49b substantially isentropically from about 621 psia [4,282 kPa (a)] to a LNG storage pressure slightly above atmospheric pressure (15.5 psia [107 kPa (a)]). The expansion stream 49c is cooled to a temperature of about −255 ° F. [−159 ° C.] by expansion work and then directed to the LNG storage tank (stream 50) to hold the LNG product.

Similar to the processes of FIGS. 1, 3 and 4, most of the cooling of stream 49 and all of the cooling of stream 49a is provided by a closed circulation cooling loop. The composition of the stream used as the working fluid in the cycle for the process of Figure 5 is approximately 8.9% nitrogen, 34.3% methane, 41.3% ethane and 11.0% propane with the balance being heavy hydrocarbons. Refrigerant stream 71 leaves effluent cooler 69 at 100 ° F. [38 ° C.] and 607 psia [4,185 kPa (a)]. This stream enters the heat exchanger 10, is cooled to -30 ° F. [-34 ° C.], and is partially condensed by the partially warmed expanded refrigerant stream 71f and by other refrigerant streams. For the simulation of FIG. 5, these other refrigerant streams were assumed to be commercial quality propane refrigerants at three different temperature and pressure levels. The partially condensed refrigerant stream 71a then enters the heat exchanger 13, where it is further cooled to -102 ° F [-74 ° C] by the partially warmed expanded refrigerant stream 71e to further condense the refrigerant (stream 71b). This refrigerant is fully condensed and then subcooled to −254 ° F. [−159 ° C.] by the heat exchanger 60 by the expanded refrigerant stream 71d. This supercooled liquid stream 71c enters the expansion work machine 63 and
Mechanical energy is removed from the stream as it expands substantially isentropically from a pressure of about 586 psia [4,040 kPa (a)] to about 34 psia [234 kPa (a)]. During expansion, a portion of the stream is vaporized and the entire stream is cooled to -264 ° F [-164 ° C] (stream 71d). The expanded stream 71d then enters heat exchangers 60, 13 and 10 and cools stream 49a, stream 49 and refrigerant (streams 71, 71a and 71b) as it is vaporized and superheated.

The superheated refrigerant vapor (stream 71 g) leaves the heat exchanger 10 at 93 ° F. [34 ° C.] and is compressed to 617 psia [4,254 kPa (a)] in three stages. The three compression stages (refrigerant compressors 64, 66 and 68) are each driven by an additional power source and follow the coolers (outflow coolers 65, 67 and 69) to remove the heat of compression. The compressed stream 71 from the effluent cooler 69 returns to the heat exchanger 10 to complete the cycle.

  An overview of the stream flow rate and energy consumption of the process shown in FIG. 5 is shown in the following table.

Assuming that the LNG production plant has an operating factor of 340 days per year, the specific power consumption of the embodiment of FIG. 5 of the present invention is 0.145 HP-Hr / Lb [0.238 kW-Hr / Kg]. Compared with the conventional process, the improvement efficiency is shown in FIG.
In this embodiment, it is 16 to 26%.

Compared to the embodiment of FIGS. 1 and 3, the embodiment of FIG. 5 of the present invention is 5% per unit of liquid produced.
~ 10% lower power is required. Thus, for a given amount of available compression power, the embodiment of FIG. 5 is about 5% more natural gas than the embodiment of FIG. 1 by recovering C ₄ and heavy hydrocarbons as condensate byproducts, Alternatively, about 10% more natural gas than the embodiment of FIG. 3 or approximately the same amount of natural gas as the embodiment of FIG. 4 can be liquefied. The choice between the embodiment of FIG. 5 and the embodiment of FIG. 1, 3 or 4 of the present invention for a particular application is that (the calorific value of LNG produced by the embodiment of FIG. 1, FIG. 3 and FIG. 4 is the embodiment of FIG. Is usually determined by the monetary value of ethane and propane in the NGL or LPG product versus its corresponding value in the LNG product, or by the calorific value specification for the LNG product.
Other Embodiments Those skilled in the art will recognize that the present invention for use in all types of LNG liquefaction plants so that NGL streams, LPG streams or condensate streams can be produced simultaneously to best meet the demand at a given plant location. Will understand that can be adapted. It will further be appreciated that various process arrangements can be used to recover the liquid byproduct stream. For example, the embodiment of FIGS. 1 and 3 can be adapted to recover an LPG stream or a condensate stream as a liquid byproduct stream, rather than an NGL stream as described in Examples 1 and 2. The embodiment of FIG. 4 is used to recover an NGL stream containing a significant fraction of the C ₂ component contained in the feed gas rather than producing an LPG by-product as described in Example 3, or in the feed gas. it can be adapted to recover the condensate stream containing only the C ₄ and heavier components contained in the. The embodiment of FIG. 5 is an NGL containing a significant fraction of the C ₂ component contained in the feed gas rather than producing a condensate byproduct as described in Example 4.
It can be adapted to recover the stream or to recover an LPG stream containing a significant fraction of the C ₃ component contained in the feed.

1, 3, 4 and 5 show preferred embodiments of the present invention for the indicated processing conditions. 6-21 represent another aspect of the present invention that may be considered for a particular application. As shown in FIGS. 6 and 7, all or part of the condensed liquid (stream 33) from the separator 11 is mixed with part of the separator vapor (stream 34) flowing to the heat exchanger 13 Rather, it can be fed separately to the fractionator 19 at the lower intermediate column feed position. FIG. 8 shows another embodiment of the present invention whose specific power consumption is somewhat higher but may require fewer devices than the embodiment of FIGS. Similarly, FIG. 9 illustrates another embodiment of the present invention that may require fewer devices than the embodiment of FIGS. 3 and 7 at the expense of high specific power consumption. FIGS. 10-14 illustrate another embodiment of the present invention that has higher specific power consumption but may require fewer devices than the embodiment of FIG. (Note that, as shown in FIGS. 10-14, a distillation column or system such as, for example, deethanizer 19 includes both a reboiling adsorbent tower design and a reflux reboiling tower design). FIG. 16 shows another embodiment of the present invention that combines the functions of the separator / adsorbent tower 18 and deethanizer 19 of FIGS. 4 and 10-14 into a single fractionation column 19. Depending on the quality of the heavy hydrocarbons in the feed gas and the feed gas pressure, the cooled feed stream 31a leaving the heat exchanger 10 does not contain any liquid [beyond the dew point or The separator 11 shown in FIGS. 1 and 3-16 is not necessary, as the criocondenbar is exceeded, and the cooling feed stream flows directly to a suitable expansion device such as the expansion work machine 15 Can do.

Prior to feeding heat exchanger 60 for condensation and subcooling, a liquid byproduct stream (FIGS.
The treatment of the gas stream remaining after collecting streams 37 of 6-11, 13 and 14; stream 47 of FIGS. 4, 12, 15 and 16; and stream 43) of FIG. 5 can be carried out in a number of ways. . In the process of FIGS. 1 and 3-16, the stream is heated, compressed to high pressure using energy derived from one or more expanded work machines, partially cooled with an effluent cooler, and then the original stream It is further cooled by mutual exchange. As shown in FIG. 17, in some applications it is preferable to compress the stream to high pressure, for example using an additional compressor 59 driven by an external power source. In some situations, before entering the heat exchanger 60 (refrigerant compressors 64, 66 and 68), as shown by the dashed line devices (heat exchanger 24 and effluent cooler 25) in FIGS. It is preferable to reduce the capital cost of the equipment by reducing or omitting pre-cooling of the compressed stream (at the expense of increased power consumption and increased cooling load on the heat exchanger 60). In such a case, the stream 49a leaving the compressor can flow directly to the heat exchanger 24 as shown in FIG. 18 or directly to the heat exchanger 60 as shown in FIG. If the expansion work machine is not used to expand any part of the high pressure feed gas, a compressor driven by an external power source, such as the compressor 59 shown by FIG. 20, may be used instead of the compressor 16. it can. In other cases, the compression of the stream is not considered reasonable at all, so the stream is a heat exchanger 60 shown in FIG. 21 and the dashed line device shown in FIGS. 1 and 3-16 (heat exchangers 24, It flows directly to the compressor 16 and the outflow cooler 25). If a heat exchanger 24 is not provided to heat the stream before the plant fuel gas (stream 48) is withdrawn, a utility to supply the necessary heat, as shown in FIGS. An additional heater 58 may be required to warm the fuel gas before consuming the fuel gas using a utility stream or another process stream. Since such factors as gas composition, plant size, desired by-product stream recovery level, and available equipment must all be taken into account, choices such as these usually must be evaluated on a per-application basis. Don't be.

In accordance with the present invention, the cooling of the feed and inlet gas streams to the LNG production section can be performed in a number of ways. In the processes of FIGS. 1, 3 and 6-9, the inlet gas stream 31 is cooled and condensed by the column liquid from the fractionating column 19 and the external refrigerant stream. 4, 5 and 10-14, the flash separator liquid is used for this purpose along with the external refrigerant stream. In FIGS. 15 and 16, column liquid and flushed separator liquid are used for this purpose along with an external refrigerant stream. 17-21, the inlet gas stream 31 is cooled using only the external refrigerant stream. However, as shown in FIGS. 4, 5, 10 and 11, a cold process stream could be used to cool some of the high pressure refrigerant (stream 71a). Furthermore, any stream that is colder than the stream or streams can be used. For example, a vapor side draw from the separator / adsorption tower 19 or fractionation tower 19 could be extracted and used for cooling. The use and distribution of column liquids and / or steam for process heat exchange, and the specific arrangement of heat exchangers for cooling inlet gas and feedstock gas, respectively, for specific applications and for specific heat exchange operations Must be evaluated with respect to the selection of process streams. The choice of cooling source will depend on a number of factors including, but not limited to, feed gas composition and conditions, plant size, heat exchanger size, potential cooling source temperature, and the like. Those skilled in the art can use any combination of the above cooling sources or cooling methods to obtain the desired feed stream temperature or temperatures.

Furthermore, the additional external cooling to supply the inlet gas stream and feed stream to the LNG production section can be performed in various ways. 1 and 3-21, it is assumed that single-component refrigerant boils for high-level external cooling and multi-component refrigerant boils for low-level external cooling, and single-component refrigerant is used. The multicomponent refrigerant stream is then precooled. Alternatively, both high level cooling and low level cooling can be performed using single component refrigerants with sequentially lower boiling points (ie, cascade cooling) or single component refrigerants with sequentially lower evaporating pressures. Alternatively, it can be carried out using a multi-component refrigerant stream with each composition adjusted to provide the required cooling temperature using both high and low level cooling. it can. The choice of method to provide external cooling will depend on many factors such as, but not limited to, feed gas composition and conditions, plant size, compressor driver size, heat exchanger size, ambient heat sink temperature, etc. Not. One skilled in the art can use any combination of the methods for providing external cooling described above to obtain the desired feed stream temperature or temperatures.

A condensed liquid stream leaving the heat exchanger 60 (stream 49 in FIGS. 1, 6 and 8, FIGS. 3, 4,
7 and 9-16 stream 49d, FIGS. 5, 19 and 20 stream 49b, FIG. 17 stream 49e
The supercooling of stream 49c in FIG. 18 and stream 49a) in FIG. 21 reduces or eliminates the amount of flash steam that can be generated while expanding the stream to the operating pressure of LNG storage tank 62. This typically reduces specific power consumption for producing LNG by eliminating the need for flash gas compression. However, in some situations, reducing the capital cost of equipment by using flash gas compression or other means to dispose of all possible flash gas and by reducing the size of the heat exchanger 60 Is preferred.

Although individual stream expansions are represented by specific expansion devices, different expansion means can be used depending on the case. For example, to ensure expansion work of a substantially condensed feed stream (stream 35a in FIGS. 1, 3, 6 and 7) or an intermediate pressure reflux stream (stream 39 in FIGS. 1, 6 and 8) depending on conditions Can do. In addition, heat exchanger 60
The supercooled liquid stream leaving the stream (stream 49 in FIGS. 1, 6 and 8; stream 49d in FIGS. 3, 4, 7 and 9-16; stream 49b in FIGS. 5, 19 and 20; stream 49e in FIG. 17; An isoenthalpy flash expansion can be used in place of the expansion work of stream 49c as well as stream 49a) of FIG. 21, but more subcooling in heat exchanger 60 to prevent flash vapor formation during expansion Or it may be necessary to add flash vapor compression or other means to treat the generated flash steam. Similarly, an isenthalpy flash expansion can be used in place of the expansion work of the supercooled high pressure refrigerant stream (stream 71c of FIGS. 1 and 3-21) leaving the heat exchanger 60, thereby compressing the refrigerant. However, power consumption increases.

  Having described what are considered to be preferred embodiments of the invention, those skilled in the art may make other or further modifications to the invention without departing from the spirit of the invention, which is limited in the scope of the appended claims. Could be adapted to various conditions, feed types or other requirements.

[Aspect of the Invention]
[1]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) expanding the cooled natural gas stream to the intermediate pressure;
(3) direct the expanded cooled natural gas stream into the distillation column, where
Separating the stream into a volatile residue gas fraction containing a majority of the methane and light components and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane;
(4) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
(5) dividing the condensing part into at least two parts, the condensate stream and the liquid stream;
And form; and
(6) The liquid stream is fed into the distillation column as an upper feed to the distillation column.
Turn to
This is an improvement.
[2]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) The partially condensed natural gas stream is separated into at least one steam
Providing a ream and a first liquid stream;
(3) expanding the steam stream to the intermediate pressure;
(4) expanding the first liquid stream to the intermediate pressure;
(5) At least the expanded steam stream and the expanded first stream are distilled.
Where the stream is relatively volatile containing a volatile residue gas fraction containing a majority of the methane and lighter components and a hydrocarbon component heavier than the methane. Separate into less likely fractions;
(6) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
(7) dividing the condensed portion into at least two portions, the condensed stream and the second liquid
Forming a stream; and
(8) The distillation column with the second liquid stream as an upper feed to the distillation column
Orient inward
This is an improvement.
[3]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is divided into at least a first gas stream and a second gas stream.
Split into reams;
(3) cooling the first gas stream to condense substantially all of it and then expand it;
Intermediate pressure;
(4) expanding the second gas stream to the intermediate pressure;
(5) a first stream of this expanded substantially condensed gas and a second stream of expanded gas.
Directing a stream into a distillation column, wherein the stream contains a volatile residue gas fraction containing a majority of the methane and light components and a majority of the hydrocarbon components heavier than the methane. Separating into relatively less volatile fractions; and
(6) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof and
Form a compressed stream
This is an improvement.
[4]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) The partially condensed natural gas stream is separated and the vapor and liquid streams are separated.
Providing a ream;
(3) converting the steam stream into at least a first gas stream and a second gas stream;
To divide;
(4) The first gas stream is cooled to substantially condense it, and then expanded.
Intermediate pressure;
(5) expanding the second gas stream to the intermediate pressure;
(6) expanding the liquid stream to the intermediate pressure;
(7) a first stream of the expanded substantially condensed gas; a second stream of the expanded gas;
And a stream of the expanded liquid into a distillation column, wherein the stream is divided into a volatile residue gas fraction containing a majority of the methane and light components, and heavier than the methane. Separating into a relatively less volatile fraction containing the majority of the hydrocarbon component; and
(8) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof and
Form a compressed stream
This is an improvement.
[5]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas under pressure to condense at least a portion thereof to form a condensed stream.
Forming; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) Separating this partially condensed natural gas stream to produce a vapor stream and a liquid stream.
And provide
(3) converting the steam stream into at least a first gas stream and a second gas stream;
To divide;
(4) mixing the first gas stream with at least a portion of the liquid stream and mixing
Form a stream;
(5) The mixed stream is cooled to substantially condense it, and then expanded to intermediate
Pressure;
(6) expanding the second gas stream to the intermediate pressure;
(7) all the remaining portion of the liquid stream is expanded to the intermediate pressure;
(8) an expanded substantially condensed mixed stream, a second stream of expanded gas;
Directing the remainder of the liquid stream into a distillation column, wherein the stream is divided into a volatile residue gas fraction containing a majority of the methane and light components, and a hydrocarbon component heavier than the methane. Separating into relatively less volatile fractions containing the majority of
(9) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof and
Form a compressed stream
This is an improvement.
[6]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is divided into at least a first gas stream and a second gas stream.
Split into reams;
(3) cooling the first gas stream to condense substantially all of it and then expand it;
Intermediate pressure;
(4) expanding the second gas stream to the intermediate pressure;
(5) a first stream of the expanded substantially condensed gas and a second stream of the expanded gas.
Directing a stream into the distillation column, where the stream is a volatile residue gas fraction containing the majority of the methane and light components and a comparison containing the majority of the hydrocarbon components heavier than the methane. Separating into fractions of low volatility;
(6) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
(7) dividing the condensing part into at least two parts, the condensate stream and the liquid stream;
And form; and
(8) The liquid stream is routed into the distillation column as an upper feed to the distillation column.
Turn to
This is an improvement.
[7]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to obtain a vapor stream and a first liquid stream;
To provide a trim;
(3) The gas stream is at least a first gas stream and a second gas stream.
To divide;
(4) The first gas stream is cooled to substantially condense it, and then expanded.
Intermediate pressure;
(5) expanding the second gas stream to the intermediate pressure;
(6) expanding the first liquid stream to the intermediate pressure;
(7) a first stream of the expanded substantially condensed gas, a second stream of the expanded gas.
Directing the stream and the expanded first liquid stream into a distillation column, wherein the stream comprises a volatile residue gas fraction containing a majority of the methane and light components, and from the methane Separating into relatively less volatile fractions containing the majority of the heavy hydrocarbon components;
(8) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
(9) dividing the condensed portion into at least two portions, the condensed stream and the second liquid
Forming a stream; and
(10) directing the second liquid stream into the distillation column as an upper feed to the distillation column
This is an improvement.
[8]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas under pressure to condense at least a portion thereof to form a condensed stream.
Forming; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) The partially condensed natural gas stream is separated and the vapor stream and the first liquid are separated.
Providing a body stream;
(3) converting the steam stream into at least a first gas stream and a second gas stream;
To divide;
(4) mixing the first gas stream with at least a portion of the first liquid stream;
Forming a mixed stream;
(5) Cool the mixed stream to condense substantially all of it and then expand it to intermediate
Pressure;
(6) expanding the second gas stream to the intermediate pressure;
(7) all the remaining portion of the first liquid stream is expanded to the intermediate pressure;
(8) the expanded substantially condensed mixed stream, the expanded gas second stream;
And a remaining portion of the first liquid stream into a distillation column, wherein the stream is divided into a volatile residue gas fraction containing a majority of the methane and light components, and the methane. Separating into a relatively less volatile fraction containing the majority of the heavier hydrocarbon components;
(9) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
(10) dividing the condensing portion into at least two portions to form the condensate stream and a second liquid stream; and
(11) directing the second liquid stream into the distillation column as an upper feed to the distillation column
This is an improvement.
[9]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) expanding the cooled natural gas stream to the intermediate pressure;
(3) separating the expanded cooled natural gas stream to produce a vapor stream and a liquid stream;
And provide
(4) expanding the liquid stream to a low intermediate pressure;
(5) directing the expanded liquid stream into a distillation column, wherein the stream is
Separating into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(6) mixing the more volatile distillation stream with the vapor stream to produce the methane
Forming a volatile residue gas fraction containing a majority of and light components;
(7) cooling the volatile residue gas fraction under pressure, condensing at least a portion thereof,
Form a condensed stream
This is an improvement.
[10]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) The partially condensed natural gas stream is separated and the first steam stream and the second
A single liquid stream;
(3) expanding the first steam stream to an intermediate pressure;
(4) separating the expanded first steam stream, the second steam stream and the second liquid
Providing a body stream;
(5) expanding the second liquid stream to a low intermediate pressure;
(6) expanding the first liquid stream to the low intermediate pressure;
(7) steaming the expanded second liquid stream and the expanded first liquid stream;
Directed into a distillation column, where the stream is separated into a more volatile distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(8) mixing the more volatile steam distillation stream with the second steam stream;
Forming a volatile residue gas fraction containing a majority of the methane and light components; and
(9) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof,
Form a condensed stream
This is an improvement.
[11]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then applied to the contact device.
Directing thereby forming a volatile residue gas fraction containing a majority of the methane and light components and a first liquid stream;
(3) directing the first liquid stream into a distillation column, wherein the stream is
Separating a highly volatile steam distillation stream and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane;
(4) The more volatile steam distillation stream is sufficient to condense at least a portion thereof.
Cool to minutes, thereby forming a second liquid stream;
(5) at least a portion of the expanded cooled natural gas stream is disposed within the contact device.
In full contact with at least a portion of the second liquid stream; and
(6) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof,
Form a condensed stream
This is an improvement.
[12]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to obtain a vapor stream and a first liquid;
Providing a body stream;
(3) The vapor stream is expanded to an intermediate pressure and then directed to the contact device,
Thereby forming a volatile residue gas fraction containing a majority of the methane and light components and a second liquid stream;
(4) expanding the first liquid stream to the intermediate pressure;
(5) The second liquid stream and the expanded first liquid stream are placed in a distillation column.
Directing, where the stream is a more volatile steam distillation stream and the methane
Separating into a relatively less volatile fraction containing the majority of the heavier hydrocarbon components;
(6) The more volatile steam distillation stream is sufficient to condense at least a portion thereof.
Cool to minutes, thereby forming a third liquid stream;
(7) at least a portion of the expanded steam stream in the contact device is the third
In full contact with at least a portion of the liquid stream; and
(8) The volatile residue gas fraction is cooled under pressure to condense at least a portion thereof,
Thus forming the condensed stream
This is an improvement.
[13]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then applied to the contact device.
Directing, thereby forming a first vapor stream and a first liquid stream;
(3) directing the first liquid stream to a distillation column, wherein the stream is
Separating into a highly volatile steam distillation stream and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane;
(4) The more volatile steam distillation stream is sufficient to condense at least a portion thereof.
To form a second vapor stream and a second liquid stream; (5) a portion of the second liquid stream as the top feed to the distillation column;
Direct to the column; and
(6) at least a portion of the expanded cooled natural gas stream in the contact device;
In full contact with at least a portion of the remaining portion of the second liquid stream;
(7) mixing the first vapor stream with the second vapor stream to produce a large amount of methane;
Forming a volatile residue gas fraction containing portions and light components; and
(8) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof,
Form a condensed stream
This is an improvement.
[14]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) This partially condensed natural gas stream is separated into a first steam stream and a first
A liquid stream of;
(3) The first steam stream is expanded to an intermediate pressure and then directed to the contact device
Thereby forming a second vapor stream and a second liquid stream;
(4) expanding the first liquid stream to the intermediate pressure;
(5) the second liquid stream and the expanded first liquid stream to a distillation column.
Directing, where the stream is separated into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(6) The more volatile steam distillation stream is sufficient to condense at least a portion thereof.
Cooling to minutes, thereby forming a third vapor stream and a third liquid stream;
(7) Distilling part of the third liquid stream as an upper feed to the distillation column
Direct to the column;
(8) at least a portion of the expanded first steam stream in the contact device;
In full contact with at least a portion of the remaining portion of the third liquid stream;
(9) mixing the second vapor stream with the third vapor stream to produce a large amount of methane.
Forming a volatile residue gas fraction containing portions and light components; and
(10) The volatile residue gas fraction is cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream.
This is an improvement.
[15]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then applied to the contact device.
Directing thereby forming a volatile residue gas fraction containing a majority of the methane and light components and a first liquid stream;
(3) heating the first liquid stream and then directing it to a distillation column, where the
Separating the stream into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(4) The more volatile steam distillation stream is sufficient to condense at least a portion thereof.
Cool to minutes, thereby forming a second liquid stream;
(5) at least a portion of the expanded cooled natural gas stream in the contact device
In full contact with at least a portion of the second liquid stream; and
(6) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof,
Form a condensed stream
This is an improvement.
[16]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to obtain a vapor stream and a first liquid;
Providing a body stream;
(3) The vapor stream is expanded to an intermediate pressure and then directed to the contact device,
Thereby forming a volatile residue gas fraction containing a majority of the methane and light components and a second liquid stream;
(4) heating the second liquid stream;
(5) expanding the first liquid stream to the intermediate pressure;
(6) steaming the heated second liquid stream and the expanded first liquid stream;
Directing to a distillation column, where the stream is separated into a more volatile steam distillation stream and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane;
(7) The more volatile steam distillation stream is sufficient to condense at least a portion thereof.
Cool in minutes, thereby forming a third liquid stream;
(8) at least a portion of the expanded steam stream in the contact device is the third
Complete contact with at least a portion of the liquid stream of; and
(9) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
Forming the condensed stream by
This is an improvement.
[17]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then applied to the contact device.
Directing, thereby forming the first vapor stream and the first liquid stream; (3) heating the first liquid stream and then directing it to a distillation column, where the
Separating the stream into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(4) The more volatile steam distillation stream is sufficient to condense at least a portion thereof.
To form a second vapor stream and a second liquid stream; (5) a portion of the second liquid stream as the top feed to the distillation column;
Direct to the column;
(6) at least a portion of the expanded cooled natural gas stream in the contact device;
In full contact with at least a portion of the remaining portion of the second liquid stream;
(7) mixing the first vapor stream with the second vapor stream to produce a large amount of methane;
Forming a volatile residue gas fraction containing portions and light components; and
(8) The volatile residue gas fraction is cooled under pressure to condense at least a portion thereof,
Thus forming the condensed stream
This is an improvement.
[18]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to condense a portion thereof;
(2) The partially condensed natural gas stream is separated and the first steam stream and the second
A single liquid stream;
(3) inflating the first gas stream to an intermediate pressure and then directing it to the contact device;
This forms a second vapor stream and a second liquid stream;
(4) heating the second liquid stream;
(5) expanding the first liquid stream to the intermediate pressure;
(6) Distilling the heated second liquid stream and the expanded first liquid stream
Directing to a column, where the stream is separated into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(7) The more volatile steam distillation stream is sufficient to condense at least a portion thereof.
Cooling in minutes, thereby forming a third vapor stream and a third liquid stream
Do;
(8) The distillation using a portion of the third liquid stream as an upper feed to the distillation column.
Direct to the column;
(9) at least a portion of the expanded first vapor stream is previously removed in the contact device;
In full contact with at least a portion of the remaining portion of the third liquid stream;
(10) mixing the second vapor stream with the third vapor stream to form a volatile residue gas fraction containing a majority of the methane and light components; and
(11) Cooling the volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream
This is an improvement.
[19]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then placed on the distillation column
Directed to a column feed position where the stream is divided into a more volatile steam distillation stream and a relatively less volatile fraction containing a majority of hydrocarbon components heavier than the methane. To separate;
(3) the distillation of the steam distillation stream below the expanded cooled natural gas stream
Withdrawn from the column region and cooled sufficiently to condense at least a portion thereof, thereby forming a vapor stream and a liquid stream;
(4) at least a portion of the expanded cooled natural gas stream is passed through the distillation column.
In full contact with at least a portion of the liquid stream;
(5) Mixing the steam stream with the more volatile steam distillation stream,
Forming a volatile residue gas fraction containing a majority of the tongue and light components; and
(6) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof,
Form a condensed stream
This is an improvement.
[20]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to produce a first steam stream and a second steam stream;
A single liquid stream;
(3) The first vapor stream and the first liquid stream are expanded to an intermediate pressure.
;
(4) steaming the expanded first vapor stream and the expanded first liquid stream;
Directing the intermediate column feed on the distillation column where the stream contains a more volatile steam distillation stream and a relatively less volatile fraction containing most of the hydrocarbons heavier than the methane Separated into;
(5) A steam distillation stream is placed in the distillation column below the expanded first steam stream.
Cooling out enough to condense at least a portion of
Forming a second vapor stream and a second liquid stream;
(6) at least a portion of the expanded first vapor stream in the distillation column.
In full contact with at least a portion of the second liquid stream;
(7) mixing the second steam stream with the more volatile steam distillation stream;
Forming a volatile residue gas fraction containing a majority of the methane and light components; and
(8) The volatile residue gas fraction is cooled under pressure to condense at least a portion thereof,
Thus forming the condensed stream
This is an improvement.
[21]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then the middle of the distillation column
Directed to column feed position, where the stream separates into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane Do;
(3) The distillation stream below the expanded cooled natural gas stream is expanded from the steam distillation stream.
Extracted from the area of the ram and cooled sufficiently to condense at least a portion thereof, thereby forming a vapor stream and a liquid stream;
(4) using a portion of the liquid stream as another feed to the distillation column,
Feeding the distillation column at a feed position in substantially the same region as the vapor distillation stream is withdrawn;
(5) at least a portion of the expanded cooled natural gas stream is passed through the distillation column.
Fully contacting at least a portion of the remaining portion of the liquid stream; and
(6) Mixing the steam stream with the more volatile steam distillation stream,
Forming a volatile residue gas fraction containing a majority of the tongue and light components; and
(7) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof,
Form a condensed stream
This is an improvement.
[22]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to produce a first steam stream and a second steam stream;
A single liquid stream;
(3) The first vapor stream and the first liquid stream are expanded to an intermediate pressure.
;
(4) steaming the expanded first vapor stream and the expanded first liquid stream;
Directing the middle column feed position of the distillation column where the stream is a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane. Separated into;
(5) A steam distillation stream is placed in the distillation column below the expanded first steam stream.
Withdrawn from the area of the tank and cooled sufficiently to condense a portion thereof, thereby forming a second vapor stream and a second liquid stream;
(6) at the feed position in substantially the same region as withdrawing the steam distillation stream, the second
A portion of the liquid stream is fed to the distillation column as another feed to the distillation column
;
(7) at least a portion of the expanded first vapor stream in the distillation column.
In full contact with at least a portion of the remaining portion of the second liquid stream;
(8) mixing the second steam stream with the more volatile steam distillation stream;
Forming a volatile residue gas fraction containing a majority of the methane and light components; and
(9) The volatile residue gas fraction is cooled under pressure to condense at least a portion thereof,
Thus forming the condensed stream
This is an improvement.
[23]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then the middle of the distillation column
Directed to column feed position, where the stream is separated into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane Do;
(3) The distillation stream below the expanded cooled natural gas stream is expanded from the steam distillation stream.
Extracted from the area of the ram and cooled sufficiently to condense at least a portion thereof, thereby forming a vapor stream and a liquid stream;
(4) at least a portion of the expanded cooled natural gas stream is pretreated in the distillation column;
Complete contact with at least a portion of the liquid stream;
(5) the liquid distillation stream is positioned above the region from which the steam distillation stream is withdrawn.
Withdrawing from the chamber, where the liquid distillation stream is heated and then redirected to the distillation column as another feed to the distillation column at a position below the region from which the steam distillation stream is withdrawn;
(6) Mixing the steam stream with the more volatile steam distillation stream,
Forming a volatile residue gas fraction containing a majority of the tongue and light components; and
(7) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof,
Form a condensed stream
This is an improvement.
[24]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to produce a first steam stream and a second steam stream;
A single liquid stream;
(3) The first vapor stream and the first liquid stream are expanded to an intermediate pressure.
;
(4) Distilling the expanded first vapor stream and the expanded first liquid stream
Directing the middle column feed position of the column where the stream is a more volatile steam distillation stream and a relatively less volatile fraction containing a majority of hydrocarbon components heavier than the methane; To separate;
(5) A steam distillation stream is placed in the distillation column below the expanded first steam stream.
Withdrawn from the area of the tank and cooled sufficiently to condense at least a portion thereof, thereby forming a second vapor stream and a second liquid stream;
(6) at least a portion of the expanded first vapor stream in the distillation column,
In full contact with at least a portion of the second liquid stream;
(7) The liquid distillation stream is advanced in a position above the region where the steam distillation stream is withdrawn.
Withdrawing from the distillation column, where the liquid distillation stream is heated and then redirected to the distillation column as another feed to the distillation column at a position below the region from which the steam distillation stream is withdrawn;
(8) mixing the second steam stream with the more volatile steam distillation stream;
Forming a volatile residue gas fraction containing a majority of the methane and light components; and
(9) The volatile residue gas fraction is cooled under pressure to condense at least a portion thereof,
More form the condensed stream
This is an improvement.
[25]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) The cooled natural gas stream is expanded to an intermediate pressure and then the middle of the distillation column
Directed to column feed position, where the stream separates into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane Do;
(3) Vapor steam from the region of the distillation column below the expanded cooled natural gas stream.
A distillate stream is withdrawn and cooled sufficiently to condense at least a portion thereof, thereby forming a vapor stream and a liquid stream;
(4) using a portion of the liquid stream as another feed to the distillation column,
Feeding the distillation column at a feed position in substantially the same region as the vapor distillation stream is withdrawn;
(5) at least a portion of the expanded cooled natural gas stream is passed through the distillation column.
Complete contact with at least a portion of the remaining portion of the liquid stream;
(6) The steam stream is placed at a position above the region where the steam distillation stream is withdrawn.
Withdrawing from the distillation column where the liquid distillation stream is heated and then redirected to the distillation column as another feed to the distillation column at a position below the region from which the vapor distillation stream is withdrawn;
(7) Mixing the steam stream with the more volatile steam distillation stream,
Forming a volatile residue gas fraction containing a majority of the tongue and light components; and
(8) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof,
Form a condensed stream
This is an improvement.
[26]
A liquefaction method for natural gas streams containing methane and hydrocarbon components heavier than methane.
What
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to produce a first steam stream and a second steam stream;
A single liquid stream;
(3) The first vapor stream and the first liquid stream are expanded to an intermediate pressure.
;
(4) steaming the expanded first vapor stream and the expanded first liquid stream;
Directing the middle column feed position of the distillation column where the stream is a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane. Separated into;
(5) a steam distillation stream from a region of the distillation column below the expanded first steam stream;
Withdrawing the stream and cooling it sufficiently to condense at least a portion thereof, thereby forming a second vapor stream and a second liquid stream;
(6) A distillation column at a feed position in substantially the same region as withdrawing the steam distillation stream.
Feeding a portion of the second liquid stream to the distillation column as another feed to
(7) at least a portion of the expanded first vapor stream in the distillation column,
In full contact with at least a portion of the remaining portion of the second liquid stream;
(8) Liquid distillation from the distillation column at a position above the region from which the steam distillation stream is withdrawn.
Withdrawing a stream where the liquid distillation stream is heated and then redirected to the distillation column as another feed to the distillation column at a position below the region from which the steam distillation stream is withdrawn;
(9) mixing the second vapor stream with the more volatile vapor distillation stream;
Forming a volatile residue gas fraction containing a majority of the methane and light components; and
(10) Cooling the volatile residue gas fraction under pressure and condensing at least a portion thereof, thereby forming the condensed stream
This is an improvement.
[27]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) expanding the cooled natural gas stream to the intermediate pressure;
(3) directing the expanded cooled natural gas stream to a distillation column, where the
Reams are separated into a volatile residue gas fraction containing the majority of the methane and light components and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane. ;as well as
(4) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof,
Form a condensed stream
This is an improvement.
[28]
A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) the natural gas stream is cooled under pressure to condense at least a portion of
Forming a stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to at least a vapor stream;
And liquid;
(3) expanding the steam stream to an intermediate pressure;
(4) expanding the liquid stream to an intermediate pressure;
(5) Distill at least the expanded vapor stream and the expanded liquid stream
Directed to a column, wherein the stream is relatively volatile containing a volatile residue gas fraction containing a majority of the methane and lighter components and a hydrocarbon component heavier than the methane. Separated into low fractions of; and
(6) The volatile residue gas fraction is cooled under pressure to condense at least a portion thereof.
Consists essentially of each processing step, forming a more condensed stream
This is an improvement.
[29]
The volatile residue gas fraction is compressed and then cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream 3, 4, 5, 11, 12, 13, 14, 15 16, 17, 18, 19, 20, 21, 22, 23, 24, 25, 26, 27 or 28.
[30]
(1) The volatile residue gas fraction is compressed and then cooled under pressure to at least partially condense it.
Shrink; and
(2) dividing the condensing part into at least two parts, whereby the condensate stream and
The improvement according to 1 or 6, which forms a liquid stream.
[31]
(1) The volatile residue gas fraction is compressed and then cooled under pressure to at least partially condense it.
Shrink; and
(2) dividing the condensing part into at least two parts, whereby the condensate stream and
9. The improvement of 2, 7 or 8 forming a second liquid stream.
[32]
10. The improvement of 9, wherein the more volatile steam distillation stream is compressed and then mixed with the steam stream to form a volatile residue gas fraction containing a majority of the methane and light components.
[33]
11. The more volatile vapor distillation stream is compressed and then mixed with the second vapor stream to form a volatile residue gas fraction containing a majority of the methane and light components. Improvements.
[34]
The volatile residue gas fraction is heated, compressed, and then cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream, 3, 4, 5, 11, 12, 13, 14, 15, 16, 17, 18, 19, 20, 21, 22, 23, 24, 25
, 26, 27 or 28.
[35]
(1) The volatile residue gas fraction is heated, compressed, then cooled under pressure to at least its
Condense part; and
(2) dividing the condensing part into at least two parts, whereby the condensate stream and
The improvement according to 1 or 6, which forms a liquid stream.
[36]
(1) The volatile residue gas fraction is heated, compressed, then cooled under pressure to at least its
Condense part; and
(2) dividing the condensing part into at least two parts, whereby the condensate stream and
9. Improvement according to 2, 7 or 8, forming a liquid stream.
[37]
Heating, compressing and cooling the more volatile steam distillation stream and then mixing with the steam stream to form the volatile residue gas component containing a majority of the methane and light components; The improvement according to 9.
[38]
The more volatile vapor distillation stream is heated, compressed, cooled, and then mixed with the second vapor stream to remove the volatile residue gas component containing the majority of the methane and light components. The improvement according to 10, which is formed.
[39]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18, 19, 20, 21, 22, 23 containing components 24, 25, 26, 27, 28, 29, 30, 31, 32, 33, 34, 35, 36, 37 or 38.
[40]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18, 19, 20, 21, 22, 23 containing components 24, 25, 26, 27, 28, 29, 30, 31, 32, 33, 34, 35, 36, 37 or 38.
[41]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) One that receives the natural gas stream and is cooperatively linked to cool under pressure
The above second heat exchange means;
(2) receiving the expanded natural gas stream and expanding it to the intermediate pressure;
A second expansion means connected to the second heat exchange means;
(3) a distillation column coupled to receive the expanded cooled natural gas stream;
The distillation column is divided into a volatile residue gas fraction containing most of the methane and light components and a relatively less volatile fraction containing most of the hydrocarbons heavier than the methane. Adapted to separate streams;
(4) the first heat coupled to the distillation column to receive the volatile residue gas fraction.
An exchange means, the first heat exchange means is adapted to cool the residual gas fraction under pressure to condense at least a portion thereof;
(5) receiving the condensed part and dividing it into at least two parts, thereby
A dividing means connected to the first heat exchange means for forming a condensed stream and a liquid stream; the dividing means is further connected to the distillation column to distill the liquid stream as an upper feed to the distillation column; Directed to the column; and
(6) controlling the amount and temperature of the feed stream to the distillation column to a temperature that is controlled.
Control means adapted to maintain the temperature at the top of the distillation column, whereby most of the hydrocarbon components heavier than the methane are recovered in a relatively less volatile fraction
It is an improvement point to include.
[42]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and (b) receiving and expanding the condensed stream to form the liquefied natural gas stream at a low pressure.
In the apparatus having a first expansion means coupled to the first heat exchange means for forming, the apparatus comprises:
(1) Accept the natural gas stream and cool it under pressure sufficiently to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving the partially condensed natural gas stream and receiving the vapor stream and the first liquid stream;
A second expansion means coupled to the second heat exchange means for separation into a stream;
(3) The separation means for receiving the vapor stream and expanding it to an intermediate pressure
A second expansion means coupled to the
(4) receiving the first liquid stream and expanding it to the intermediate pressure before
Third expansion means coupled to the separating means;
(5) receiving the expanded vapor stream and the expanded first liquid stream;
A distillation column connected to the volatile residue gas fraction containing most of the methane and light components, and a relatively volatile residue containing most of the hydrocarbon components heavier than the methane. Adapted to separate the stream into less likely fractions; and
(6) the first heat coupled to the distillation column to receive the volatile residue gas fraction.
An exchange means, wherein the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof;
(7) receiving the condensing part and dividing it into at least two parts, thereby
A dividing means connected to the first heat exchange means to form a ream and the liquid stream, the dividing means is further connected to the distillation column, and the second liquid stream is connected to the upper part of the distillation column. Directing to the distillation column as feed; and
(8) Control the amount and temperature of the feed stream to the distillation column to
Control means adapted to maintain the top temperature of the distillation column and thereby recover the majority of the hydrocarbon components heavier than the methane to the relatively less volatile fraction
The improvement is to include.
[43]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and (b) receiving and expanding the condensed stream to low pressure to form the liquefied natural gas stream.
In the apparatus having a first expansion means coupled to the first heat exchange means for forming, the apparatus comprises:
(1) One that receives the natural gas stream and is cooperatively linked to cool under pressure
The above second heat exchange means;
(2) receiving the cooled natural gas stream and at least the first gas stream and the second gas stream;
A dividing means connected to the second heat exchange means for dividing into a stream;
(3) receiving the first gas stream and cooling it sufficiently to substantially condense it;
A third heat exchange means connected to said dividing means for
(4) receiving the substantially condensed first gas stream and expanding it to produce an intermediate pressure;
A second expansion means coupled to the third heat exchange means to
(5) receiving the second gas stream and expanding it to an intermediate pressure to expand it.
A third expansion means connected to the split means;
(6) the expanded substantially condensed first gas stream and the expanded second gas stream;
A distillation column coupled to receive a stream, the distillation column comprising a stream, a volatile residue gas fraction containing a majority of the methane and light components, and a hydrocarbon component heavier than the methane. Adapted to separate into a relatively less volatile fraction containing the majority of
(7) the first heat coupled to the distillation column to receive the volatile residue gas fraction.
An exchange means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream; and
(8) controlling the amount and temperature of the feed stream to the distillation column to
Control means adapted to recover the majority of the hydrocarbon components heavier than methane in the relatively low-volatile fraction by maintaining the temperature at the top of the column at a certain temperature
The improvement is to include.
[44]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and (b) receiving and expanding the condensed stream to form the liquefied natural gas stream at a low pressure.
In the apparatus having a first expansion means coupled to the first heat exchange means for forming, the apparatus comprises:
(1) receiving the natural gas stream and cooling under pressure sufficient to partially condense
One or more second heat exchanging means that are cooperatively coupled to each other;
(2) receiving the partially condensed natural gas stream to receive a vapor stream and a liquid stream;
Separating means coupled to the second heat exchange means for separation into
(3) receiving the vapor stream, which is at least a first gas stream and a second gas;
Dividing means connected to said separating means for dividing into streams;
(4) Cool sufficiently to receive and substantially condense the first gas stream.
A third heat exchange means connected to said dividing means for
(5) receiving the substantially condensed first gas stream and expanding it to produce an intermediate pressure;
A second expansion means coupled to the third heat exchange means to
(6) receiving the second gas stream and expanding it to the intermediate pressure before
Third expansion means coupled to the dividing means;
(7) receiving the liquid stream and expanding the same to obtain the intermediate pressure
A fourth expansion means coupled to the means;
(8) the expanded substantially condensed first gas, the expanded second gas stream;
A distillation column coupled to receive the expanded liquid stream, the distillation column comprising the stream, a volatile residue gas fraction containing a majority of the methane and light components, and heavier than the methane. Adapted to separate into a relatively less volatile fraction containing the majority of the hydrocarbon components of
(9) the first heat coupled to the distillation column to receive the volatile residue gas fraction.
An exchange means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream; and
(10) controlling the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, thereby allowing most of the hydrocarbon components heavier than the methane to Control means adapted to collect in relatively volatile fractions
Is an improvement.
[45]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and (b) receiving and expanding the condensed stream to a low pressure, wherein the liquefied natural gas stream
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) The natural gas stream is received and cooled under sufficient pressure to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving said partially condensed natural gas stream, which is converted into a vapor stream and a liquid;
Separation means coupled to said second heat exchange means for separation into a stream;
(3) receiving the steam stream, which is converted into a first gas stream and a second gas stream;
Dividing means connected to said separating means for dividing into;
(4) receiving the first gas stream and at least a portion of the liquid stream;
A mixing means connected to the dividing means and the separating means to mix them to form a mixed stream;
(5) To receive the mixed stream and cool sufficiently to substantially condense it
Third heat exchange means coupled to the mixing means;
(6) receiving the substantially condensed mixed stream and expanding it to an intermediate pressure
Second expansion means connected to said third heat exchange means for;
(7) receiving the second gas stream and expanding it to the intermediate pressure before
A third expansion means connected to the dividing means;
(8) Receiving all the remaining part of the liquid stream and expanding it to produce the intermediate pressure
A fourth expansion means coupled to the separation means to
(9) the expanded substantially condensed mixed stream, the expanded second gas stream;
And a distillation column coupled to receive the expanded residual portion of the liquid stream.
Ram, the distillation column is a volatile residue gas containing most of the methane and light components
Adapted to separate the stream into a fraction and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane;
(10) The first heat exchange means connected to the distillation column to receive the volatile residue gas fraction, the first heat exchange means, the volatile residue gas fraction under pressure. Adapted to cool and condense at least a portion thereof, thereby forming said condensed stream; and
(11) Control the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, thereby removing most of the hydrocarbon components heavier than the methane. Control means adapted to collect in said relatively low-volatile fraction
The improvement is to include.
[46]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and (b) receiving and expanding the condensed stream to a low pressure, wherein the liquefied natural gas stream
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) One that receives the natural gas stream and is cooperatively linked to cool under pressure
The above second heat exchange means;
(2) receiving the cooled natural gas stream, which is at least a first gas stream;
A first dividing means coupled to the second heat exchange means for dividing into a second gas stream;
(3) receiving the first gas stream and cooling it sufficiently to substantially condense it;
A third heat exchanging means coupled to the first dividing means for
(4) receiving the substantially condensed first gas stream and expanding it to produce an intermediate pressure;
A second expansion means coupled to the third heat exchange means to
(5) receiving the second gas stream and expanding it to the intermediate pressure before
Third expansion means connected to the first dividing means;
(6) the expanded substantially condensed first gas stream and the expanded second gas stream;
A distillation column coupled to receive a stream, the distillation means comprising a volatile residue gas fraction containing a majority of the methane and light components and a majority of the hydrocarbon components heavier than the methane; Adapted to separate the stream into relatively less volatile fractions containing;
(7) the first heat coupled to the distillation column to receive the volatile residue gas fraction.
An exchange means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof;
(8) receiving the condensing part and dividing it into at least two parts, thereby
Coupled to the first heat exchange means to form a condensed stream and a liquid stream.
The second dividing means, the second dividing means, is used as an upper feed to the distillation column.
Further connected to the distillation column to direct the liquid stream to the ram; and (9) controlling the amount and temperature of the feed stream to the distillation column to control the top temperature of the distillation column. Control means adapted to maintain a temperature and thereby recover most of the hydrocarbon components heavier than the methane to the relatively volatile fraction
The improvement is to include.
[47]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and (b) receiving and expanding the condensed stream to a low pressure, wherein the liquefied natural gas stream
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) The natural gas stream is received and cooled under sufficient pressure to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving said partially condensed natural gas stream, which is converted into a vapor stream and a liquid;
Separation means coupled to said second heat exchange means for separation into a stream;
(3) receiving the steam stream, which is converted into a first gas stream and a second gas stream;
First dividing means connected to said separating means for dividing into;
(4) accept the first gas stream and cool it sufficiently to condense it effectively
A third heat exchanging means coupled to the first dividing means for
(5) receiving the substantially condensed first gas stream and expanding it to produce an intermediate pressure;
A second expansion means coupled to the third heat exchange means to
(6) receiving the second gas stream and expanding it to the intermediate pressure before
Third expansion means connected to the first dividing means;
(7) receiving the first liquid stream and expanding it to the intermediate pressure before
A fourth expansion means connected to the separation means;
(8) the expanded substantially condensed first gas stream, the expanded second gas stream;
A distillation column coupled to receive the stream and the expanded first liquid stream;
Ram, the distillation column is a volatile residue gas containing most of the methane and light components
Adapted to separate the stream into a fraction and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane;
(9) the first heat coupled to the distillation column to receive the volatile residue gas fraction.
An exchange means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof;
(10) a second connected to the first heat exchange means for receiving the condensing portion and dividing it into at least two portions, thereby forming the condensate stream and the liquid stream; A dividing means, the second dividing means is further connected to the distillation column for directing the second liquid stream to the distillation column as an upper feed to the distillation column; and
(11) Control the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, thereby removing most of the hydrocarbon components heavier than the methane. Control means adapted to collect in said relatively low-volatile fraction
The improvement is to include.
[48]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) The natural gas stream is received and cooled under sufficient pressure to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving said partially condensed natural gas stream, which is converted into a vapor stream and a liquid;
Separation means coupled to said second heat exchange means for separation into a stream;
(3) receiving the steam stream, which is converted into a first gas stream and a second gas stream;
First dividing means connected to said separating means for dividing into;
(4) receiving at least a portion of the first gas stream and the first liquid stream;
Mixing means connected to the first dividing means and the separating means to mix them into a mixed stream;
(5) To receive the mixed stream and cool sufficiently to substantially condense it
Third heat exchange means coupled to the mixing means;
(6) receiving the substantially condensed mixed stream and expanding it to an intermediate pressure
A second expansion means connected to the third heat exchanger for;
(7) receiving the second gas stream and expanding it to the intermediate pressure before
Third expansion means connected to the first dividing means;
(8) Receiving all the remaining portion of the first liquid stream and expanding it to produce the intermediate pressure
A fourth expansion means coupled to the separation means to
(9) the expanded substantially condensed mixed stream, the expanded second gas stream;
And a swollen remaining portion of the first liquid stream coupled to receive
The distillation column is a volatile residue containing most of the methane and light components.
Adapted to separate the stream into a residue gas fraction and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane;
(10) The first heat exchange means connected to the distillation column for receiving the volatile residue gas fraction, the first heat exchange means cooling the volatile residue gas fraction under pressure. Adapted to condense at least some of it;
(11) Accept the condensed part and divide it into at least two parts, thereby
The first heat exchanger to form the condensed stream and the second liquid stream.
A second dividing means connected to the stage, the second dividing means further comprising the distillation column for directing the second liquid stream to the distillation column as an upper feed to the distillation column.
Connected to the ram; and
(12) Control the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, thereby increasing the hydrocarbon content heavier than the methane.
Control means adapted to recover a portion into said relatively less volatile fraction
The improvement is to include.
[49]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) accepting said natural gas stream and cooperatively connected to cool it under pressure.
One or more second heat exchange means;
(2) In order to receive the cooled natural gas stream and expand it to an intermediate pressure
Second expansion means coupled to the second heat exchange means;
(3) receiving the expanded cooled natural gas stream, which is converted into a vapor stream and a liquid stream;
Separation means coupled to said second expansion means for separation into a ream;
(4) receiving the liquid stream and expanding it to a low intermediate pressure
A third expansion means coupled to the means;
(5) a distillation column coupled to receive the expanded liquid stream, the distillation column;
Rum is adapted to separate the stream into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(6) receiving the steam stream and the more volatile steam distillation stream,
Mixing means coupled to the separation means and the distillation column to form a volatile residue gas fraction containing a majority of the methane and light components;
(7) the first heat exchange coupled to the mixing means for receiving the volatile residue gas fraction.
A conversion means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream; and
(8) controlling the amount and temperature of the feed stream to the distillation column to control the distillation column
Control means adapted to maintain a temperature at the top of the column at a temperature, thereby recovering a majority of the hydrocarbon components heavier than the methane into the relatively less volatile fraction
The improvement is to include.
[50]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) The natural gas stream is received and cooled under sufficient pressure to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving the partially condensed natural gas stream and converting it into a first steam stream;
And a first separation means coupled to the second heat exchange means for separation into a first liquid stream;
(3) receiving the first steam stream and expanding it to an intermediate pressure to expand it.
A second expansion means connected to one separation means;
(4) receiving the expanded first steam stream and combining it with the second steam stream;
Second separation means coupled to the second expansion means for separation into a liquid stream of: (5) receiving the second liquid stream and expanding it to a low intermediate pressure Previous
A third expansion means connected to the second separation means;
(6) To receive the first liquid stream and expand it to the low intermediate pressure
A fourth expansion means connected to the first separation means;
(7) receiving the expanded second liquid stream and the expanded first liquid stream;
A distillation column connected for storage, the distillation column comprising a more volatile steam distillation stream and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane. Adapted to separate the streams;
(8) receiving the second steam stream and the more volatile steam distillation stream;
Mixing means coupled to the second separation means and the distillation column to mix them to form a volatile residue gas fraction containing a majority of the methane and light components;
(9) the first heat exchange coupled to the mixing means for receiving the volatile residue gas fraction.
Conversion means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream; and
(10) controlling the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, so that most of the hydrocarbon components heavier than the methane are Control means adapted to collect in said relatively low volatile fraction
The improvement is to include.
[51]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) receiving said natural gas stream and cooperating to cool it under pressure
One or more second heat exchange means;
(2) Before receiving the cooled natural gas stream and expanding it to intermediate pressure
Second expansion means coupled to the second heat exchange means;
(3) Contact and separation coupled to receive the expanded cooled natural gas stream.
Means, said contact and separation means comprise at least one contact device for mixing liquid and vapor, separating said vapor and liquid after mixing and containing a majority of said methane and light components Separation means for forming a volatile residue gas fraction and a first liquid stream;
(4) A distillation column coupled to receive the first liquid stream, the distillation column
Is adapted to separate the stream into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(5) receiving the more volatile steam distillation stream and condensing at least a portion thereof;
A third heat exchange means connected to the distillation column to cool it sufficiently so as to form a second liquid stream;
(6) receiving the second liquid stream and reducing the expanded cooled natural gas stream;
The contact and separation means further coupled to the third heat exchange means such that at least a portion is in full contact with at least a portion of the second liquid stream in the contact device;
(7) The first connected to the contact and separation means to receive the volatile residue gas fraction.
One heat exchange means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream. Are; and
(8) controlling the amount and temperature of the feed to the contacting and separating means and the distillation column;
Adapted to maintain the top temperature of the contacting and separation means and the distillation column at a certain temperature, thereby recovering the majority of hydrocarbon components heavier than the methane in the relatively less volatile fraction. Control means
The improvement is to include.
[52]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) Accept the natural gas stream and cool it under pressure sufficiently to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving the partially condensed natural gas stream,
Separation means coupled to the second heat exchange means for separation into a liquid stream of
(3) The separation means for receiving the vapor stream and expanding it to an intermediate pressure
A second expansion means coupled to the
(4) contact and separation means coupled to receive the expanded vapor stream;
The contact and separation means includes at least one contact device for mixing the liquid and the vapor, separates the vapor and the liquid after mixing, and contains a majority of the methane and light components. Including separation means for forming a residual gas fraction and a second liquid stream;
(5) receiving the first liquid stream and expanding it to the intermediate pressure before
Third expansion means coupled to the separating means;
(6) To receive the second liquid stream and the expanded first liquid stream
A distillation column connected to the column, the distillation column separates the stream into a more volatile distillation stream and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane. Adapted to do;
(7) receiving the more volatile steam distillation stream and condensing at least a portion thereof;
A third heat exchange means coupled to the distillation column so as to be sufficiently cooled to thereby form a third liquid stream;
(8) receiving the third liquid stream and at least one of the expanded vapor stream;
Said contact and separation means further coupled to said third heat exchange means such that a portion is in full contact with at least a portion of said third liquid stream in said contact device;
(9) the first connected to the contacting and separating means for receiving the volatile residue gas fraction;
One heat exchange means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream. Are; and
(10) The amount and temperature of the feed stream to the contact and separation means and the distillation column
To maintain the top temperature of the contact and separation means and the distillation column at a certain temperature.
A control means adapted to recover a majority of the hydrocarbon components heavier than the methane into the relatively less volatile fraction
The improvement is to include.
[53]
A liquefaction unit for natural gas streams containing methane and hydrocarbon components heavier than methane.
What
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) receiving said natural gas stream and cooperating to cool it under pressure
One or more second heat exchange means;
(2) Before receiving the cooled natural gas stream and expanding it to intermediate pressure
Second expansion means coupled to the second heat exchange means;
(3) Contact and separation coupled to receive the expanded cooled natural gas stream.
Means, the contacting and separating means comprise at least one contact device for mixing the liquid and the vapor, separating the vapor and the liquid after mixing, and separating the first vapor stream and the liquid stream. Including separation means for forming;
(4) A distillation column coupled to receive the first liquid stream, the distillation column
Is adapted to separate the stream into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(5) receiving the more volatile steam distillation stream and condensing at least a portion thereof;
A third heat exchange means connected to the distillation column so as to cool it sufficiently so that it is cooled; (6) receiving the cooled more volatile vapor distillation stream and supplying it to the second steam The
Separation means coupled to said third heat exchange means for separation into a stream and a second liquid stream;
(7) receiving the second liquid stream, which is at least in the first part and the second part;
A dividing means connected to the separating means for dividing, the dividing means being further connected to the distillation column, wherein the first portion of the second liquid stream is fed to the distillation column as an upper feed to the distillation column. Supply;
(8) A cooled natural gas stream that has received and expanded the second portion of the second liquid stream.
Said contacting and separating means further coupled to said dividing means for bringing at least a portion of a segment into full contact with at least a portion of a second portion of said second liquid stream in said contacting device;
(9) receiving and mixing the first steam stream and the second steam stream;
Mixing means coupled to the contacting and separating means and the separating means to form a volatile residue gas fraction containing a majority of the methane and light components;
(10) The first heat exchange means connected to the mixing means for receiving the volatile residue gas fraction, the first heat exchange means, the volatile residue gas fraction under pressure. Adapted to cool and condense at least a portion thereof to form the condensed stream; and
(11) The amount and temperature of the feed stream to the contacting and separating means and the distillation column
To maintain the top temperature of the contact and separation means and the distillation column at a certain temperature.
A control means adapted to recover most of the hydrocarbon components heavier than the methane into the relatively less volatile fraction
The improvement is to include.
[54]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) The natural gas stream is received and cooled under sufficient pressure to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving the partially condensed cooled natural gas stream and supplying it to the first steam stroke;
A first separation means coupled to the second heat exchange means for separation into a ream and a first liquid stream;
(3) receiving the first steam stream and expanding it to an intermediate pressure to expand it.
A second expansion means connected to one separation means;
(4) Contact and separation means coupled to receive the expanded first vapor stream
The contact and separation means comprises at least one contact device for mixing the liquid and the vapor, separating the vapor and the liquid after mixing, and separating the second vapor stream and the second liquid stream; Including separation means for forming;
(5) receiving the first liquid stream and expanding it to the intermediate pressure before
Third expansion means coupled to the separating means;
(6) Receiving the second liquid stream and the expanded first liquid stream
The combined distillation column, the distillation column, separates the stream into a more volatile vapor distillation stream and a relatively less volatile fraction containing a majority of hydrocarbons heavier than the methane. Adapted to;
(7) receiving the more volatile steam distillation stream and condensing at least a portion thereof;
A third heat exchange means connected to the distillation column for sufficient cooling to achieve
(8) accepting the cooled, more volatile steam distillation stream and passing it to a third steam stream;
A second separation means coupled to the third heat exchange means for separation into a stream and a third liquid stream;
(9) receiving the third liquid stream, which is at least in the first part and the second part;
A dividing means coupled to the second separating means for dividing, the dividing means further for supplying a first portion of the third liquid stream to the distillation column as an upper feed to the distillation column; Connected to the distillation column;
(10) further receiving and expanding at least a portion of the expanded first vapor stream in the contact device, wherein at least a portion of the second portion of the third liquid stream is received in the second portion of the third liquid stream. Said contacting and separating means coupled to said dividing means for complete contact with a part;
(11) receiving the second vapor stream and the third vapor stream and mixing them to form a volatile residue gas fraction containing a majority of the methane and light components; The contacting and separating means and a mixing means connected to the separating means;
(12) The first heat exchange means connected to the mixing means for receiving the volatile residue gas fraction, the first heat exchange means, the volatile residue gas fraction under pressure. Adapted to cool and condense at least a portion thereof, thereby forming said condensed stream; and
(13) controlling the amount and temperature of the feed stream to the contact and separation means and the distillation column to maintain the temperature at the top of the contact and separation means and the distillation column at a certain temperature, thereby Control means adapted to recover most of the heavier hydrocarbon components in a relatively less volatile fraction
The improvement is to include.
[55]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) receiving said natural gas stream and cooperating to cool it under pressure
One or more second heat exchange means;
(2) Before receiving the cooled natural gas stream and expanding it to intermediate pressure
Second expansion means coupled to the second heat exchange means;
(3) Contact and separation coupled to receive the expanded cooled natural gas stream.
Means, said contact and separation means comprise at least one contact device for mixing liquid and vapor, separating said vapor and liquid after mixing and containing a majority of said methane and light components Separation means for forming a volatile residue gas fraction and a first liquid stream;
(4) a third connected to the contacting and separating means to receive the first liquid stream;
Heat exchange means;
(5) a distillation column coupled to receive the heated first liquid stream,
A distillation column is adapted to separate the stream into a more volatile steam distillation stream and a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane. ;
(6) receiving the more volatile steam distillation stream and condensing at least a portion thereof;
A fourth heat exchange means coupled to the distillation column so as to be sufficiently cooled to thereby form a second liquid stream;
(7) further receiving a second liquid stream and expanding the cooled natural gas stream.
Said contacting and separating means coupled to said fourth heat exchange means such that at least a portion thereof is in full contact with at least a portion of said second liquid stream in said contacting device;
(8) the first connected to the contacting and separating means for receiving the volatile residue gas fraction;
One heat exchanging means, the first heat exchanging means is adapted to cool the volatile residue gas fraction under pressure and condense at least a portion thereof, thereby forming the condensed stream. ;as well as
(9) the amount and temperature of the feed stream to the contact and separation means and the distillation column;
Control and maintain the temperature at the top of the contacting and separation means and the distillation column at a certain temperature, thereby recovering the majority of hydrocarbon components heavier than the methane in a relatively less volatile fraction. Control means adapted to
The improvement is to include.
[56]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) The natural gas stream is received and cooled under sufficient pressure to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving the partially condensed cooled natural gas stream and supplying it to the first steam stroke;
Separation means coupled to the second heat exchange means for separation into a ream and a first liquid stream;
(3) receiving the first steam stream and expanding it to an intermediate pressure to expand it.
A second expansion means connected to one separation means;
(4) Contact and separation means coupled to receive the expanded first vapor stream
The contact and separation means contains at least one contact device for mixing the liquid and the vapor, separates the vapor and the liquid after mixing, and contains a majority of the methane and light components. A separation means for forming a gaseous residue gas fraction and a second liquid stream;
(5) In the contact and separation means for receiving and heating the second liquid stream
Linked third heat exchange means;
(6) receiving the first liquid stream and expanding it to the intermediate pressure before
Third expansion means coupled to the separating means;
(7) To receive the heated second liquid stream and the expanded first liquid stream.
A distillation column coupled to the separation column, which separates the stream into a more volatile steam distillation stream and a less volatile fraction containing the majority of the hydrocarbon components heavier than the methane. Adapted to do;
(8) receiving the more volatile steam distillation stream and condensing at least a portion thereof;
A fourth heat exchange means coupled to the distillation column to cool sufficiently to form a third liquid stream;
(9) the first vapor stream further receiving and expanding the third liquid stream;
Said contacting and separating means coupled to said fourth heat exchanging means for at least partly contacting said at least part of said third liquid stream in said contacting device;
(10) The first heat exchange means and the first heat exchange means connected to the contact and separation means for receiving the volatile residue gas fraction add the volatile residue gas fraction. Adapted to cool under pressure and to condense at least a portion thereof, thereby forming said condensed stream;
(11) The amount and temperature of the feed stream to the contacting and separating means and the distillation column
To maintain the top temperature of the contact and separation means and the distillation column at a certain temperature.
A control means adapted to recover a majority of the hydrocarbon components heavier than the methane to the relatively less volatile fraction
The improvement is to include.
[57]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) receiving said natural gas stream and cooperating to cool it under pressure
One or more second heat exchange means;
(2) Before receiving the cooled natural gas stream and expanding it to an intermediate pressure
Second expansion means coupled to the second heat exchange means;
(3) Contact and separation coupled to receive the expanded cooled natural gas stream.
Means, said contacting and separating means comprising at least one contact device for mixing the liquid and the vapor, separating the vapor and the liquid after mixing, the first vapor stream and the first liquid stream; Including separation means to form
(4) receiving said first liquid stream and contacting said separation and separation means to heat it;
Linked third heat exchange means;
(5) a distillation column coupled to receive the heated first liquid stream;
A distillation column is adapted to separate the stream into a more volatile steam distillation stream and a relatively less volatile fraction containing a majority of hydrocarbons heavier than the methane;
(6) receiving the more volatile steam distillation stream and condensing at least a portion thereof;
A fourth heat exchange means connected to the distillation column for sufficient cooling to achieve
(7) receiving the cooled, more volatile, steam distillation stream and passing it to the second steam stream.
Separation means coupled to the fourth heat exchange means for separation into a stream and a second liquid stream;
(8) receiving the second liquid stream, which is at least in the first part and the second part;
A splitting means coupled to the separation means for splitting, wherein the splitting means is further adapted to supply the first portion of the second liquid stream to the distillation column as an upper feed to the distillation column. Connected to a column;
(9) Cooled natural gas further receiving and expanding the second portion of the second liquid stream
Said contacting and separating means coupled to said dividing means for bringing at least a portion of a stream into full contact with at least a portion of a second portion of said second liquid stream in said contacting device;
(10) receiving the first vapor stream and the second vapor stream and mixing them to form a volatile residue gas fraction containing a majority of the methane and light components; The contacting and separating means and a mixing means connected to the separating means;
(11) The first heat exchange means connected to the mixing means for receiving the volatile residue gas fraction, the first heat exchange means, the volatile residue gas fraction under pressure. Adapted to cool and condense at least a portion thereof, thereby forming said condensed stream; and
(12) controlling the amount and temperature of the feed stream to the contact and separation means and the distillation column to maintain the top temperature of the contact and separation means and the distillation column at a certain temperature, thereby Control means adapted to recover most of the heavier hydrocarbon components in a relatively less volatile fraction
The improvement is to include.
[58]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) The natural gas stream is received and cooled under sufficient pressure to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving the partially condensed cooled natural gas stream and supplying it to the first steam stroke;
A first separation means coupled to the second heat exchange means for separation into a ream and a first liquid stream;
(3) receiving the first steam stream and expanding it to an intermediate pressure to expand it.
A second expansion means connected to one separation means;
(4) Contact and separation means coupled to receive the expanded first vapor stream
The contact and separation means comprises at least one contact device for mixing the liquid and the vapor, separating the vapor and the liquid after mixing, and separating the second vapor stream and the second liquid stream; Including separation means for forming;
(5) receiving and feeding said second liquid stream to said contacting and separating means to heat it;
Linked third heat exchange means;
(6) receiving said first liquid stream and connecting it to expand to an intermediate pressure
A third expansion means;
(7) receiving the heated second liquid stream and the expanded first liquid stream;
A distillation column connected to the steam column, the distillation column is a more volatile steam distillation stream;
And is adapted to separate the stream into a relatively less volatile fraction containing a majority of hydrocarbons heavier than the methane;
(8) receiving the more volatile steam distillation stream and condensing at least a portion thereof;
A fourth heat exchange means connected to the distillation column for sufficient cooling to achieve
(9) accepting the cooled, more volatile steam distillation stream and receiving it as a third steam stream;
A second separation means coupled to the fourth heat exchange means for separation into a stream and a third liquid stream;
(10) receiving said third liquid stream, comprising at least a first portion and a second portion;
The dividing means connected to the second separating means so as to be divided into
Connected to the distillation column to supply a first portion of the third liquid stream to the distillation column as an upper feed to the distillation column;
(11) further receiving and expanding a second portion of the third liquid stream and transferring at least a portion of the expanded first vapor stream in the contact device to at least a second portion of the third liquid stream. Said contacting and separating means coupled to said dividing means for complete contact with a part;
(12) receiving the second vapor stream and the third vapor stream and mixing them to form a volatile residue gas fraction containing a majority of the methane and light components; The contacting and separating means and a mixing means connected to the separating means;
(13) The first heat exchange means connected to the mixing means to receive the volatile residue gas fraction, the first heat exchange means, the volatile residue gas fraction under pressure. Adapted to cool and condense at least a portion thereof, thereby forming said condensed stream; and
(14) controlling the amount and temperature of the feed stream to the contact and separation means and the distillation column to maintain the temperature at the top of the contact and separation means and the distillation column at a certain temperature, thereby Control means adapted to recover most of the heavier hydrocarbon components in a relatively less volatile fraction
The improvement is to include.
[59]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) receiving said natural gas stream and cooperating to cool it under pressure
One or more second heat exchange means;
(2) Before receiving the cooled natural gas stream and expanding it to an intermediate pressure
Second expansion means coupled to the second heat exchange means;
(3) a distillation column coupled to receive the expanded cooled natural gas stream;
The distillation column is adapted to separate the stream into a more volatile vapor distillation stream and a relatively less volatile fraction containing a majority of hydrocarbons heavier than the methane. ;
(4) Vapor steam from the region of the distillation column below the expanded cooled natural gas stream.
A vapor extraction means connected to the distillation column for receiving a distillation stream;
(5) receiving said steam distillation stream and sufficient to condense at least a portion thereof;
A third heat exchanging means coupled to the steam extraction means for cooling to
(6) receiving the cooled steam distillation stream, which is converted into a steam stream and a liquid stream;
Separation means coupled to the third heat exchange means for separation into
(7) receiving the liquid stream and at least a portion of the expanded cooled natural gas stream;
Part of the distillation column connected to the separation means in order to bring at least part of the liquid stream into full contact in the distillation column;
(8) receiving the more volatile steam distillation stream and the steam stream,
Mixing means coupled to the distillation column and the separation means so as to form a volatile residue gas fraction containing a majority of the methane and light components;
(9) the first heat coupled to the mixing means to receive the volatile residue gas fraction.
An exchange means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream; and
(10) Control the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, thereby comparing most of the hydrocarbon components heavier than the methane Control means adapted to recover in fractions with low volatility
The improvement is to include.
[60]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) Accept the natural gas stream and cool it under pressure sufficiently to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving the partially condensed natural gas stream and converting it into a first steam stream;
And a first separation means coupled to the second heat exchange means for separation into a first liquid stream;
(3) receiving the first steam stream and expanding it to an intermediate pressure to expand it.
A second expansion means connected to one separation means;
(4) receiving the first liquid stream and expanding it to the intermediate pressure before
A third expansion means coupled to the first separation means;
(5) receiving the expanded first vapor stream and the expanded first liquid stream;
A distillation column connected for storage, the distillation column comprising a more volatile steam distillation stream and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane. Adapted to separate the streams;
(6) the steam steam from the region of the distillation column below the expanded first steam stream.
A vapor outlet means connected to the distillation column to receive a distillation stream;
(7) Receiving the distillation distillation stream and cooling sufficiently to condense at least a portion thereof
A third heat exchanging means connected to the steam extraction means to
(8) receiving the cooled steam distillation stream, which is converted into a second steam stream and a second liquid;
A second separation means coupled to the third heat exchange means for separation into a stream;
(9) less of the first vapor stream receiving and expanding the second liquid stream;
Said distillation column further connected to said second separation means for bringing a part thereof into full contact with at least a part of said second liquid stream in said distillation column;
(10) receiving the more volatile steam distillation stream and the second steam stream and mixing them to form a volatile residue gas fraction containing a majority of the methane and light components; Mixing means connected to the distillation column and the second separation means for
(11) The first heat exchange means connected to the mixing means for receiving the volatile residue gas fraction, the first heat exchange means, the volatile residue gas fraction under pressure. Cool and less
Adapted to condense partly thereby forming said condensed stream; and
(12) controlling the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, thereby allowing most of the hydrocarbon components heavier than the methane to Control means adapted to collect in relatively volatile fractions
The improvement is to include.
[61]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) receiving said natural gas stream and cooperating to cool it under pressure
One or more second heat exchange means;
(2) Before receiving the cooled natural gas stream and expanding it to an intermediate pressure
Second expansion means coupled to the second heat exchange means;
(3) a distillation column coupled to receive the expanded cooled natural gas stream;
The distillation column is adapted to separate the stream into a more volatile vapor distillation stream and a relatively less volatile fraction containing a majority of hydrocarbons heavier than the methane. ;
(4) Vapor steam from the region of the distillation column below the expanded cooled natural gas stream.
A vapor extraction means connected to the distillation column for receiving a distillation stream;
(5) Receiving the steam distillation stream and cooling sufficiently to condense at least a portion thereof
A third heat exchanging means connected to the steam extraction means to
(6) receiving the cooled steam distillation stream, which is converted into a steam stream and a liquid stream;
Separation means coupled to the third heat exchange means for separation into
(7) receiving the liquid stream and dividing it into at least a first part and a second part;
A dividing means connected to the separating means for further separating the first of the liquid stream to the distillation column at a feed position substantially in the same region as the vapor distillation stream is withdrawn. Connected to the distillation column to supply a portion;
(8) receiving the second portion of the liquid stream and expanding the cooled cooled natural gas stream;
Said distillation column further coupled to said dividing means for bringing at least a portion of the stream into full contact with at least a portion of said second portion of said liquid stream in said distillation column; (9) Receiving a highly volatile steam distillation stream and said steam stream;
Mixing means connected to the distillation column and the separation means to form a volatile residue gas fraction containing a majority of the methane and light components;
(10) The first heat exchange means coupled to the mixing means for receiving the volatile residue gas fraction, the first heat exchange means cooling the volatile residue gas fraction under pressure. Adapted to condense at least a portion thereof, thereby forming said condensed stream; and
(11) Control the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, thereby comparing most of the hydrocarbon components heavier than the methane Control means adapted to recover in fractions with low volatility
The improvement is to include.
[62]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) receiving the natural gas stream and cooling under pressure sufficiently to partially condense
One or more second heat exchanging means that are cooperatively coupled to each other;
(2) receiving the partially condensed natural gas stream and converting it into a first steam stream;
And a first separation means coupled to the second heat exchange means for separation into a first liquid stream;
(3) receiving the first steam stream and expanding it to an intermediate pressure to expand it.
A second expansion means connected to one separation means;
(4) receiving the first liquid stream and expanding it to the intermediate pressure before
A third expansion means coupled to the first separation means;
(5) receiving the expanded first vapor stream and the expanded first liquid stream;
A distillation column connected for storage, the distillation column comprising a more volatile steam distillation stream and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane. Adapted to separate the streams;
(6) a steam distillation stream from the region of the distillation column below the expanded steam stream
Vapor extraction means connected to the distillation column to receive the system;
(7) Receiving the steam distillation stream and cooling sufficiently to condense at least a portion thereof
A third heat exchanging means connected to the steam extraction means to
(8) receiving the cooled steam distillation stream, which is converted into a second steam stream and a second liquid;
A second separation means coupled to the third heat exchange means for separation into a stream;
(9) receiving said second liquid stream, which is at least in a first part and a second part;
A splitting means coupled to the second separation means for splitting, the splitting means further comprising a second feed to the distillation column at a feed position substantially in the same region as the vapor distillation stream is withdrawn. Connected to the distillation column to supply a first portion of a liquid stream of
(10) receiving and expanding a second portion of the second liquid stream to at least a portion of the first vapor stream in the distillation column in the second portion of the second liquid stream; The distillation column further connected to the dividing means for complete contact with at least a portion of the distillation column;
(11) receiving the more volatile steam distillation stream and the second steam stream and mixing them to form a volatile residue gas fraction containing a majority of the methane and light components; Mixing means connected to the distillation column and the separating means for
(12) The first heat exchange means connected to the mixing means for receiving the volatile residue gas fraction, the first heat exchange means, the volatile residue gas fraction under pressure. Adapted to cool and condense at least a portion thereof, thereby forming said condensed stream; and
(13) Control the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, so that most of the hydrocarbon components heavier than the methane. Control means adapted to collect in said relatively low volatile fraction
The improvement is to include.
[63]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream
;as well as
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) receiving said natural gas stream and cooperating to cool it under pressure
One or more second heat exchange means;
(2) receiving the partially condensed natural gas stream and expanding it to produce an intermediate pressure and
Second expansion means coupled to said second heat exchange means to
(3) a distillation column coupled to receive the expanded cooled natural gas stream;
The distillation column is adapted to separate the stream into a more volatile vapor distillation stream and a relatively less volatile fraction containing a majority of hydrocarbon components heavier than the methane. Is;
(4) a steam distillation stream from the area of the distillation column below the expanded cooled natural gas stream;
Vapor extraction means connected to the distillation column to receive the stream;
(5) Receiving the steam distillation stream and cooling sufficiently to condense at least a portion thereof
A third heat exchanging means connected to the steam extraction means to
(6) receiving the cooled steam distillation stream, which is converted into a steam stream and a liquid stream;
Separation means coupled to the third heat exchange means for separation into
(7) receiving at least the liquid stream and expanding at least a cooled natural gas stream;
The distillation column further connected to the separation means for bringing a portion into full contact with at least a portion of the liquid stream in the distillation column;
(8) receiving a liquid distillation stream from the area of the distillation column above the vapor extraction means
Means for withdrawing liquid connected to the distillation column to
(9) connected to the liquid extraction means for receiving the liquid stream and heating it.
The fourth heat exchange means, further connected to the distillation column for supplying the heated liquid distillation stream to the distillation column one below the vapor extraction means. ;
(10) receiving the more volatile steam distillation stream and the steam stream and mixing them to form a volatile residue gas fraction containing a majority of the methane and light components; Mixing means connected to the distillation column and said separating means;
(11) The first heat exchange means connected to the mixing means for receiving the volatile residue gas fraction, the first heat exchange means, the volatile residue gas fraction under pressure. Adapted to cool and condense at least a portion thereof, thereby forming said condensed stream; and
(12) Control the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, so that most of the hydrocarbon components heavier than the methane. Control means adapted to collect in said relatively low volatile fraction
The improvement is to include.
[64]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) Accept the natural gas stream and cool it under pressure sufficiently to partially condense it.
One or more second heat exchanging means that are cooperatively linked to reject;
(2) receiving the partially condensed natural gas stream and converting it into a first steam stream;
And a first separation means coupled to the second heat exchange means for separation into a first liquid stream;
(3) receiving the first steam stream and expanding it to an intermediate pressure to expand it.
A second expansion means connected to one separation means;
(4) receiving the first liquid stream and expanding it to the intermediate pressure before
A third expansion means coupled to the first separation means;
(5) receiving the expanded first vapor stream and the expanded first liquid stream;
A distillation column connected for storage, the distillation column comprising a more volatile steam distillation stream and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane. Adapted to separate the streams;
(6) a steam distillation column from the region of the distillation column below the expanded first steam stream;
Vapor extraction means connected to the distillation column to receive the stream;
(7) Receiving the steam distillation stream and cooling sufficiently to condense at least a portion thereof
A third heat exchanging means connected to the steam extraction means to
(8) receiving the cooled steam distillation stream, which is converted into a second steam stream and a second liquid;
A second separation means coupled to the third heat exchange means for separation into a stream;
(9) receiving the second liquid stream and expanding the first vapor in the distillation column;
The distillation column further coupled to the second separation means to fully contact at least a portion of the stream with at least a portion of the second liquid stream;
(10) Liquid extraction means connected to the distillation column for receiving a liquid distillation stream from the area of the distillation column above the vapor extraction means;
(11) Fourth heat exchange means connected to the liquid extraction means for receiving the liquid distillation stream and heating it, the fourth heat exchange means is further positioned below the vapor extraction means Connected to the distillation column for supplying the heated liquid distillation stream to the distillation column;
(12) Receiving the more volatile steam distillation stream and the second steam stream and mixing them to form a volatile residual gas fraction containing the majority of the methane and light components Mixing means connected to the distillation column and the second separation means to
(13) The first heat exchange means connected to the mixing means for receiving the volatile residue gas component, the first heat exchange means cools the volatile residue gas fraction under pressure. Adapted to condense at least a portion thereof to thereby form the condensed stream; and
(14) controlling the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, so that most of the hydrocarbon components heavier than the methane. Control means adapted to collect in said relatively low volatile fraction
The improvement is to include.
[65]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) One that receives the natural gas stream and is cooperatively linked to cool under pressure
The above second heat exchange means;
(2) Before receiving the cooled natural gas stream and expanding it to an intermediate pressure
Second heat exchange means coupled to the second heat exchange means;
(3) a distillation column coupled to receive the expanded cooled natural gas stream;
The distillation column is adapted to separate the stream into a more volatile vapor distillation stream and a relatively less volatile fraction containing a majority of hydrocarbon components heavier than the methane. Is;
(4) steaming from the region of the distillation column below the expanded cooled natural gas stream.
A vapor outlet means connected to the distillation column to receive a distillation stream;
(5) Receiving the steam distillation stream and cooling sufficiently to condense at least a portion thereof
A third heat exchanging means connected to the steam extraction means to
(6) receiving the cooled steam distillation stream, which is converted into a steam stream and a liquid stream;
Separation means coupled to the third heat exchange means for separation into
(7) receiving the liquid stream and dividing it into at least a first part and a second part;
A dividing means coupled to the separating means, the dividing means further comprising a first of the liquid stream in the distillation column at a feed position substantially in the same region as the vapor distillation stream is withdrawn. Connected to the distillation column to supply a portion;
(8) The distillation column receives the second portion of the liquid stream and expands the cooled
Further coupled to the dividing means for bringing at least a portion of the natural gas stream into full contact with at least a portion of the second portion of the liquid stream in the distillation column;
(9) receiving a liquid distillation stream from the area of the distillation column above the vapor extraction means
Means for withdrawing liquid connected to the distillation column to
(10); to the liquid extraction means for receiving and heating the liquid distillation stream;
The connected fourth heat exchanging means and the fourth heat exchanging means are lower than the steam extracting means.
Further connected to the distillation column to supply the heated liquid distillation stream to the distillation column at a position;
(11) receiving the more volatile steam distillation stream and the steam stream and mixing them to form a volatile residue gas fraction containing a majority of the methane and light components; Mixing means connected to the distillation column and said separating means;
(12) The first heat exchange means connected to the mixing means for receiving the volatile residue gas fraction, the first heat exchange means, the volatile residue gas fraction under pressure. Adapted to cool and condense at least a portion thereof, thereby forming said condensed stream; and
(13) Control the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, so that most of the hydrocarbon components heavier than the methane. Control means adapted to collect in said relatively low volatile fraction
The improvement is to include.
[66]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) receiving the natural gas stream and cooling under pressure sufficiently to partially condense
One or more second heat exchanging means that are cooperatively coupled to each other;
(2) receiving the partially condensed natural gas stream and converting it into a first steam stream;
And a first separation means coupled to the second heat exchange means for separation into a first liquid stream;
(3) receiving the first steam stream and expanding it to an intermediate pressure to expand it.
A second expansion means connected to one separation means;
(4) receiving the first liquid stream and expanding it to the intermediate pressure before
A third expansion means coupled to the first separation means;
(5) receiving the expanded first vapor stream and the expanded first liquid stream;
A distillation column connected for storage, the distillation column comprising a more volatile steam distillation stream and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane. Adapted to separate the streams;
(6) a steam distillation column from the region of the distillation column below the expanded first steam stream;
Vapor extraction means connected to the distillation column to receive the stream;
(7) Receiving the steam distillation stream and cooling sufficiently to condense at least a portion thereof
A third heat exchanging means connected to the steam extraction means to
(8) receiving the cooled steam distillation stream, which is converted into a second steam stream and a second liquid;
A second separation means coupled to the third heat exchange means for separation into a stream;
(9) receiving said second liquid stream, which is at least in a first part and a second part;
A splitting means coupled to the second separation means for splitting, the splitting means further comprising a second feed to the distillation column at a feed position substantially in the same region as the vapor distillation stream is withdrawn. Connected to the distillation column to supply a first portion of a liquid stream of
(10) receiving and expanding a second portion of the second liquid stream to at least a portion of the first vapor stream in the distillation column in the second portion of the second liquid stream; The distillation column further connected to the dividing means for complete contact with at least a portion of the distillation column;
(11) Liquid extraction means coupled to the distillation column for receiving a liquid distillation stream from a region of the vapor column above the vapor extraction means;
(12) Fourth heat exchange means connected to the liquid extraction means for receiving and heating the liquid distillation stream, the fourth heat exchange means is located at a position below the vapor extraction means. Further connected to the distillation column to supply the heated liquid distillation stream to the distillation column;
(13) receiving the more volatile steam distillation stream and the second steam stream and mixing them to form a volatile residue gas fraction containing a majority of the methane and light components; Mixing means connected to the distillation column and the separating means for
(14) The first heat exchange means connected to the mixing means to receive the volatile residue gas fraction, the first heat exchange means, the volatile residue gas fraction under pressure. Adapted to cool and condense at least a portion thereof, thereby forming said condensed stream; and
(15) controlling the amount and temperature of the feed stream to the distillation column to maintain the top temperature of the distillation column at a certain temperature, so that most of the hydrocarbon components heavier than the methane. Control means adapted to collect in said relatively low volatile fraction
The improvement is to include.
[67]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) One that receives the natural gas stream and is cooperatively linked to cool under pressure
The above second heat exchange means;
(2) Before receiving the cooled natural gas stream and expanding it to an intermediate pressure
Second expansion means coupled to the second heat exchange means;
(3) a distillation column coupled to receive the expanded cooled natural gas stream;
The distillation column is divided into a volatile residue gas fraction containing most of the methane and light components and a relatively less volatile fraction containing most of the hydrocarbon components heavier than the methane. Adapted to separate the streams;
(4) the first heat coupled to the first distillation means to receive the volatile residue gas fraction.
An exchange means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream; and
(5) controlling the amount and temperature of the feed stream to the distillation column to
Control means adapted to maintain the tower top temperature at a certain temperature and thereby recover most of the hydrocarbon components heavier than the methane in the relatively less volatile fraction
The improvement is to include.
[68]
A liquefaction device for a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) receiving the natural gas stream and cooling it under pressure to condense at least a portion thereof;
One or more first heat exchange means cooperatively coupled to form a condensed stream; and
(b) receiving the condensate stream and expanding it to a low pressure, the liquefied natural gas stream;
Wherein said apparatus has a first expansion means coupled to said first heat exchange means to form a system comprising:
(1) receiving the natural gas stream and cooling under pressure sufficiently to partially condense
One or more second heat exchanging means that are cooperatively coupled to each other;
(2) receiving said partially condensed natural gas stream, which is converted into a vapor stream and a liquid;
Separation means coupled to said second heat exchange means for separation into a stream;
(3) receiving the first steam stream and expanding it to an intermediate pressure to expand it.
Second expansion means coupled to the separation means;
(4) receiving the liquid stream and expanding the same to obtain the intermediate pressure
A third expansion means coupled to the means;
(5) To receive the expanded vapor stream and the expanded liquid stream
A connected distillation column, the distillation column is a relatively volatile residue gas fraction containing a majority of the methane and lighter components and a majority of hydrocarbon components heavier than the methane. Adapted to separate the stream into low fractions of;
(6) the first heat coupled to the distillation column to receive the volatile residue gas fraction.
An exchange means, the first heat exchange means is adapted to cool the volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream; and
(7) controlling the amount and temperature of the feed stream to the distillation column to
Control means adapted to maintain the tower top temperature at a certain temperature and thereby recover most of the hydrocarbon components heavier than the methane in the relatively less volatile fraction
The improvement consists of essentially consisting of
[69]
73. Improvement according to 43, 44, 45, 67 or 68, wherein the device comprises:
(1) connected to the distillation column to receive and compress the volatile residue gas fraction
Compression means; and
(2) the first connected to the compression means for receiving the compressed volatile residue gas fraction;
The heat exchange means, wherein the first heat exchange means is adapted to cool the compressed volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream. ing.
[70]
42. The improvement of 41, wherein the device includes:
(1) A pressure connected to the distillation column to receive and compress the volatile gas fraction.
Contraction means;
(2) the first connected to the compression means for receiving the compressed volatile residue gas fraction;
And the first heat exchange means is adapted to cool the compressed volatile residue gas fraction under pressure to condense at least a portion thereof; and
(3) receiving the condensing part and dividing it into at least two parts, thereby
Said dividing means coupled to said first heat exchange means to form a condensed stream and said liquid stream, said dividing means further directing said liquid stream to said distillation column as an upper feed to the distillation column It is connected to the distillation column for attaching.
[71]
43. Improvement according to 42, wherein the device comprises:
(1) A pressure connected to the distillation column to receive and compress the volatile gas fraction.
Contraction means;
(2) the first connected to the compression means for receiving the compressed volatile residue gas fraction;
And the first heat exchange means is adapted to cool the compressed volatile residue gas fraction under pressure to condense at least a portion thereof; and
(3) receiving the condensing part and dividing it into at least two parts, thereby
The splitting means coupled to the first heat exchange means to form a condensed stream and the second liquid stream, the splitting means further comprising a first feed to the distillation column as an upper feed to the distillation column. Connected to the distillation column for directing two liquid streams.
[72]
46. Improvement according to 46, wherein the device comprises:
(1) Accept the volatile residue gas fraction and connect it to the distillation column to compress it.
Compression means;
(2) the first connected to the compression means for receiving the compressed volatile residue gas fraction;
The heat exchange means, wherein the first heat exchange means is adapted to cool the compressed volatile residue gas fraction under pressure to condense at least a portion thereof; and
(3) receiving the condensing part and dividing it into at least two parts, thereby
The second dividing means coupled to the first heat exchange means to form a condensed stream and the liquid stream, the second dividing means further comprising the distillation as an upper feed to the distillation column Connected to the distillation column to direct the liquid stream to the column.
[73]
47. Improvement according to 47 or 48, wherein said device comprises:
(1) A pressure connected to the distillation column to receive and compress the volatile gas fraction.
Contraction means;
(2) the first connected to the compression means for receiving the compressed volatile residue gas fraction;
And the first heat exchange means is adapted to cool the compressed volatile residue gas fraction under pressure to condense at least a portion thereof; and
(3) receiving the condensing part and dividing it into at least two parts, thereby
Said first heat exchange means to form a condensed stream and said second liquid stream
The second dividing means connected to the second dividing means further includes an upper part to the distillation column.
Connected to the distillation column to direct the second liquid stream to the distillation column as a feed.
[74]
49. Improvement according to 49, wherein the device comprises:
(1) receiving the more volatile steam distillation stream and reducing the distillation column to compress it.
Compression means coupled to the system; and
(2) receiving the steam stream and the compressed more volatile steam distillation stream
And mixing means connected to the separation means and the compression means to mix them to form the volatile residue gas fraction containing the majority of the methane and light components.
[75]
51. Improvements according to 50, wherein the device comprises:
(1) accepting the more volatile steam distillation stream and distilling it to compress it
Compression means coupled to the column; and
(2) the second steam stream and the compressed more volatile steam distillation stream;
Said mixing means coupled to said separation means and said compression means to receive and mix them to form said volatile residue gas fraction containing a majority of said methane and light components. [76]
Improvements according to 51, 52, 55 or 56, wherein the device comprises:
(1) receiving said volatile gas fraction and connected to said contacting and separating means to compress it;
Compressed compression means; and
(2) the first means coupled to the compression means for receiving the compressed volatile residue gas fraction;
Heat exchanging means, the first heat exchanging means is adapted to cool the compressed volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream. Yes.
[77]
Improvements according to 53, 54, 57, 58, 59, 60, 61, 62, 63, 64, 65 or 66, wherein the device comprises:
(1) A compression connected to the mixing means to receive the volatile gas fraction and compress it
Means; and
(2) the first connected to the compression means for receiving the compressed volatile residue gas fraction;
The heat exchange means, wherein the first heat exchange means is adapted to cool the compressed volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream. ing.
[78]
73. Improvement according to 43, 44, 45, 67 or 68, wherein the device comprises:
(1) receiving the volatile gas fraction and adding it connected to the distillation column to heat it.
Heat means;
(2) receiving the heated volatile residue gas fraction and supplying it to the heating means to compress it;
Coupled compression means; and
(3) connected to the compression means to receive the compressed heated volatile residue gas fraction
The first heat exchanging means and the first heat exchanging means cool the compressed heated volatile residue gas fraction under pressure to condense at least a portion thereof, thereby forming the condensed stream. Have been adapted to.
[79]
42. The improvement of 41, wherein the device includes:
(1) receiving the volatile gas fraction and adding it connected to the distillation column to heat it.
Heat means;
(2) receiving the heated volatile residue gas fraction and supplying it to the heating means to compress it;
Linked compression means;
(3) connected to the compression means to receive the compressed heated volatile residue gas fraction
The first heat exchanging means, the first heat exchanging means is adapted to cool the compressed heated volatile residue gas fraction under pressure to condense at least a portion thereof; and
(4) receiving the condensed part and dividing it into at least two parts, thereby
The dividing means coupled to the first heat exchange means to form a condensed stream and the liquid stream, the dividing means further comprising a distillation column as an upper feed to the distillation column.
Connected to the distillation column to direct the liquid stream to a ram.
[80]
43. Improvement according to 42, wherein the device comprises:
(1) receiving the volatile gas fraction and adding it connected to the distillation column to heat it.
Heat means;
(2) receiving the heated volatile residue gas fraction and supplying it to the heating means to compress it;
Linked compression means;
(3) connected to the compression means to receive the compressed heated volatile residue gas fraction
The first heat exchanging means, the first heat exchanging means is adapted to cool the compressed heated volatile residue gas fraction under pressure to condense at least a portion thereof; and
(4) receiving the condensed part and dividing it into at least two parts, thereby
The dividing means coupled to the first heat exchange means to form a condensed stream and the liquid stream, the dividing means further comprising an upper feed to the distillation column and the second liquid to the distillation column Connected to the distillation column to direct the stream. [81]
46. Improvement according to 46, wherein the device comprises:
(1) receiving the volatile gas fraction and adding it connected to the distillation column to heat it.
Heat means;
(2) receiving the heated volatile residue gas fraction and supplying it to the heating means to compress it;
Linked compression means;
(3) connected to the compression means to receive the compressed heated volatile residue gas fraction
The first heat exchanging means, the first heat exchanging means is adapted to cool the compressed heated volatile residue gas fraction under pressure to condense at least a portion thereof; and
(4) receiving the condensed part and dividing it into at least two parts, thereby
Said dividing means coupled to said first heat exchange means to form a condensed stream and said liquid stream, said dividing means further directing said liquid stream to a distillation column as an upper feed to said distillation column It is connected to the distillation column for attaching.
[82]
47. Improvement according to 47 or 48, wherein said device comprises:
(1) receiving the volatile gas fraction and adding it connected to the distillation column to heat it.
Heat means;
(2) receiving the heated volatile residue gas fraction and supplying it to the heating means to compress it;
Linked compression means;
(3) connected to the compression means to receive the compressed heated volatile residue gas fraction
The first heat exchanging means, the first heat exchanging means is adapted to cool the compressed heated volatile residue gas fraction under pressure to condense at least a portion thereof; and
(4) receiving the condensed part and dividing it into at least two parts, thereby
The dividing means coupled to the first heat exchange means to form a condensed stream and the liquid stream, the dividing means further comprising an upper feed to the distillation column and the second liquid to the distillation column Connected to the distillation column to direct the stream. [83]
49. Improvement according to 49, wherein the device comprises:
(1) accepting the more volatile steam distillation stream and heating it to heat it
Heating means connected to the column;
(2) To receive and compress the heated, more volatile steam distillation stream
Compression means connected to the heating means;
(3) receiving and cooling the compressed heated more volatile steam distillation stream
Cooling means connected to said compression means for
(4) the steam stream and the cooled and compressed more volatile steam distillation stream;
Volatile residue containing most of the methane and light components by mixing and mixing these
The mixing means connected to the separating means and the cooling means to form a gas fraction.
[84]
51. Improvements according to 50, wherein the device comprises:
(1) accepting the more volatile steam distillation stream and heating it to heat it
Heating means connected to the column;
(2) To receive and compress the heated, more volatile steam distillation stream
Compression means connected to the heating means;
(3) receiving and cooling the compressed heated more volatile steam distillation stream
Cooling means connected to said compression means for
(4) the second steam stream and the cooled and compressed more volatile steam distillation steam.
Said mixing means connected to said separation means and said cooling means for receiving a stream and mixing them to form a volatile residue gas fraction containing a majority of said methane and light components .
[85]
Improvements according to 51, 52, 55 or 56, wherein the device comprises:
(1) receiving the volatile residue gas fraction and communicating with the contact and separation means to heat it.
Bonded heating means;
(2) receiving the heated volatile residue gas fraction and supplying it to the heating means to compress it;
Coupled compression means; and
(3) connected to the compression means for receiving the compressed and heated volatile residue gas fraction.
The first heat exchanging means and the first heat exchanging means are configured to cool the compressed and heated volatile residue gas fraction under pressure to condense at least a part thereof, thereby condensing the condensation. Adapted to form a stream.
[86]
Improvements according to 53, 54, 57, 58, 59, 60, 61, 62, 63, 64, 65 or 66, wherein the device comprises:
(1) Received the volatile residue gas fraction and connected to the mixing means to heat it
Heating means;
(2) receiving the heated volatile residue gas fraction and supplying it to the heating means to compress it;
Coupled compression means; and
(3) connected to the compression means for receiving the compressed and heated volatile residue gas fraction.
The first heat exchanging means and the first heat exchanging means are configured to cool the compressed and heated volatile residue gas fraction under pressure to condense at least a part thereof, thereby condensing the condensation. Adapted to form a stream.
[87]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 41, 42, 43, 44, 45, 46, 47, 48, 49, 50, 51, 52, 53, 54, 55, 56, 57, 58, 59, 60, 61, 62, 63, 64, 65, 66, 67, 68, 70, 71, 72, 74, 75, 79, 80, 81, 83 or 84.
[88]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 41, 42, 43, 44, 45, 46, 47, 48, 49, 50, 51, 52, 53, 54, 55, 56, 57, 58, 59, 60, 61, 62, 63, 64, 65, 66, 67, 68, 70, 71, 72, 74, 75, 79, 80, 81, 83 or 84.
[89]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 30. The improvement according to 29, comprising the components.
[90]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 30. The improvement according to 30, comprising the components.
[91]
The volatile residue gas fraction contains most of the methane, light components and C ₂ The improvement of 31 containing a component.
[92]
The volatile residue gas fraction contains most of the methane, light components and C ₂ The improvement of 34 containing the component.
[93]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 36. The improvement according to 35, comprising the components.
[94]
The volatile residue gas fraction contains most of the methane, light components and C ₂ The improvement of 36 containing an ingredient.
[95]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three The improvement according to 29, comprising:
[96]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 30. The improvement according to 30, comprising the components.
[97]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three The improvement of 31 containing a component.
[98]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three The improvement of 34 containing the component.
[99]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 36. The improvement according to 35, comprising the components.
[100]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three The improvement of 36 containing an ingredient.
[101]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 70. The improvement according to 69, comprising the components.
[102]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 74. The improvement according to 73, comprising the components.
[103]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 76. The improvement according to 76, comprising the components.
[104]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 78. The improvement according to 77, comprising an ingredient.
[105]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 78. The improvement according to 78, comprising: an ingredient.
[106]
The volatile residue gas fraction contains most of the methane, light components and C ₂ Containing 82 ingredients.
Improvements described in.
[107]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 85. The improvement according to 85, comprising the components.
[108]
The volatile residue gas fraction contains most of the methane, light components and C ₂ 86. The improvement according to 86, comprising the components.
[109]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 70. The improvement according to 69, comprising an ingredient.
[110]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 74. The improvement according to 73, comprising an ingredient.
[111]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 76. The improvement according to 76, comprising an ingredient.
[112]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 78. The improvement according to 77, comprising an ingredient.
[113]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 79. The improvement according to 78, comprising an ingredient.
[114]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 83. The improvement according to 82, comprising an ingredient.
[115]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 85. The improvement according to 85, comprising an ingredient.
[116]
The volatile residue gas fraction contains most of the methane, light components, C ₂ Ingredients and C _Three 87. The improvement according to 86, comprising an ingredient.

Claims (44)

A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) expanding the cooled natural gas stream to the intermediate pressure;
(3) directing the expanded cooled natural gas stream into a distillation column, wherein the expanded cooled natural gas stream is a fraction of a volatile residue gas containing a majority of the methane and light components. And a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(4) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
(5) dividing the condensed portion into at least two portions to form the condensed stream and the liquid stream; and
(6) Directing the liquid stream into the distillation column as an upper feed to the distillation column, with methane constituting at least 50 mol% of the natural gas stream. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide at least one vapor stream and a first liquid stream;
(3) expanding the steam stream to the intermediate pressure;
(4) expanding the first liquid stream to the intermediate pressure;
(5) directing at least the expanded vapor stream and the expanded first stream into a distillation column, wherein the stream is a volatile residue gas fraction containing a majority of the methane and light components. And a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(6) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
(7) dividing the condensing portion into at least two portions to form the condensate stream and a second liquid stream; and
(8) Directing the second liquid stream into the distillation column as an upper feed to the distillation column, where methane constitutes at least 50 mol% of the natural gas stream. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) dividing the cooled natural gas stream into at least a first gas stream and a second gas stream;
(3) cooling the first gas stream to condense substantially all of it and then expanding to intermediate pressure;
(4) expanding the second gas stream to the intermediate pressure;
(5) directing the first stream of expanded substantially condensed gas and the second stream of expanded gas into a distillation column, wherein the stream is comprised of a majority of the methane and light components. And a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than methane; and
(6) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof to form the condensed stream, and methane constitutes at least 50 mol% of the natural gas stream. To do. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a vapor stream and a liquid stream;
(3) dividing the vapor stream into at least a first gas stream and a second gas stream;
(4) cooling the first gas stream to condense substantially all of it and then expanding to intermediate pressure;
(5) expanding the second gas stream to the intermediate pressure;
(6) expanding the liquid stream to the intermediate pressure;
(7) directing the expanded substantially condensed gas first stream, the expanded gas second stream, and the expanded liquid stream into a distillation column, wherein the stream is Separating into a volatile residue gas fraction containing a majority of the methane and light components and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane; and
(8) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof to form the condensed stream, and methane constitutes at least 50 mol% of the natural gas stream. To do. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a vapor stream and a liquid stream;
(3) dividing the vapor stream into at least a first gas stream and a second gas stream;
(4) mixing the first gas stream with at least a portion of the liquid stream to form a mixed stream;
(5) cooling the mixed stream to substantially condense it, and then expanding to intermediate pressure;
(6) expanding the second gas stream to the intermediate pressure;
(7) all the remaining portion of the liquid stream is expanded to the intermediate pressure;
(8) an expanded substantially condensed mixed stream, a second stream of expanded gas;
Directing the remainder of the liquid stream into a distillation column, wherein the stream is divided into a volatile residue gas fraction containing a majority of the methane and light components, and a hydrocarbon component heavier than the methane. Separating into relatively less volatile fractions containing the majority of
(9) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof to form the condensed stream, and methane constitutes at least 50 mol% of the natural gas stream. To do. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) dividing the cooled natural gas stream into at least a first gas stream and a second gas stream;
(3) cooling the first gas stream to condense substantially all of it and then expanding to intermediate pressure;
(4) expanding the second gas stream to the intermediate pressure;
(5) directing the expanded first stream of substantially condensed gas and the second stream of expanded gas into a distillation column, wherein the stream comprises a majority of the methane and light components. Separating into a volatile residue gas fraction containing and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane;
(6) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
(7) dividing the condensed portion into at least two portions to form the condensed stream and the liquid stream; and
(8) Directing the liquid stream into the distillation column as an upper feed to the distillation column, with methane constituting at least 50 mol% of the natural gas stream. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a vapor stream and a first liquid stream;
(3) dividing the gas stream into at least a first gas stream and a second gas stream;
(4) cooling the first gas stream to condense substantially all of it and then expanding to intermediate pressure;
(5) expanding the second gas stream to the intermediate pressure;
(6) expanding the first liquid stream to the intermediate pressure;
(7) directing the expanded substantially condensed gas first stream, the expanded gas second stream, and the expanded first liquid stream into a distillation column, wherein The stream is separated into a volatile residue gas fraction containing a majority of the methane and light components and a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane. Do;
(8) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
(9) dividing the condensed portion into at least two portions to form the condensed stream and a second liquid stream; and
(10) Directing the second liquid stream into the distillation column as an upper feed to the distillation column, where methane constitutes at least 50 mol% of the natural gas stream. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a vapor stream and a first liquid stream;
(3) dividing the vapor stream into at least a first gas stream and a second gas stream;
(4) mixing the first gas stream with at least a portion of the first liquid stream to form a mixed stream;
(5) cooling the mixed stream to condense substantially all of it and then expanding to intermediate pressure;
(6) expanding the second gas stream to the intermediate pressure;
(7) all the remaining portion of the first liquid stream is expanded to the intermediate pressure;
(8) directing the expanded substantially condensed mixed stream, the second stream of expanded gas, and the remainder of the first liquid stream into a distillation column, wherein the stream is Separating into a volatile residue gas fraction containing the majority of the methane and light components and a relatively volatile fraction containing the majority of the hydrocarbon components heavier than the methane;
(9) cooling the volatile residue gas fraction under pressure to condense at least a portion thereof;
(10) dividing the condensing portion into at least two portions to form the condensate stream and a second liquid stream; and
(11) Directing the second liquid stream into the distillation column as an upper feed to the distillation column, wherein methane constitutes at least 50 mol% of the natural gas stream. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) expanding the cooled natural gas stream to the intermediate pressure;
(3) separating the expanded cooled natural gas stream to provide a vapor stream and a liquid stream;
(4) expanding the liquid stream to a low intermediate pressure;
(5) directing the expanded liquid stream into a distillation column, wherein the stream is relatively volatile containing a more volatile steam distillation stream and a majority of hydrocarbon components heavier than the methane. Separate into less likely fractions;
(6) mixing the more volatile distillation stream with the vapor stream to form a volatile residue gas fraction containing a majority of the methane and light components;
(7) The volatile residue gas fraction is cooled under pressure, and at least a part of the volatile residue gas fraction is condensed to form the condensed stream. Configure. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a first vapor stream and a first liquid stream;
(3) expanding the first steam stream to an intermediate pressure;
(4) separating the expanded first vapor stream to provide a second vapor stream and a second liquid stream;
(5) expanding the second liquid stream to a low intermediate pressure;
(6) expanding the first liquid stream to the low intermediate pressure;
(7) directing the expanded second liquid stream and the expanded first liquid stream into a distillation column, wherein the stream is heavier than the more volatile distillation stream and the methane. Separating into relatively less volatile fractions containing the majority of quality hydrocarbon components;
(8) mixing the more volatile steam distillation stream with the second steam stream;
Forming a volatile residue gas fraction containing a majority of the methane and light components; and
(9) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof to form the condensed stream, and methane is at least 50 mol% of the natural gas stream. Configure. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) expanding the cooled natural gas stream to an intermediate pressure and then directing it to a contact device, whereby a volatile residue gas fraction containing a majority of the methane and light components, and a first liquid; Form a stream;
(3) directing the first liquid stream into a distillation column, wherein the stream contains a more volatile steam distillation stream and a relatively high content of hydrocarbon components heavier than the methane. Separate into less volatile fractions;
(4) cooling the more volatile vapor distillation stream sufficiently to condense at least a portion thereof, thereby forming a second liquid stream;
(5) at least a portion of the expanded cooled natural gas stream is in full contact with at least a portion of the second liquid stream within the contact device; and
(6) An improvement is that the volatile residue gas fraction is cooled under pressure to condense at least a portion thereof to form the condensed stream, wherein methane accounts for at least 50 mol% of the natural gas stream. Configure. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a vapor stream and a first liquid stream;
(3) expanding the vapor stream to an intermediate pressure and then directing it to a contact device, whereby a volatile residue gas fraction containing a majority of the methane and light components and a second liquid stream; Form;
(4) expanding the first liquid stream to the intermediate pressure;
(5) directing the second liquid stream and the expanded first liquid stream to a distillation column, wherein the stream is a more volatile steam distillation stream and a hydrocarbon heavier than the methane Separating into relatively less volatile fractions containing the majority of the components;
(6) cooling the more volatile vapor distillation stream sufficiently to condense at least a portion thereof, thereby forming a third liquid stream;
(7) bringing at least a portion of the expanded vapor stream into full contact with at least a portion of the third liquid stream in the contact device; and
(8) An improvement is that the volatile residue gas fraction is cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream, wherein methane is at least 50 mol% of the natural gas stream. Configure. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) expanding the cooled natural gas stream to an intermediate pressure and then directing it to the contact device, thereby forming a first vapor stream and a first liquid stream;
(3) directing the first liquid stream to a distillation column, wherein the stream is relatively volatile containing a more volatile vapor distillation stream and a majority of hydrocarbon components heavier than the methane; Separate into less likely fractions;
(4) cooling the more volatile vapor distillation stream sufficiently to condense at least a portion thereof, thereby forming a second vapor stream and a second liquid stream; (5) the first Directing a portion of the two liquid streams to the distillation column as an upper feed to the distillation column; and
(6) at least a portion of the expanded cooled natural gas stream is in full contact with at least a portion of the remaining portion of the second liquid stream in the contact device;
(7) mixing the first vapor stream with the second vapor stream to form a volatile residue gas fraction containing a majority of the methane and light components; and
(8) The volatile residue gas fraction is cooled under pressure to condense at least a part thereof to form the condensed stream, and methane contains at least 50 mol% of the natural gas stream. Configure. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a first vapor stream and a first liquid stream;
(3) expanding the first vapor stream to an intermediate pressure and then directing it to the contact device, thereby forming a second vapor stream and a second liquid stream;
(4) expanding the first liquid stream to the intermediate pressure;
(5) directing the second liquid stream and the expanded first liquid stream to a distillation column, wherein the stream is a more volatile steam distillation stream and a hydrocarbon heavier than the methane Separating into relatively less volatile fractions containing the majority of the components;
(6) cooling the more volatile vapor distillation stream sufficiently to condense at least a portion thereof, thereby forming a third vapor stream and a third liquid stream; (7) the first Directing a portion of the three liquid streams to the distillation column as an upper feed to the distillation column;
(8) bringing at least a portion of the expanded first vapor stream into full contact with at least a portion of the remaining portion of the third liquid stream in the contact device;
(9) mixing the second vapor stream with the third vapor stream to form a volatile residue gas fraction containing a majority of the methane and light components; and
(10) An improvement is that the volatile residue gas fraction is cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream, wherein methane is at least 50 mol% of the natural gas stream. Configure. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) expanding the cooled natural gas stream to an intermediate pressure and then directing it to a contact device, whereby a volatile residue gas fraction containing a majority of the methane and light components, and a first liquid; Form a stream;
(3) heating the first liquid stream and then directing it to a distillation column, where the stream contains a more volatile steam distillation stream and a majority of hydrocarbon components heavier than the methane. Separating into relatively less volatile fractions;
(4) cooling the more volatile vapor distillation stream sufficiently to condense at least a portion thereof, thereby forming a second liquid stream;
(5) bringing at least a portion of the expanded cooled natural gas stream into full contact with at least a portion of the second liquid stream within the contact device; and
(6) An improvement is that the volatile residue gas fraction is cooled under pressure to condense at least a portion thereof to form the condensed stream, wherein methane accounts for at least 50 mol% of the natural gas stream. Configure. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide a vapor stream and a first liquid stream;
(3) expanding the vapor stream to an intermediate pressure and then directing it to a contact device, whereby a volatile residue gas fraction containing a majority of the methane and light components and a second liquid stream; Form;
(4) heating the second liquid stream;
(5) expanding the first liquid stream to the intermediate pressure;
(6) directing the heated second liquid stream and the expanded first liquid stream to a distillation column, wherein the stream is more volatile than the volatile vapor distillation stream and heavier than the methane. Separating into a relatively less volatile fraction containing the majority of the hydrocarbon components of
(7) cooling the more volatile vapor distillation stream sufficient to condense at least a portion thereof, thereby forming a third liquid stream;
(8) bringing at least a portion of the expanded vapor stream into full contact with at least a portion of the third liquid stream in the contact device; and
(9) An improvement is that the volatile residue gas fraction is cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream, wherein methane is at least 50 moles of the natural gas stream. Make up%. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) inflating the cooled natural gas stream to an intermediate pressure and then directing it to a contact device, thereby forming the first vapor stream and the first liquid stream; (3) the first The liquid stream is heated and then directed to a distillation column where the stream is relatively less volatile containing a more volatile vapor distillation stream and a majority of hydrocarbon components heavier than the methane. Separate into fractions;
(4) cooling the more volatile vapor distillation stream sufficiently to condense at least a portion thereof, thereby forming a second vapor stream and a second liquid stream; (5) the first Directing a portion of the two liquid streams to the distillation column as an upper feed to the distillation column;
(6) at least a portion of the expanded cooled natural gas stream is in full contact with at least a portion of the remaining portion of the second liquid stream in the contact device;
(7) mixing the first vapor stream with the second vapor stream to form a volatile residue gas fraction containing a majority of the methane and light components; and
(8) An improvement is that the volatile residue gas fraction is cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream, wherein methane is at least 50 mol% of the natural gas stream. Configure. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to condense a portion thereof;
(2) separating the partially condensed natural gas stream to provide a first vapor stream and a first liquid stream;
(3) inflating the first gas stream to an intermediate pressure and then directing it to the contact device;
This forms a second vapor stream and a second liquid stream;
(4) heating the second liquid stream;
(5) expanding the first liquid stream to the intermediate pressure;
(6) directing the heated second liquid stream and the expanded first liquid stream to a distillation column, wherein the stream is more volatile steam distillation stream and heavier than the methane. Separating into a relatively less volatile fraction containing the majority of the hydrocarbon components;
(7) cooling the more volatile vapor distillation stream sufficiently to condense at least a portion thereof, thereby forming a third vapor stream and a third liquid stream;
(8) directing a portion of the third liquid stream to the distillation column as an upper feed to the distillation column;
(9) bringing at least a portion of the expanded first vapor stream into full contact with at least a portion of the remaining portion of the third liquid stream in the contact device;
(10) mixing the second vapor stream with the third vapor stream to form a volatile residue gas fraction containing a majority of the methane and light components; and
(11) An improvement is that the volatile residue gas fraction is cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream, wherein methane is at least 50 mol% of the natural gas stream. Configure. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating the natural gas stream in one or more cooling stages;
(2) expanding the cooled natural gas stream to the intermediate pressure;
(3) directing the expanded cooled natural gas stream to a distillation column, wherein the expanded cooled natural gas stream comprises a volatile residue gas fraction containing a majority of the methane and light components; Separated into a relatively less volatile fraction containing the majority of the hydrocarbon components heavier than the methane; and
(4) An improvement is that the volatile residue gas fraction is cooled under pressure to condense at least a portion thereof to form the condensed stream, wherein methane accounts for at least 50 mol% of the natural gas stream. Configure. A method for liquefying a natural gas stream containing methane and a hydrocarbon component heavier than methane,
(a) cooling the natural gas stream under pressure to condense at least a portion thereof to form a condensed stream; and
(b) expanding the condensed stream to a low pressure to form the liquefied natural gas stream;
In said method,
(1) treating said natural gas stream in one or more cooling stages to partially condense;
(2) separating the partially condensed natural gas stream to provide at least a vapor stream and a liquid;
(3) expanding the steam stream to an intermediate pressure;
(4) expanding the liquid stream to an intermediate pressure;
(5) directing at least the expanded vapor stream and the expanded liquid stream to a distillation column, wherein the stream is a volatile residue gas fraction containing a majority of the methane and light components; Separating into a relatively less volatile fraction containing a majority of the hydrocarbon components heavier than the methane; and
(6) The volatile residue gas fraction is cooled under pressure to condense at least a portion thereof, thereby forming a condensed stream, which is an improvement consisting essentially of methane, It constitutes at least 50 mol% of the natural gas stream. 15. The volatile residue gas fraction is compressed and then cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream. , 15, 16, 17, 18, 19 or 20. (1) compressing the volatile residue gas fraction and then cooling under pressure to condense at least a portion thereof; and
(2) The improvement according to claim 1 or 6, wherein the condensing part is divided into at least two parts, thereby forming the condensate stream and the liquid stream. (1) compressing the volatile residue gas fraction and then cooling under pressure to condense at least a portion thereof; and
(2) The improvement of claim 2, 7 or 8, wherein the condensing part is divided into at least two parts, thereby forming the condensate stream and a second liquid stream. The improvement of claim 9, wherein the more volatile vapor distillation stream is compressed and then mixed with the vapor stream to form a volatile residue gas fraction containing a majority of the methane and light components. point. 11. The more volatile steam distillation stream is compressed and then mixed with the second steam stream to form a volatile residue gas fraction containing a majority of the methane and light components. Improvements described in. The volatile residue gas fraction is heated, compressed, and then cooled under pressure to condense at least a portion thereof, thereby forming the condensed stream. The improvement according to 13, 14, 15, 16, 17, 18, 19 or 20. (1) heating, compressing said volatile residue gas fraction, then cooling under pressure to condense at least a portion thereof; and
(2) The improvement according to claim 1 or 6, wherein the condensing part is divided into at least two parts, thereby forming the condensate stream and the liquid stream. (1) heating, compressing said volatile residue gas fraction, then cooling under pressure to condense at least a portion thereof; and
(2) The improvement of claim 2, 7 or 8, wherein the condensing part is divided into at least two parts, thereby forming the condensate stream and the liquid stream. Heating, compressing and cooling the more volatile steam distillation stream and then mixing with the steam stream to form the volatile residue gas component containing a majority of the methane and light components; The improvement according to claim 9. The more volatile vapor distillation stream is heated, compressed, cooled, and then mixed with the second vapor stream to remove the volatile residue gas component containing the majority of the methane and light components. The improvement of claim 10, which forms. It said volatile residue gas fraction contains a major portion, light components and C ₂ components of the methane, claims 1,2,3,4,5,6,7,8,9,10,11,12, The improvement according to 13, 14, 15, 16, 17, 18, 19, 20, 21, 22, 23, 24, 25, 26, 27, 28, 29 or 30. The majority of the volatile residue gas fraction the methane, lighter components, containing C ₂ components and C ₃ components, claim 1,2,3,4,5,6,7,8,9,10, The improvement according to 11, 12, 13, 14, 15, 16, 17, 18, 19, 20, 21, 22, 23, 24, 25, 26, 27, 28, 29, or 30. It said volatile residue gas fraction, most of the methane, containing the lighter components and C ₂ components, improvement of claim 21. It said volatile residue gas fraction, most of the methane, containing the lighter components and C ₂ components, improvement of claim 22. It said volatile residue gas fraction, most of the methane, containing the lighter components and C ₂ components, improvement of claim 23. It said volatile residue gas fraction, most of the methane, containing the lighter components and C ₂ components, improvement of claim 26. It said volatile residue gas fraction, most of the methane, containing the lighter components and C ₂ components, improvement of claim 27. It said volatile residue gas fraction, most of the methane, containing the lighter components and C ₂ components, improvement of claim 28. It said volatile residue gas fraction, most of the methane, lighter components, improvement of claim 21 containing a C ₂ component and the C ₃ components. It said volatile residue gas fraction, most of the methane, lighter components, containing a C ₂ component and the C ₃ components, improvement of claim 22. It said volatile residue gas fraction, most of the methane, lighter components, containing a C ₂ component and the C ₃ components, improvement of claim 23. It said volatile residue gas fraction, most of the methane, lighter components, containing a C ₂ component and the C ₃ components, improvement of claim 26. It said volatile residue gas fraction, most of the methane, lighter components, containing a C ₂ component and the C ₃ components, improvement of claim 27. It said volatile residue gas fraction, most of the methane, lighter components, containing a C ₂ component and the C ₃ components, improvement of claim 28.

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