Patent Application
20140096563
This invention relates to a process for the separation of ethane and heavier hydrocarbons or propane and heavier hydrocarbons from liquefied natural gas (hereinafter referred to as LNG) combined with the separation of a gas containing hydrocarbons to provide a volatile methane-rich gas stream and a less volatile natural gas liquids (NGL) or liquefied petroleum gas (LPG) stream. The applicants claim the benefits under Title 35, United States Code, Section 119(e) of prior U.S. Provisional Application No. 61/053,814 which was filed on May 16, 2008.
As an alternative to transportation in pipelines, natural gas at remote locations is sometimes liquefied and transported in special LNG tankers to appropriate LNG receiving and storage terminals. The LNG can then be re-vaporized and used as a gaseous fuel in the same fashion as natural gas. Although LNG usually has a major proportion of methane, i.e., methane comprises at least 50 mole percent of the LNG, it also contains relatively lesser amounts of heavier hydrocarbons such as ethane, propane, butanes, and the like, as well as nitrogen. It is often necessary to separate some or all of the heavier hydrocarbons from the methane in the LNG so that the gaseous fuel resulting from vaporizing the LNG conforms to pipeline specifications for heating value. In addition, it is often also desirable to separate the heavier hydrocarbons from the methane and ethane because these hydrocarbons have a higher value as liquid products (for use as petrochemical feedstocks, as an example) than their value as fuel.
Although there are many processes which may be used to separate ethane and/or propane and heavier hydrocarbons from LNG, these processes often must compromise between high recovery, low utility costs, and process simplicity (and hence low capital investment). U.S. Pat. Nos. 2,952,984; 3,837,172; 5,114,451; and 7,155,931 describe relevant LNG processes capable of ethane or propane recovery while producing the lean LNG as a vapor stream that is thereafter compressed to delivery pressure to enter a gas distribution network. However, lower utility costs may be possible if the lean LNG is instead produced as a liquid stream that can be pumped (rather than compressed) to the delivery pressure of the gas distribution network, with the lean LNG subsequently vaporized using a low level source of external heat or other means. U.S. Pat. Nos. 6,604,380; 6,907,752; 6,941,771; 7,069,743; and 7,216,507 and co-pending application Ser. Nos. 11/749,268 and 12/060,362 describe such processes.
Economics and logistics often dictate that LNG receiving terminals be located close to the natural gas transmission lines that will transport the re-vaporized LNG to consumers. In many cases, these areas also have plants for processing natural gas produced in the region to recover the heavier hydrocarbons contained in the natural gas. Available processes for separating these heavier hydrocarbons include those based upon cooling and refrigeration of gas, oil absorption, and refrigerated oil absorption. Additionally, cryogenic processes have become popular because of the availability of economical equipment that produces power while simultaneously expanding and extracting heat from the gas being processed. Depending upon the pressure of the gas source, the richness (ethane, ethylene, and heavier hydrocarbons content) of the gas, and the desired end products, each of these processes or a combination thereof may be employed.
The cryogenic expansion process is now generally preferred for natural gas liquids recovery because it provides maximum simplicity with ease of startup, operating flexibility, good efficiency, safety, and good reliability. U.S. Pat. Nos. 3,292,380; 4,061,481; 4,140,504; 4,157,904; 4,171,964; 4,185,978; 4,251,249; 4,278,457; 4,519,824; 4,617,039; 4,687,499; 4,689,063; 4,690,702; 4,854,955; 4,869,740; 4,889,545; 5,275,005; 5,555,748; 5,566,554; 5,568,737; 5,771,712; 5,799,507; 5,881,569; 5,890,378; 5,983,664; 6,182,469; 6,578,379; 6,712,880; 6,915,662; 7,191,617; 7,219,513; reissue U.S. Pat. No. 33,408; and co-pending application Ser. Nos. 11/430,412; 11/839,693; 11/971,491; and 12/206,230 describe relevant processes (although the description of the present invention is based on different processing conditions than those described in the cited U.S. patents).
The present invention is generally concerned with the integrated recovery of ethylene, ethane, propylene, propane, and heavier hydrocarbons from such LNG and gas streams. It uses a novel process arrangement to integrate the heating of the LNG stream and the cooling of the gas stream to eliminate the need for a separate vaporizer and the need for external refrigeration, allowing high C2 component recovery while keeping the processing equipment simple and the capital investment low. Further, the present invention offers a reduction in the utilities (power and heat) required to process the LNG and gas streams, resulting in lower operating costs than other processes, and also offering significant reduction in capital investment.
Heretofore, assignee's U.S. Pat. No. 7,216,507 has been used to recover C2 components and heavier hydrocarbon components in plants processing LNG, while assignee's U.S. Pat. No. 5,568,737 has been used to recover C2 components and heavier hydrocarbon components in plants processing natural gas. Surprisingly, applicants have found that by integrating certain features of the assignee's U.S. Pat. No. 7,216,507 invention with certain features of the assignee's U.S. Pat. No. 5,568,737, extremely high C2 component recovery levels can be accomplished using less energy than that required by individual plants to process the LNG and natural gas separately.
A typical analysis of an LNG stream to be processed in accordance with this invention would be, in approximate mole percent, 92.2% methane, 6.0% ethane and other C2 components, 1.1% propane and other C3 components, and traces of butanes plus, with the balance made up of nitrogen. A typical analysis of a gas stream to be processed in accordance with this invention would be, in approximate mole percent, 80.1% methane, 9.5% ethane and other C2 components, 5.6% propane and other C3 components, 1.3% iso-butane, 1.1% normal butane, 0.8% pentanes plus, with the balance made up of nitrogen and carbon dioxide. Sulfur containing gases are also sometimes present.
For a better understanding of the present invention, reference is made to the following examples and drawings. Referring to the drawings:
In the following explanation of the above figures, tables are provided summarizing flow rates calculated for representative process conditions. In the tables appearing herein, the values for flow rates (in moles per hour) have been rounded to the nearest whole number for convenience. The total stream rates shown in the tables include all non-hydrocarbon components and hence are generally larger than the sum of the stream flow rates for the hydrocarbon components. Temperatures indicated are approximate values rounded to the nearest degree. It should also be noted that the process design calculations performed for the purpose of comparing the processes depicted in the figures are based on the assumption of no heat leak from (or to) the surroundings to (or from) the process. The quality of commercially available insulating materials makes this a very reasonable assumption and one that is typically made by those skilled in the art.
For convenience, process parameters are reported in both the traditional British units and in the units of the Systeme International d'Unites (SI). The molar flow rates given in the tables may be interpreted as either pound moles per hour or kilogram moles per hour. The energy consumptions reported as horsepower (HP) and/or thousand British Thermal Units per hour (MBTU/Hr) correspond to the stated molar flow rates in pound moles per hour. The energy consumptions reported as kilowatts (kW) correspond to the stated molar flow rates in kilogram moles per hour.
The inlet gas stream 31 is cooled in heat exchanger 12 by heat exchange with a portion (stream 72a) of partially warmed LNG at −174° F. [−114° C.] and cool distillation stream 38a at −107° F. [−77° C.]. The cooled stream 31a enters separator 13 at −79° F. [−62° C.] and 584 psia [4,027 kPa(a)] where the vapor (stream 34) is separated from the condensed liquid (stream 35). Liquid stream 35 is flash expanded through an appropriate expansion device, such as expansion valve 17, to the operating pressure (approximately 430 psia [2,965 kPa(a)]) of fractionation tower 20. The expanded stream 35a leaving expansion valve 17 reaches a temperature of −93° F. [−70° C.] and is supplied to fractionation tower 20 at a first mid-column feed point.
The vapor from separator 13 (stream 34) enters a work expansion machine 10 in which mechanical energy is extracted from this portion of the high pressure feed. The machine 10 expands the vapor substantially isentropically to slightly above the tower operating pressure, with the work expansion cooling the expanded stream 34a to a temperature of approximately −101° F. [−74° C.]. The typical commercially available expanders are capable of recovering on the order of 80-88% of the work theoretically available in an ideal isentropic expansion. The work recovered is often used to drive a centrifugal compressor (such as item 11) that can be used to re-compress the heated distillation stream (stream 38b), for example. The expanded stream 34a is further cooled to −124° F. [−87° C.] in heat exchanger 14 by heat exchange with cold distillation stream 38 at −143° F. [−97° C.], whereupon the partially condensed expanded stream 34b is thereafter supplied to fractionation tower 20 at a second mid-column feed point.
The demethanizer in tower 20 is a conventional distillation column containing a plurality of vertically spaced trays, one or more packed beds, or some combination of trays and packing to provide the necessary contact between the liquids falling downward and the vapors rising upward. The column also includes reboilers (such as reboiler 19) which heat and vaporize a portion of the liquids flowing down the column to provide the stripping vapors which flow up the column to strip the liquid product, stream 41, of methane and lighter components. Liquid product stream 41 exits the bottom of the tower at 99° F. [37° C.], based on a typical specification of a methane to ethane ratio of 0.020:1 on a molar basis in the bottom product.
Overhead distillation stream 43 is withdrawn from the upper section of fractionation tower 20 at −143° F. [−97° C.] and is divided into two portions, streams 44 and 47. The first portion, stream 44, flows to reflux condenser 22 where it is cooled to −237° F. [−149° C.] and totally condensed by heat exchange with a portion (stream 72) of the cold LNG (stream 71a). Condensed stream 44a enters reflux separator 23 wherein the condensed liquid (stream 46) is separated from any uncondensed vapor (stream 45). The liquid stream 46 from reflux separator 23 is pumped by reflux pump 24 to a pressure slightly above the operating pressure of demethanizer 20 and stream 46a is then supplied as cold top column feed (reflux) to demethanizer 20. This cold liquid reflux absorbs and condenses the C2 components and heavier hydrocarbon components from the vapors rising in the upper section of demethanizer 20.
The second portion (stream 47) of overhead vapor stream 43 combines with any uncondensed vapor (stream 45) from reflux separator 23 to form cold distillation stream 38 at −143° F. [−97° C.]. Distillation stream 38 passes countercurrently to expanded stream 34a in heat exchanger 14 where it is heated to −107° F. [−77° C.] (stream 38a), and countercurrently to inlet gas in heat exchanger 12 where it is heated to 47° F. [8° C.] (stream 38b). The distillation stream is then re-compressed in two stages. The first stage is compressor 11 driven by expansion machine 10. The second stage is compressor 21 driven by a supplemental power source which compresses stream 38c to sales line pressure (stream 38d). After cooling to 126° F. [52° C.] in discharge cooler 22, stream 38e combines with warm LNG stream 71b to form the residue gas product (stream 42). Residue gas stream 42 flows to the sales gas pipeline at 1262 psia [8,701 kPa(a)], sufficient to meet line requirements.
The LNG (stream 71) from LNG tank 50 enters pump 51 at −251° F. [−157° C.]. Pump 51 elevates the pressure of the LNG sufficiently so that it can flow through heat exchangers and thence to the sales gas pipeline. Stream 71a exits the pump 51 at −242° F. [−152° C.] and 1364 psia [9,401 kPa(a)] and is divided into two portions, streams 72 and 73. The first portion, stream 72, is heated as described previously to −174° F. [−114° C.] in reflux condenser 22 as it provides cooling to the portion (stream 44) of overhead vapor stream 43 from fractionation tower 20, and to 43° F. [6° C.] in heat exchanger 12 as it provides cooling to the inlet gas. The second portion, stream 73, is heated to 35° F. [2° C.] in heat exchanger 53 using low level utility heat. The heated streams 72b and 73a recombine to form warm LNG stream 71b at 40° F. [4° C.], which thereafter combines with distillation stream 38e to form residue gas stream 42 as described previously.
A summary of stream flow rates and energy consumption for the process illustrated in
The recoveries reported in Table I are computed relative to the total quantities of ethane, propane, and butanes+ contained in the gas stream being processed in the plant and in the LNG stream. Although the recoveries are quite high relative to the heavier hydrocarbons contained in the gas being processed (99.58%, 100.00%, and 100.00%, respectively, for ethane, propane, and butanes+), none of the heavier hydrocarbons contained in the LNG stream are captured in the
In the simulation of the
The second portion, stream 76, is heated to −79° F. [−62° C.] in heat exchanger 52 by cooling compressed overhead distillation stream 79a at −70° F. [−57° C.]and reflux stream 82 at −128° F. [−89° C.]. The partially heated stream 76a is further heated and vaporized in heat exchanger 53 using low level utility heat. The heated stream 76b at −5° F. [−20° C.] and 1334 psia [9,195 kPa(a)] enters work expansion machine 55 in which mechanical energy is extracted from this portion of the high pressure feed. The machine 55 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 76c to a temperature of approximately −107° F. [−77° C.] before it is supplied as feed to fractionation column 62 at a lower mid-column feed point.
The demethanizer in fractionation column 62 is a conventional distillation column containing a plurality of vertically spaced trays, one or more packed beds, or some combination of trays and packing consisting of two sections. The upper absorbing (rectification) section contains the trays and/or packing to provide the necessary contact between the vapors rising upward and cold liquid falling downward to condense and absorb the ethane and heavier components; the lower stripping (demethanizing) section contains the trays and/or packing to provide the necessary contact between the liquids falling downward and the vapors rising upward. The demethanizing section also includes one or more reboilers (such as side reboiler 60 using low level utility heat, and reboiler 61 using high level utility heat) which heat and vaporize a portion of the liquids flowing down the column to provide the stripping vapors which flow up the column. The column liquid stream 80 exits the bottom of the tower at 54° F. [12° C.], based on a typical specification of a methane to ethane ratio of 0.020:1 on a molar basis in the bottom product.
Overhead distillation stream 79 is withdrawn from the upper section of fractionation tower 62 at −144° F. [−98° C.] and flows to compressor 56 driven by expansion machine 55, where it is compressed to 807 psia [5,567 kPa(a)] (stream 79a). At this pressure, the stream is totally condensed as it is cooled to −128° F. [−89° C.] in heat exchanger 52 as described previously. The condensed liquid (stream 79b) is then divided into two portions, streams 83 and 82. The first portion (stream 83) is the methane-rich lean LNG stream, which is pumped by pump 63 to 1270 psia [8,756 kPa(a)] for subsequent vaporization in heat exchanger 12, heating stream 83a to 40° F. [4° C.] as described in paragraph [0033] below to produce warm lean LNG stream 83b.
The remaining portion of condensed liquid stream 79b, reflux stream 82, flows to heat exchanger 52 where it is subcooled to −237° F. [−149° C.] by heat exchange with a portion of the cold LNG (stream 76) as described previously. The subcooled stream 82a is then expanded to the operating pressure of demethanizer 62 by expansion valve 57. The expanded stream 82b at −236° F. [−149° C.] is then supplied as cold top column feed (reflux) to demethanizer 62. This cold liquid reflux absorbs and condenses the C2 components and heavier hydrocarbon components from the vapors rising in the upper rectification section of demethanizer 62.
In the simulation of the
Vapor stream 33 from separator 13 is divided into two streams, 32 and 34. Stream 32, containing about 22% of the total vapor, passes through heat exchanger 14 in heat exchange relation with cold distillation stream 38 at −150° F. [−101° C.] where it is cooled to substantial condensation. The resulting substantially condensed stream 32a at −144° F. [−98° C.] is then flash expanded through an appropriate expansion device, such as expansion valve 16, to the operating pressure of fractionation tower 20, cooling stream 32b to −148° F. [−100° C.] before it is supplied to fractionation tower 20 at an upper mid-column feed point.
The remaining 78% of the vapor from separator 13 (stream 34) enters a work expansion machine 10 in which mechanical energy is extracted from this portion of the high pressure feed. The machine 10 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 34a to a temperature of approximately −100° F. [−73° C.]. The partially condensed expanded stream 34a is thereafter supplied as feed to fractionation tower 20 at a second lower mid-column feed point.
The demethanizer in fractionation column 20 is a conventional distillation column containing a plurality of vertically spaced trays, one or more packed beds, or some combination of trays and packing consisting of two sections. The upper absorbing (rectification) section contains the trays and/or packing to provide the necessary contact between the vapors rising upward and cold liquid falling downward to condense and absorb the ethane and heavier components; the lower stripping (demethanizing) section contains the trays and/or packing to provide the necessary contact between the liquids falling downward and the vapors rising upward. The demethanizing section also includes one or more reboilers (such as the side reboiler in heat exchanger 12 described previously, and reboiler 19 using high level utility heat) which heat and vaporize a portion of the liquids flowing down the column to provide the stripping vapors which flow up the column. The column liquid stream 40 exits the bottom of the tower at 85° F. [30° C.], based on a typical specification of a methane to ethane ratio of 0.020:1 on a molar basis in the bottom product, and combines with stream 80 to form the liquid product (stream 41).
Overhead distillation stream 38 is withdrawn from the upper section of fractionation tower 20 at −150° F. [−101° C.]. It passes countercurrently to vapor stream 32 and recycle stream 36a in heat exchanger 14 where it is heated to −96° F. [−71° C.] (stream 38a), and countercurrently to inlet gas stream 31 and recycle stream 36 in heat exchanger 12 where it is heated to 6° F. [−15° C.] (stream 38b). The distillation stream is then re-compressed in two stages. The first stage is compressor 11 driven by expansion machine 10. The second stage is compressor 21 driven by a supplemental power source which compresses stream 38c to sales line pressure (stream 38d). After cooling to 126° F. [52° C.] in discharge cooler 22, stream 38e is divided into two portions, stream 37 and recycle stream 36. Stream 37 combines with warm lean LNG stream 83b to form the residue gas product (stream 42). Residue gas stream 42 flows to the sales gas pipeline at 1262 psia [8,701 kPa(a)], sufficient to meet line requirements.
Recycle stream 36 flows to heat exchanger 12 and is cooled to −102° F. [−75° C.] by heat exchange with cool lean LNG (stream 83a), cool distillation stream 38a, and demethanizer liquids (stream 39) as described previously. Stream 36a is further cooled to −144° F. [−98° C.] by heat exchange with cold distillation stream 38 in heat exchanger 14 as described previously. The substantially condensed stream 36b is then expanded through an appropriate expansion device, such as expansion valve 15, to the demethanizer operating pressure, resulting in cooling of the total stream to −152° F. [−102° C.]. The expanded stream 36c is then supplied to fractionation tower 20 as the top column feed. The vapor portion of stream 36c combines with the vapors rising from the top fractionation stage of the column to form distillation stream 38, which is withdrawn from an upper region of the tower as described above.
A summary of stream flow rates and energy consumption for the process illustrated in
Comparison of the recovery levels displayed in Tables I and II shows that the liquids recovery of the
In the simulation of the
The second portion, stream 73, is heated prior to entering separator 54 so that all or a portion of it is vaporized. In the example shown in
The heated stream 76a enters separator 54 at −5° F. [−20° C.] and 1334 psia [9,195 kPa(a)] where the vapor (stream 77) is separated from any remaining liquid (stream 78). Vapor stream 77 enters a work expansion machine 55 in which mechanical energy is extracted from this portion of the high pressure feed. The machine 55 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 77a to a temperature of approximately −107° F. [−77° C.]. The work recovered is often used to drive a centrifugal compressor (such as item 56) that can be used to re-compress the column overhead vapor (stream 79), for example. The partially condensed expanded stream 77a is thereafter supplied as feed to fractionation column 62 at a lower mid-column feed point. The separator liquid (stream 78), if any, is expanded to the operating pressure of fractionation column 62 by expansion valve 59 before expanded stream 78a is supplied to fractionation tower 62 at a second lower mid-column feed point.
The demethanizer in fractionation column 62 is a conventional distillation column containing a plurality of vertically spaced trays, one or more packed beds, or some combination of trays and packing. The fractionation tower 62 may consist of two sections. The upper absorbing (rectification) section contains the trays and/or packing to provide the necessary contact between the vapors rising upward and cold liquid falling downward to condense and absorb the ethane and heavier components; the lower stripping (demethanizing) section contains the trays and/or packing to provide the necessary contact between the liquids falling downward and the vapors rising upward. The demethanizing section also includes one or more reboilers (such as side reboiler 60 using low level utility heat, and reboiler 61 using high level utility heat) which heat and vaporize a portion of the liquids flowing down the column to provide the stripping vapors which flow up the column. The column liquid stream 80 exits the bottom of the tower at 54° F. [12° C.], based on a typical specification of a methane to ethane ratio of 0.020:1 on a molar basis in the bottom product.
Overhead distillation stream 79 is withdrawn from the upper section of fractionation tower 62 at −144° F. [−98° C.] and flows to compressor 56 driven by expansion machine 55, where it is compressed to 805 psia [5,554 kPa(a)] (stream 79a). At this pressure, the stream is totally condensed as it is cooled to −116° F. [−82° C.] in heat exchanger 52 as described previously. The condensed liquid (stream 79b) is then divided into two portions, streams 83 and 81. The first portion (stream 83) is the methane-rich lean LNG stream, which is pumped by pump 63 to 1275 psia [8,791 kPa(a)] for subsequent vaporization in heat exchangers 14 and 12, heating stream 83a to −94° F. [−70° C.] and 40° F. [4° C.], respectively, as described in paragraphs [0048] and [0050] below to produce warm lean LNG stream 83c.
The remaining portion of condensed liquid stream 79b, stream 81, flows to heat exchanger 52 where it is subcooled to −237° F. [−149° C.] by heat exchange with a portion of the cold LNG (stream 73) as described previously. The subcooled stream 81a is then divided into two portions, streams 82 and 36. The first portion, reflux stream 82, is expanded to the operating pressure of demethanizer 62 by expansion valve 57. The expanded stream 82a at −236° F. [−149° C.] is then supplied as cold top column feed (reflux) to demethanizer 62. This cold liquid reflux absorbs and condenses the C2 components and heavier hydrocarbon components from the vapors rising in the upper rectification section of demethanizer 62. The disposition of the second portion, reflux stream 36 for demethanizer 20, is described in paragraph [0051] below.
In the simulation of the
The second portion of feed stream 31, stream 33, enters a work expansion machine 10 in which mechanical energy is extracted from this portion of the high pressure feed. The machine 10 expands the vapor substantially isentropically to a pressure slightly above the operating pressure of fractionation tower 20, with the work expansion cooling the expanded stream 33a to a temperature of approximately 92° F. [33° C.]. The work recovered is often used to drive a centrifugal compressor (such as item 11) that can be used to re-compress the heated distillation stream (stream 38b), for example. The expanded stream 33a is further cooled in heat exchanger 12 by heat exchange with cool lean LNG (stream 83b), cool distillation stream 38a, and demethanizer liquids (stream 39) as described previously. The further cooled stream 33b enters separator 13 at −84° F. [−65° C.] and 423 psia [2,916 kPa(a)] where the vapor (stream 34) is separated from the condensed liquid (stream 35).
Vapor stream 34 is cooled to −120° F. [−85° C.] in heat exchanger 14 by heat exchange with cold lean LNG (stream 83a) and cold distillation stream 38 as described previously. The partially condensed stream 34a is then supplied to fractionation tower 20 at a first lower mid-column feed point. Liquid stream 35 is flash expanded through an appropriate expansion device, such as expansion valve 17, to the operating pressure of fractionation tower 20. The expanded stream 35a leaving expansion valve 17 reaches a temperature of −85° F. [−65° C.] and is supplied to fractionation tower 20 at a second lower mid-column feed point.
The second portion of subcooled stream 81a, reflux stream 36, is expanded to the operating pressure of demethanizer 20 by expansion valve 15. The expanded stream 36a at −236° F. [−149° C.] is then supplied as cold top column feed (reflux) to demethanizer 20. This cold liquid reflux absorbs and condenses the C2 components and heavier hydrocarbon components from the vapors rising in upper rectification section 20a of demethanizer 20.
The demethanizer in fractionation column 20 is a conventional distillation column containing a plurality of vertically spaced trays, one or more packed beds, or some combination of trays and packing. The fractionation tower 20 may consist of two sections. The upper absorbing (rectification) section 20a contains the trays and/or packing to provide the necessary contact between the vapors rising upward and cold liquid falling downward to condense and absorb the ethane and heavier components; the lower stripping (demethanizing) section 20b contains the trays and/or packing to provide the necessary contact between the liquids falling downward and the vapors rising upward. Demethanizing section 20b also includes one or more reboilers (such as the side reboiler in heat exchanger 12 described previously, and reboiler 19 using high level utility heat) which heat and vaporize a portion of the liquids flowing down the column to provide the stripping vapors which flow up the column. The column liquid stream 40 exits the bottom of the tower at 95° F. [35° C.], based on a typical specification of a methane to ethane ratio of 0.020:1 on a molar basis in the bottom product, and combines with stream 80 to form the liquid product (stream 41).
Overhead distillation stream 38 is withdrawn from the upper section of fractionation tower 20 at −144° F. [−98° C.]. It passes countercurrently to the first portion (stream 32a) of inlet gas stream 31 and vapor stream 34 in heat exchanger 14 where it is heated to −94° F. [−70° C.] (stream 38a), and countercurrently to the first portion (stream 32) of inlet gas stream 31 and expanded second portion (stream 33a) in heat exchanger 12 where it is heated to 13° F. [−11° C.] (stream 38b). The distillation stream is then re-compressed in two stages. The first stage is compressor 11 driven by expansion machine 10. The second stage is compressor 21 driven by a supplemental power source which compresses stream 38c to sales gas line pressure (stream 38d). After cooling to 126° F. [52° C.] in discharge cooler 22, stream 38e combines with warm lean LNG stream 83c to form the residue gas product (stream 42). Residue gas stream 42 flows to the sales gas pipeline at 1262 psia [8,701 kPa(a)], sufficient to meet line requirements.
A summary of stream flow rates and energy consumption for the process illustrated in
The improvement offered by the
Comparing the recovery levels displayed in Table III for the
There are six primary factors that account for the improved efficiency of the present invention. First, compared to many prior art processes, the present invention does not depend on the LNG feed itself to directly serve as the reflux for fractionation column 62. Rather, the refrigeration inherent in the cold LNG is used in heat exchanger 52 to generate a liquid reflux stream (stream 82) that contains very little of the C2 components and heavier hydrocarbon components that are to be recovered, resulting in efficient rectification in the absorbing section of fractionation tower 62 and avoiding the equilibrium limitations of such prior art processes. Second, splitting the LNG feed into two portions before feeding fractionation column 62 allows more efficient use of low level utility heat, thereby reducing the amount of high level utility heat consumed by reboiler 61. The cold portion of the LNG feed (stream 75a) serves as a supplemental reflux stream for fractionation tower 62, providing partial rectification of the vapors in the expanded vapor and liquid streams (streams 77a and 78a, respectively) so that heating and at least partially vaporizing the other portion (stream 73) of the LNG feed does not unduly increase the condensing load in heat exchanger 52. Third, using a portion of the cold LNG feed (stream 75a) as a supplemental reflux stream allows using less top reflux (stream 82a) for fractionation tower 62. The lower top reflux flow, plus the greater degree of heating using low level utility heat in heat exchanger 53, results in less total liquid feeding fractionation column 62, reducing the duty required in reboiler 61 and minimizing the amount of high level utility heat needed to meet the specification for the bottom liquid product from demethanizer 62.
Fourth, using the cold lean LNG stream 83a to provide “free” refrigeration to the gas streams in heat exchangers 12 and 14 eliminates the need for a separate vaporization means (such as heat exchanger 53 in the
An alternative method of processing natural gas is shown in another embodiment of the present invention as illustrated in
In the simulation of the
The second portion, stream 73, is heated prior to entering separator 54 so that all or a portion of it is vaporized. In the example shown in
The column liquid stream 80 exits the bottom of the tower at 54° F. [12° C.], based on a typical specification of a methane to ethane ratio of 0.020:1 on a molar basis in the bottom product. Overhead distillation stream 79 is withdrawn from the upper section of fractionation tower 62 at −144° F. [−98° C.] and flows to compressor 56 driven by expansion machine 55, where it is compressed to 805 psia [5,554 kPa(a)] (stream 79a). At this pressure, the stream is totally condensed as it is cooled to −115° F. [−82° C.] in heat exchanger 52 as described previously. The condensed liquid (stream 79b) is then divided into two portions, streams 83 and 81. The first portion (stream 83) is the methane-rich lean LNG stream, which is pumped by pump 63 to 1270 psia [8,756 kPa(a)] for subsequent vaporization in heat exchanger 12, heating stream 83a to 40° F. [4° C.] as described in paragraph [0064] below to produce warm lean LNG stream 83b.
The remaining portion of condensed liquid stream 79b, stream 81, flows to heat exchanger 52 where it is subcooled to −237° F. [−149° C.] by heat exchange with a portion of the cold LNG (stream 73) as described previously. The subcooled stream 81a is then divided into two portions, streams 82 and 36. The first portion, reflux stream 82, is expanded to the operating pressure of demethanizer 62 by expansion valve 57. The expanded stream 82a at −236° F. [−149° C.] is then supplied as cold top column feed (reflux) to demethanizer 62. This cold liquid reflux absorbs and condenses the C2 components and heavier hydrocarbon components from the vapors rising in the upper rectification section of demethanizer 62. The disposition of the second portion, reflux stream 36 for demethanizer 20, is described in paragraph [0067] below.
In the simulation of the
The second portion of feed stream 31, stream 33, is cooled in heat exchanger 12 by heat exchange with cold lean LNG (stream 83a), cool compressed distillation stream 38b, and demethanizer liquids (stream 39) as described previously. The cooled stream 33a enters separator 13 at −86° F. [−65° C.] and 584 psia [4,027 kPa(a)] where the vapor (stream 34) is separated from the condensed liquid (stream 35). Liquid stream 35 is flash expanded through an appropriate expansion device, such as expansion valve 17, to the operating pressure of fractionation tower 20. The expanded stream 35a leaving expansion valve 17 reaches a temperature of −100° F. [−73° C.] and is supplied to fractionation tower 20 at a first lower mid-column feed point.
The vapor from separator 13 (stream 34) enters a work expansion machine 10 in which mechanical energy is extracted from this portion of the high pressure feed. The machine 10 expands the vapor substantially isentropically to slightly above the tower operating pressure, with the work expansion cooling the expanded stream 34a to a temperature of approximately −106° F. [−77° C.]. The expanded stream 34a is further cooled to −121° F. [−85° C.] in heat exchanger 14 by heat exchange with cold compressed distillation stream 38a as described previously, whereupon the partially condensed expanded stream 34b is thereafter supplied to fractionation tower 20 at a second lower mid-column feed point.
The second portion of subcooled stream 81a, reflux stream 36, is expanded to the operating pressure of demethanizer 20 by expansion valve 15. The expanded stream 36a at −236° F. [−149° C.] is then supplied as cold top column feed (reflux) to demethanizer 20. This cold liquid reflux absorbs and condenses the C2 components and heavier hydrocarbon components from the vapors rising in the upper rectification section of demethanizer 20.
The column liquid stream 40 exits the bottom of the tower at 102° F. [39° C.], based on a typical specification of a methane to ethane ratio of 0.020:1 on a molar basis in the bottom product, and combines with stream 80 to form the liquid product (stream 41). Overhead distillation stream 38 is withdrawn from the upper section of fractionation tower 20 at −141° F. [−96° C.] and flows to compressor 11 driven by expansion machine 10, where it is compressed to 501 psia [3,452 kPa(a)]. The cold compressed distillation stream 38a passes countercurrently to the first portion (stream 32a) of inlet gas stream 31 and expanded vapor stream 34a in heat exchanger 14 where it is heated to −109° F. [−78° C.] (stream 38b), and countercurrently to the first portion (stream 32) and second portion (stream 33) of inlet gas stream 31 in heat exchanger 12 where it is heated to 31° F. [−1° C.] (stream 38c). The heated distillation stream then enters compressor 21 driven by a supplemental power source which compresses stream 38c to sales line pressure (stream 38d). After cooling to 126° F. [52° C.] in discharge cooler 22, stream 38e combines with warm lean LNG stream 83b to form the residue gas product (stream 42). Residue gas stream 42 flows to the sales gas pipeline at 1262 psia [8,701 kPa(a)], sufficient to meet line requirements.
A summary of stream flow rates and energy consumption for the process illustrated in
A comparison of Tables III and IV shows that the
Another alternative method of processing natural gas is shown in the embodiment of the present invention as illustrated in
In the simulation of the
The second portion, stream 73, is heated prior to entering separator 54 so that all or a portion of it is vaporized. In the example shown in
The column liquid stream 80 exits the bottom of the tower at 54° F. [12° C.], based on a typical specification of a methane to ethane ratio of 0.020:1 on a molar basis in the bottom product. Overhead distillation stream 79 is withdrawn from the upper section of fractionation tower 62 at −144° F. [−98° C.] and flows to compressor 56 driven by expansion machine 55, where it is compressed to 805 psia [5,554 kPa(a)] (stream 79a). At this pressure, the stream is totally condensed as it is cooled to −112° F. [−80° C.] in heat exchanger 52 as described previously. The condensed liquid (stream 79b) is then divided into two portions, streams 83 and 81. The first portion (stream 83) is the methane-rich lean LNG stream, which is pumped by pump 63 to 1270 psia [8,756 kPa(a)] for subsequent vaporization in heat exchanger 12, heating stream 83a to 40° F. [4° C.] as described in paragraph [0076] below to produce warm lean LNG stream 83b.
The remaining portion of condensed liquid stream 79b, stream 81, flows to heat exchanger 52 where it is subcooled to −237° F. [−149° C.] by heat exchange with a portion of the cold LNG (stream 73) as described previously. The subcooled stream 81a is then divided into two portions, streams 82 and 36. The first portion, reflux stream 82, is expanded to the operating pressure of demethanizer 62 by expansion valve 57. The expanded stream 82a at −236° F. [−149° C.] is then supplied as cold top column feed (reflux) to demethanizer 62. This cold liquid reflux absorbs and condenses the C2 components and heavier hydrocarbon components from the vapors rising in the upper rectification section of demethanizer 62. The disposition of the second portion, reflux stream 36 for demethanizer 20, is described in paragraph [0079] below.
In the simulation of the
The second portion of feed stream 31, stream 33, enters a work expansion machine 10 in which mechanical energy is extracted from this portion of the high pressure feed. The machine 10 expands the vapor substantially isentropically to a pressure slightly above the operating pressure of fractionation tower 20, with the work expansion cooling the expanded stream 33a to a temperature of approximately 95° F. [35° C.]. The expanded stream 33a is further cooled in heat exchanger 12 by heat exchange with cold lean LNG (stream 83a), cool compressed distillation stream 38b, and demethanizer liquids (stream 39) as described previously. The further cooled stream 33b enters separator 13 at −85° F. [−65° C.] and 436 psia [3,004 kPa(a)] where the vapor (stream 34) is separated from the condensed liquid (stream 35).
Vapor stream 34 is cooled to −100° F. [−74° C.] in heat exchanger 14 by heat exchange with cold compressed distillation stream 38a as described previously. The partially condensed stream 34a is then supplied to fractionation tower 20 at a first lower mid-column feed point. Liquid stream 35 is flash expanded through an appropriate expansion device, such as expansion valve 17, to the operating pressure of fractionation tower 20. The expanded stream 35a leaving expansion valve 17 reaches a temperature of −86° F. [−65° C.] and is supplied to fractionation tower 20 at a second lower mid-column feed point.
The second portion of subcooled stream 81a, reflux stream 36, is expanded to the operating pressure of demethanizer 20 by expansion valve 15. The expanded stream 36a at −236° F. [−149° C.] is then supplied as cold top column feed (reflux) to demethanizer 20. This cold liquid reflux absorbs and condenses the C2 components and heavier hydrocarbon components from the vapors rising in the upper rectification section of demethanizer 20.
The column liquid stream 40 exits the bottom of the tower at 98° F. [37° C.], based on a typical specification of a methane to ethane ratio of 0.020:1 on a molar basis in the bottom product, and combines with stream 80 to form the liquid product (stream 41). Overhead distillation stream 38 is withdrawn from the upper section of fractionation tower 20 at −143° F. [−97° C.] and flows to compressor 11 driven by expansion machine 10, where it is compressed to 573 psia [3,950 kPa(a)]. The cold compressed distillation stream 38a passes countercurrently to the first portion (stream 32a) of inlet gas stream 31 and vapor stream 34 in heat exchanger 14 where it is heated to −91° F. [−68° C.] (stream 38b), and countercurrently to the first portion (stream 32) and expanded second portion (stream 33a) of inlet gas stream 31 in heat exchanger 12 where it is heated to 67° F. [19° C.] (stream 38c). The heated distillation stream then enters compressor 21 driven by a supplemental power source which compresses stream 38c to sales line pressure (stream 38d). After cooling to 126° F. [52° C.] in discharge cooler 22, stream 38e combines with warm lean LNG stream 83b to form the residue gas product (stream 42). Residue gas stream 42 flows to the sales gas pipeline at 1262 psia [8,701 kPa(a)], sufficient to meet line requirements.
A summary of stream flow rates and energy consumption for the process illustrated in
A comparison of Tables III, IV, and V shows that the
An alternative method of processing LNG and natural gas is shown in the embodiment of the present invention as illustrated in
In the simulation of the
The second portion, stream 73, is heated prior to entering separator 54 so that all or a portion of it is vaporized. In the example shown in
In the simulation of the
The second portion of feed stream 31, stream 33, enters a work expansion machine 10 in which mechanical energy is extracted from this portion of the high pressure feed. The machine 10 expands the vapor substantially isentropically to a pressure slightly above the operating pressure of fractionation tower 20, with the work expansion cooling the expanded stream 33a to a temperature of approximately 96° F. [36° C.]. The expanded stream 33a is further cooled in heat exchanger 12 by heat exchange with cold lean LNG (stream 83a), cool compressed distillation stream 38b, and demethanizer liquids (stream 39) as described previously. The further cooled stream 33b enters separator 13 at −90° F. [−68° C.] and 443 psia [3,052 kPa(a)] where the vapor (stream 34) is separated from the condensed liquid (stream 35).
Vapor stream 34 is cooled to −101° F. [−74° C.] in heat exchanger 14 by heat exchange with the partially heated second portion (stream 73a) of the LNG stream and with cold compressed distillation stream 38a as described previously. The partially condensed stream 34a is then supplied to fractionation tower 20 at a third lower mid-column feed point. Liquid stream 35 is flash expanded through an appropriate expansion device, such as expansion valve 17, to the operating pressure of fractionation tower 20. The expanded stream 35a leaving expansion valve 17 reaches a temperature of −90° F. [−68° C.] and is supplied to fractionation tower 20 at a fourth lower mid-column feed point.
The liquid product stream 41 exits the bottom of the tower at 89° F. [32° C.], based on a typical specification of a methane to ethane ratio of 0.020:1 on a molar basis in the bottom product. Overhead distillation stream 79 is withdrawn from the upper section of fractionation tower 20 at −142° F. [−97° C.] and is divided into two portions, stream 81 and stream 38. The first portion (stream 81) flows to compressor 56 driven by expansion machine 55, where it is compressed to 864 psia [5,955 kPa(a)] (stream 81a). At this pressure, the stream is totally condensed as it is cooled to −117° F. [−83° C.] in heat exchanger 52 as described previously. The condensed liquid (stream 81b) is then divided into two portions, streams 83 and 82. The first portion (stream 83) is the methane-rich lean LNG stream, which is pumped by pump 63 to 1270 psia [8,756 kPa(a)] for subsequent vaporization in heat exchanger 12, heating stream 83a to 40° F. [4° C.] as described previously to produce warm lean LNG stream 83b.
The remaining portion of stream 81b (stream 82) flows to heat exchanger 52 where it is subcooled to −237° F. [−149° C.] by heat exchange with a portion of the cold LNG (stream 73) as described previously. The subcooled stream 82a is expanded to the operating pressure of fractionation column 20 by expansion valve 57. The expanded stream 82b at −236° F. [−149° C.] is then supplied as cold top column feed (reflux) to demethanizer 20. This cold liquid reflux absorbs and condenses the C2 components and heavier hydrocarbon components from the vapors rising in the upper rectification section of demethanizer 20.
The second portion of distillation stream 79 (stream 38) flows to compressor 11 driven by expansion machine 10, where it is compressed to 604 psia [4,165 kPa(a)]. The cold compressed distillation stream 38a passes countercurrently to the first portion (stream 32a) of inlet gas stream 31 and vapor stream 34 in heat exchanger 14 where it is heated to −92° F. [−69° C.] (stream 38b), and countercurrently to the first portion (stream 32) and expanded second portion (stream 33a) of inlet gas stream 31 in heat exchanger 12 where it is heated to 48° F. [9° C.] (stream 38c). The heated distillation stream then enters compressor 21 driven by a supplemental power source which compresses stream 38c to sales line pressure (stream 38d). After cooling to 126° F. [52° C.] in discharge cooler 22, stream 38e combines with warm lean LNG stream 83b to form the residue gas product (stream 42). Residue gas stream 42 flows to the sales gas pipeline at 1262 psia [8,701 kPa(a)], sufficient to meet line requirements.
A summary of stream flow rates and energy consumption for the process illustrated in
A comparison of Tables III, IV, V, and VI shows that the
The capital cost of the
Some circumstances may favor using cold distillation stream 38 in the
When the inlet gas is leaner, separator 13 in
In the embodiments of the present invention illustrated in
In the examples shown, total condensation of stream 79b in
Feed gas conditions, LNG conditions, plant size, available equipment, or other factors may indicate that elimination of work expansion machines 10 and/or 55, or replacement with an alternate expansion device (such as an expansion valve), is feasible. Although individual stream expansion is depicted in particular expansion devices, alternative expansion means may be employed where appropriate.
In
In the embodiments of the present invention illustrated in
It will be recognized that the relative amount of feed found in each branch of the split LNG feed to fractionation column 62, in each branch of the split inlet gas to fractionation column 20, and in each branch of the split LNG feed and the split inlet gas to fractionation column 20 will depend on several factors, including inlet gas composition, LNG composition, the amount of heat which can economically be extracted from the feed, and the quantity of horsepower available. More feed to the top of the column may increase recovery while increasing the duty in reboilers 61 and/or 19 and thereby increasing the high level utility heat requirements. Increasing feed lower in the column reduces the high level utility heat consumption but may also reduce product recovery. The relative locations of the mid-column feeds may vary depending on inlet gas composition, LNG composition, or other factors such as the desired recovery level and the amount of vapor formed during heating of the LNG streams. Moreover, two or more of the feed streams, or portions thereof, may be combined depending on the relative temperatures and quantities of individual streams, and the combined stream then fed to a mid-column feed position.
In some circumstance it may be desirable to recover refrigeration from the portion (stream 75a) of LNG feed stream 71 that is fed to an upper mid-column feed point on demethanizer 62 (
In the examples given for the
While there have been described what are believed to be preferred embodiments of the invention, those skilled in the art will recognize that other and further modifications may be made thereto, e.g. to adapt the invention to various conditions, types of feed, or other requirements without departing from the spirit of the present invention as defined by the following claims.
This application is a continuation of U.S. Non-Provisional application Ser. No. 12,423,306, filed on Apr. 14, 2009, which claims the benefit of U.S. Provisional Application No. 61/053,814, filed May 16, 2008, both of which are incorporated herein by reference in their entirety.
| Number | Date | Country | |
|---|---|---|---|
| 20130125582 A1 | May 2013 | US |
| Number | Date | Country | |
|---|---|---|---|
| 61053814 | May 2008 | US |
| Number | Date | Country | |
|---|---|---|---|
| Parent | 12423306 | Apr 2009 | US |
| Child | 13686641 | US |
