US20110036120A1

US20110036120A1 - Method and apparatus for recovering and fractionating a mixed hydrocarbon feed stream

Info

Publication number: US20110036120A1
Application number: US12/669,073
Authority: US
Inventors: Marco Dick Jager; Wouter Jan Meiring
Original assignee: Individual
Current assignee: Shell USA Inc
Priority date: 2007-07-19
Filing date: 2008-07-17
Publication date: 2011-02-17
Also published as: EA016149B1; GB0922540D0; AU2008277656B2; AU2008277656A1; GB2463202B; WO2009010558A3; EA201000224A1; WO2009010558A2; GB2463202A

Abstract

A condensed mixed hydrocarbon feed stream (10), recovered from an initial feed stream (8), is fractionated into one ore more fractionated streams. In this process, the condensed mixed hydrocarbon feed stream (10) is separated into at least a first part-feed stream (20) and a second part-feed stream (30). The first part-feed stream (20) is passed into a first gas/liquid separator (14), to provide at least a first fractionated stream in the form of a first gaseous overhead stream (40). A first bottom liquid stream (50) provided by the first gas/liquid separator (14) is passed into a second gas/liquid separator (22) to provide at least a second fractionated stream in the form of a second gaseous overhead stream (70), which is cooled by heat exchange (26) against the second part-feed stream (30).

Description

The present invention relates to a method and apparatus for recovering a mixed hydrocarbon stream from an initial feed stream, such as a natural gas stream, and fractionating the mixed hydrocarbon feed stream into one or more fractionated streams.
Natural gas is a useful fuel source, as well as a source of various hydrocarbon compounds. It may be produced for distribution in a pipeline grid at or near the source. Sometimes the natural gas is first liquefied in a liquefied natural gas (LNG) plant at or near the source of a natural gas stream for a number of reasons. As an example, natural gas can be stored and transported over long distances more readily as a liquid than in gaseous form because it occupies a small volume and does not need to be stored at high pressure.
Usually, natural gas, comprising predominantly methane, enters an LNG plant at elevated pressures and is pre-treated to produce a purified feed stream suitable for its intended purpose. In case of subsequent liquefaction, the purified feed stream should be suitable for liquefaction at cryogenic temperatures. The purified gas is processed through a plurality of cooling stages using heat exchangers to progressively reduce its temperature until liquefaction is achieved. The liquid natural gas is then further cooled and expanded to final atmospheric pressure suitable for storage and transportation.
In addition to methane, natural gas usually includes some heavier hydrocarbons and impurities, including but not limited to carbon dioxide, sulphur, hydrogen sulphide and other sulphur compounds, nitrogen, helium, water and other non-hydrocarbon acid gases, ethane, propane, butanes, C₅ ⁺ hydrocarbons and aromatic hydrocarbons. These and any other common or known heavier hydrocarbons and impurities either prevent or hinder the usual known methods of liquefying the methane, especially the most efficient methods of liquefying methane. Most if not all known or proposed methods of liquefying hydrocarbons, especially liquefying natural gas, are based on reducing as far as necessary the levels of at least most of the heavier hydrocarbons and impurities prior to the liquefying process.
Hydrocarbons heavier than methane and usually ethane are typically typically removed from the initial feed stream by partly condensing the initial feed stream thereby forming a condensed mixed hydrocarbon feed stream that is subsequently separated from the initial feed stream. In case of the feed stream being formed of natural gas, the condensed mixed hydrocarbon feed stream is recovered as so-called natural gas liquids (NGL).
The mixed hydrocarbon feed stream containing the NGLs is often fractionated to yield valuable hydrocarbon products, either as product steams per se or for use in a process. For example, if the process is liquefaction, the hydrocarbon products may be used as a component of a refrigerant.
Fractionation typically involves separating one or more C₂ ⁺ hydrocarbon streams from a mixed hydrocarbon stream, in particular as or as part of a multi-column natural gas liquids (NGL) recovery system and arrangement.
The use of two or more gas/liquid separators in series is commonly used in NGL recovery known to those skilled in the art. In one example, an NGL extraction unit provides a single heavier hydrocarbon rich stream, which is subsequently used either per se, or is further divided into particular heavier hydrocarbon rich streams in a separate location or unit. The fractionation of a heavier hydrocarbon rich stream can be carried out by one or more further gas/liquid separators known in the art, such as a fractionator.
A fractionator using one or more columns could provide individual streams of certain heavier hydrocarbons. For example, with multiple columns, each column could be designed to provide an individual hydrocarbon stream, such as an ethane-rich stream, a propane-rich stream, a butane-rich stream, and a C₅ ⁺-rich stream, the latter sometimes also termed a ‘light condensate stream’. Propane, butane, C₅ ⁺ hydrocarbons (and optionally ethane) are sometimes collectively termed “natural gas liquids” (NGL), and have known uses.
An example of a fractionation tower as a conventional distillation column for NGL extraction is shown in US 2004/0079107 A1.
In another example, an NGL extraction unit can include a fractionator, which integrally provides individual streams of certain heavier hydrocarbons such as those listed hereinbefore.
NGL recovery thus generally involves cooling, condensation and fractionation steps that require significant amounts of refrigeration and other power consumption. It is desirable to recover NGLs from a natural gas stream with the most efficient or minimal refrigeration power consumption.
U.S. Pat. No. 7,051,553 describes a typical gas separation process, in which a feed gas stream is cooled and liquids condensing from the cooled gas are then expanded and fractionated in a distillation column to separate residual components from desired heavier components. U.S. Pat. No. 7,051,553 also describes a two-column NGL recovery plant having an absorber and a distillation column, with the absorber receiving a second reflux stream comprising the cooled overhead gas of the distillation column. Cooling of the overhead gas from the distillation column is provided by a separate cooler, requiring separate power consumption.
U.S. Pat. No. 6,116,050 discloses methods for separating and recovering propane, propylene, and the C₃ ⁺ hydrocarbons from a feed gas, to produce pipeline gas and a liquid product. The methods employ sequentially configured first and second distillation columns, and a self-refrigeration system which is said to improve the separation efficiency in the first column. The cooled feed gas is separated in a feed separator, and both the vapours and the liquids from the feed separator are fed into the first column. Part of the liquids conducted directly through a line into the first column, while the remaining portion is heated against a vapour overhead stream from the second column prior to introduction into the first column via the same line.
It is an object of the present invention to improve the efficiency of recovery and subsequent fractionation of a mixed hydrocarbon feed stream from an initial feed stream.
In one aspect, the present invention provides a method of recovering a mixed hydrocarbon feed stream from an initial feed stream, such as a natural gas stream, and fractionating the mixed hydrocarbon feed stream into one or more fractionated streams, the method at least comprising the step of:
(a) providing an initial feed stream;
(b) partly condensing the initial feed stream, thereby forming a partly condensed initial feed stream;
(c) separating the partly condensed initial feed stream into an initial gaseous overhead stream and a condensed mixed hydrocarbon feed stream;
(d) dividing the condensed mixed hydrocarbon feed stream into at least a first part-feed stream and a second part-feed stream;
(e) passing the first part-feed stream into a first gas/liquid separator, via a first inlet into the first gas/liquid separator, to provide at least a first fractionated stream in the form of a first gaseous overhead stream and a first bottom liquid stream;
(f) passing the first bottom liquid stream into a second gas/liquid separator to provide at least a second fractionated stream in the form of a second gaseous overhead stream and a second bottom liquid stream; and
(g) cooling the second overhead gaseous stream by heat exchange against the second part-feed stream, resulting in a warmer second part-feed stream;
(h) passing the warmer second part-feed stream into the first gas/liquid separator at a level gravitationally below the first inlet.
In another aspect, the invention provides an apparatus for recovering a mixed hydrocarbon feed stream from an initial feed stream and fractionating the mixed hydrocarbon feed stream into one or more fractionated streams, the apparatus at least comprising:
a pre-cooling heat exchanger arranged to cool the initial feed stream to provide a partly condensed initial feed stream;
an initial gas/liquid separator arranged to separate the partly condensed initial feed stream into an initial gaseous overhead stream and a condensed mixed hydrocarbon stream;
a stream splitter to divide the condensed mixed hydrocarbon feed stream into at least a first part-feed stream and a second part-feed stream;
a first gas/liquid separator arranged to receive the first part-feed stream via a first inlet into the first gas/liquid separator, and to provide at least a first fractionated stream in the form of a first overhead gaseous stream and a first bottom liquid stream;
a second gas/liquid separator arranged to receive the first bottom liquid stream, and to provide at least a second fractionated stream in the form of a second overhead gaseous stream and a second bottom liquid stream;
a heat exchanger arranged to receive the second part-feed stream and the second overhead gaseous stream, and to provide a cooled second overhead gaseous stream and a warmer second part-feed stream; and
a second inlet into the first gas/liquid separator arranged to allow entry of the warmer second part-feed stream into the first gas/liquid separator, the second inlet being at a level gravitationally below the first inlet.

Embodiments and examples of the present invention will now be described by way of example and with reference to the accompanying non-limited drawings in which;

FIG. 1 is a diagrammatic scheme for a method of C₂ ⁺ separation; and

FIG. 2 shows the integration of the method shown in FIG. 1 within a diagrammatic LNG plant.

For the purpose of this description, a single reference number will be assigned to a line as well as a stream carried in that line.
In the embodiments disclosed herein, cooling of the second overhead gaseous stream from the second gas/liquid separator is provided by use of a portion of the cold energy in the condensed mixed hydrocarbon feed stream, rather than requiring any separate refrigeration or cooler involving separate power consumption, or rather than integration with a refrigeration system or circuit associated with a liquefaction process.
Thus, cold energy from another source, such as (pre-) cooling of a hydrocarbon stream such as natural gas by a separate refrigerant, refrigeration system or circuit, need not be diverted to be involved in recovery and fractionation of the mixed hydrocarbon stream, such as in NGL recovery, thereby increasing the efficiency of other processes or sections of a liquefaction plant such as an LNG plant.
The cooling of the second overhead gaseous stream provides a warmer second part-feed stream, which can still be passed into the first gas/liquid separator or used otherwise. The introduction of a fraction of the mixed hydrocarbon feed stream into the first gas/liquid separator at a warmer temperature, (following use of some of its cold energy to cool the second overhead gaseous stream from the second gas/liquid separator), reduces the energy input required from a heat source such as a reboiler to operate the first gas/liquid separator.
It has further been found that an improvement of the separation efficiency and a further decrease of any heating duty from an external source can be achieved by passing the warmer second part-feed stream into the first gas/liquid separator at a height along the separator below where the first part-feed stream is passed into the first gas/liquid separator.
Usually the initial feed stream is comprised substantially of methane. Preferably the feed stream comprises at least 60 mol % methane, more preferably at least 80 mol % methane.
The term “mixed hydrocarbon feed stream” as used herein relates to a feed stream comprising methane and one or more hydrocarbons selected from the group comprising: ethane, propane, butanes, pentanes, and C₆ ⁺ hydrocarbons.
The mixed hydrocarbon feed stream may be provided from any suitable source. Preferably, the mixed hydrocarbon feed stream is provided from an initial feed stream. The initial feed stream may be any suitable hydrocarbon stream such as, but not limited to, a hydrocarbon-containing gas stream to be cooled. One example is a natural gas stream obtained from a natural gas or petroleum reservoir. As an alternative the initial feed stream may also be obtained from another source, such as a refinery and/or including a synthetic source such as a Fischer-Tropsch process.
The term “C₂ ⁺” as used herein relates to one or more components selected from the group comprising: ethane, propane, butanes, pentanes, and C₆ ⁺ hydrocarbons.
Similarly, the term “C₃ ⁺” as used herein relates to one or more components selected from the group comprising: propane, butanes, pentanes, and C6+ hydrocarbons.
The terms “C₄ ⁺”, etc. are similarly defined starting with “butanes”, etc.
Each gas/liquid separator of the present invention may involve one or more columns, and one or each of such columns could provide individual liquid streams of certain heavier hydrocarbons such as ethane, propane, etc.
Any fractionated, or individual stream of C₂ ⁺, C₃ ⁺, C₄ ⁺, etc., may still comprise a minor (<10 mol %) amount of methane; each such stream is preferably >80 mol %, more preferably >95 mol %, of its one or more components as defined above.
The division of a stream such as a feed stream into two or more part streams may be carried out using any suitable stream splitter or divider, which may be a distinct unit, or a simpler division of a line such as a T-Piece.
Although the method according to the present invention is applicable to various initial hydrocarbon-containing feed streams, it is particularly suitable for natural gas streams to be liquefied. As the person skilled readily understands how to liquefy a hydrocarbon stream, this will herein only be discussed at a basic level of detail.
FIG. 1 shows a simplified and general scheme 1 of a method for separating one or more C₂ ⁺ hydrocarbon streams from a mixed hydrocarbon feed stream recovered from an initial feed stream, such as natural gas. The scheme of FIG. 1 can be part of a liquefied natural gas plant 2 shown in FIG. 2.
FIG. 1 illustrates a method and apparatus for separating one or more C₂ ⁺ hydrocarbon streams from an initial feed stream such as natural gas. The apparatus comprises:
means to separate a mixed hydrocarbon feed stream 10 from the initial feed stream 8;
a stream splitter 36 to divide the mixed hydrocarbon feed stream 10 into at least a first part-feed stream 20 and a second part-feed stream 30;
a first gas/liquid separator 14 to receive the first part-feed stream 20, and to provide at least a first overhead gaseous stream 40 and a first bottom liquid stream 50;
a second gas/liquid separator 22 to receive the first bottom liquid stream 50, and to provide at least a second overhead gaseous stream 70 and a second bottom liquid stream 80; and
a heat exchanger 26 to receive the second part-feed stream 30 and the second overhead gaseous stream 70, and to provide a cooled second overhead gaseous stream 70 a and a warmer second part-feed stream 30 b.
The method as illustrated in FIG. 1 at least comprises the steps of:
providing a mixed hydrocarbon feed stream 10 from an initial feed stream 8;
dividing the mixed hydrocarbon feed stream 10 into at least a first part-feed stream 20 and a second part-feed stream 30;
passing the first part-feed stream into a first gas/liquid separator 14 to provide at least a first gaseous overhead stream 40 and a first bottom liquid stream 50;
passing the first bottom liquid stream 50 into a second gas/liquid separator 22 to provide at least a second gaseous overhead stream 70 and a second bottom liquid stream 80; and
cooling the second overhead gaseous stream 70 by heat exchange against the second part-feed stream 30.
The first and second gas/liquid separators may be any form of separator such as a distillation column adapted to provide at least one gaseous stream, usually being enriched in one or more lighter hydrocarbons, and at least one liquid stream, usually being enriched in one or more heavier hydrocarbons. An example of such a separator is a “de-methanizer” designed to provide a methane-enriched overhead stream, and one or more C₂ ⁺ enriched liquid steams at or near the bottom. Similarly, there are “de-ethanizers” and “de-propanizers”, etc., known in the art.
Thus, where the first gas/liquid separator is a de-methanizer, the first bottom liquid stream will be a C₂ ⁺ hydrocarbon stream. Where the second gas/liquid separator is a de-ethanizer, the second bottom liquid stream will be a C₃ ⁺ hydrocarbon stream, and the second overhead gaseous stream is preferably >60 mol % ethane, more preferably >85 and even more preferably >90 mol % ethane.
In more detail, FIG. 1 shows an initial feed stream 8 containing natural gas, which is cooled by a pre-cooling heat exchanger 32 to provide a cooled and partly condensed initial stream 8 a. The pre-cooling heat exchanger 32 may comprise one or more heat exchangers either in parallel, series or both, in a manner known in the art. Cooling is provided by a first refrigerant stream 100, which is warmed in the pre-cooling heat exchanger 32 to create a warmed refrigerant stream 100 a.
This cooling of the initial feed stream 8 may be part of a liquefaction process, such as a pre-cooling stage involving a propane refrigerant circuit as described hereinafter in relation to FIG. 2, or a separate process.
Cooling of the initial feed stream 8 may involve reducing the temperature of the initial feed stream 8 to below −0° C., for example, in the range −10° C. to −40° C.
The cooled initial stream 8 a is passed into an initial gas/liquid separator such as a scrub column 34, operating at an above ambient pressure in the manner known in the art. The scrub column 34 provides a condensed mixed hydrocarbon feed stream 10, and an initial gaseous overhead steam 110. The initial gaseous overhead stream 110 usually comprises greater than 80 mol % methane. It is typically a methane-enriched stream compared to the cooled initial stream 8 a.
The mixed hydrocarbon feed stream 10 comprises methane and one or more C₂ ⁺ hydrocarbons. Typically, the proportion of methane in the mixed hydrocarbon feed stream is 30-50 mol %, with a significant fraction of ethane and propane, such as 5-10 mol % each.
Commonly, it is desired to recover any methane in a mixed hydrocarbon stream (for use as a fuel or so that it can be liquefied in the LNG plant 2 and provided as additional LNG), and to provide one or more of a C₂stream, a C₂ ⁺ stream, a C₃stream, a C₃ ⁺ stream, a C₄ ⁺ stream, etc., or a combination of same. The method of the present invention is applicable to separation of any one or more of the C₂ ⁺ streams, either as pure streams or as combined component streams.
In FIG. 1, the mixed hydrocarbon feed stream 10 is divided by a steam splitter 36 into a first part-feed stream 20 and a second part-feed stream 30. The division of the mixed hydrocarbon feed stream 10 could be based on any ratio of mass and/or volume and/or flow rate. The ratio may be based on the size or capacity of the subsequent parts, systems or units, or the size, capacity or cold energy for the second part-feed stream 30 and duty of the heat exchanger 26 (discussed hereinafter). Generally, the first part-feed stream 20 will be between 20 to 70 mass %, preferably 30 to 50 mass % and more preferably 40 vol %, of the mixed hydrocarbon feed stream 10.
The first part-feed stream 20 passes through a valve 12 to provide a reduced pressure first part-feed stream 20 a, which then enters a first gas/liquid separator such as a first distillation column 14 through a first inlet at or near the top of the first distillation column 14. The reduced pressure first part-feed stream 20 a is typically a mixed phase stream, and the first distillation column 14 is adapted to separate the gaseous and vapour phases, so as to provide a first overhead gaseous stream 40 and a first bottom liquid stream 50.
The nature of the streams provided by the first distillation column 14 can be varied according to the size and type of distillation column, and its operating conditions and parameters, in a manner known in the art. For the arrangement shown in FIG. 1, it is desired for the first overhead gaseous stream 40 to be methane-enriched, preferably to be >90 mol % methane. This methane-enriched stream 40 could be added into other parts of a liquefaction plant to provide for example further LNG, or it could be used as fuel.
The first distillation column 14 also includes a first reboiler 17 and a bottom return stream 60, typically in the form of a reboiler vapour return stream, in a manner known in the art.
The first bottom liquid stream 50 will predominantly be C₂ ⁺ hydrocarbons, such as >90 or >95 mol % of ethane and heavier hydrocarbons. The first bottom liquid stream 50 is cooled by one or more ambient coolers, such as a water and/or air cooler 16, followed by a passage through a valve 18 to provide a reduced pressure first bottom stream 50 a, which enters through inlet 42 into a second gas/liquid separator such as a second distillation column 22. Again, the type, size and capacity of the second distillation column 22, as well as its operating conditions and parameters, will control the nature of the streams provided by the second distillation column 22.
In the arrangement shown in FIG. 1, the second distillation column 22 provides a second overhead gaseous stream 70 being predominantly ethane, preferably >85 or >90 mol % ethane, and a second bottom liquid stream 80, generally being >98% propane and heavier hydrocarbons. The second distillation column 22 also includes a reboiler 27 and a reboiler vapour return stream 90.
The cooling of the second overhead gaseous stream 70 preferably results in condensation of at least part, preferably all, of the second overhead gaseous stream. Particularly a condensed fraction may be used as a reflux stream 70 b for the second gas/liquid separator 22. In one embodiment of the present invention, the method thus further provides the steps of:
(i) dividing a cooled second gaseous overhead stream 70 a provided by step (g) into two or more fractions (70 b, 70 c); and
(j) passing at least one of said fractions (70 b) back into the second gas/liquid separator 22, preferably as a reflux stream.
Where the second gas/liquid separator is a distillation column, for instance a de-ethanizer, the fraction of the second overhead gaseous stream in step (i) can be used to provide reflux to the distillation column.
Conventionally, the second overhead gaseous stream 70 is cooled by a separate or external cooler as shown in U.S. Pat. No. 7,051,553 B2, or by the pre-cooling heat exchanger 32. Using the former requires the involvement of a separate energy source and use, whilst using the latter takes away some of the cooling power of the pre-cooling heat exchanger 32 from cooling of the initial feed stream 8. Both of these situations reduce the efficiency of an LNG plant. Both also create complicated integration between the fractionation arrangement and the remainder of a liquefaction plant.
The second part-feed stream 30 (from the mixed hydrocarbon feed stream 10), after passing through a valve 24 to provide a reduced pressure second part stream 30 a, preferably has a temperature that is low enough, such as between 0° C. and −50° C., to provide cooling in a heat exchanger 26 to the second overhead gaseous stream 70. The heat exchanger 26 may be one or more heat exchangers in parallel, series or both. In embodiments, heat exchanger 26 may be referred to as a reflux heat exchanger.
The cold energy of the reduced pressure second part-feed stream 30 a withdraws warmth from the second overhead gaseous stream 70 to at least partially condense, preferably fully condense, the second overhead gaseous stream 70 in the heat exchanger 26, and provide an at least partly condensed second stream 70 a. Thus, cooling of the second overhead gas stream 70 is achieved without the need for a separate source of cooling, making the arrangement for NGL recovery shown in FIG. 1 independent of any refrigeration system.
The at least partly condensed second stream 70 a can be divided by a stream splitter 44 into a reflux stream 70 b, and a product stream 70 c. The product stream 70 c could be provided as a separate product stream for use outside a liquefaction plant, or as a refrigerant or as a component of a refrigerant in a liquefaction plant, such as in a mixed refrigerant known in the art.
The heat exchange of the second overhead gaseous stream 70 and the second part-feed stream 30 a also provides a warmer second part-feed stream 30 b, which can be passed into the first distillation column 14, preferably between the inlet 38 for the first part-feed stream 20 a and the bottom return stream 60, e.g. via an inlet 39 into the first distillation column 14, located gravitationally lower than inlet 38. The bottom return stream 60 may be fed back into the first distillation column 14 via return stream inlet 41.
The arrangement shown in FIG. 1 is for the separation of C₁and C₂streams 40, 70 from a mixed hydrocarbon feed stream 10, resulting in a remaining C₃ ⁺ stream 80. However, this arrangement is equally applicable to provide, for example, a C₁stream and a mixed C_2/3stream, with the remainder being a C₄ ⁺ stream, or to provide separate C₁, C₂and C₃streams, with a remaining C₄ ⁺ stream. All such configurations and arrangements are known to the person skilled in the art in relation to NGL recovery.
Thus, the method of the present invention is equally applicable to use with two other gas/liquid separators using a mixed hydrocarbon feed stream and adapted to provide different product streams. Equally, the method of the present invention is applicable to an arrangement involving more than two gas/liquid separators, where more than three product streams such as separate C₃, C₄and C₅ ⁺ streams are provided.
Additionally, the second part-feed stream 30 could be divided into two or more fractions for cooling other overhead gaseous streams (such as from a de-propanizer, etc.), thus further reducing or eliminating the requirement for separate coolers or heat exchangers for each overhead stream.
In the embodiment as shown in FIG. 1, the mixed hydrocarbon feed stream 10 is provided from the initial feed stream 8 by separating the initial feed stream 8 into the mixed hydrocarbon feed stream 10 and the initial gaseous overhead stream 110. The latter may in practical situations often be a methane-enriched stream.
The initial gaseous overhead stream 110 may be fed into a gas grid to distribute the methane-enriched stream as gas to market. Before feeding into a grid, the initial gaseous overhead stream 110 may, however, be subjected to other processing steps such as further treating to change the composition and/or cooling, preferably liquefying, to provide a cooled hydrocarbon stream, preferably LNG.
Thus, the present invention further provides a method of cooling an initial feed stream such as a hydrocarbon stream such as natural gas comprising at least the steps of:
(i) passing the initial feed stream through an initial separator to provide an, methane-enriched, initial gaseous overhead stream and a condensed mixed hydrocarbon feed stream;
(ii) cooling, preferably liquefying, the initial gaseous overhead stream to provide a cooled, preferably liquefied, hydrocarbon stream; and
(iii) separating one or more C₂ ⁺ hydrocarbons from the condensed mixed hydrocarbon stream by a method as herein defined.
The initial gaseous overhead stream is preferably cooled without passing it through the first gas/liquid separator. It may be cooled by passing the initial gaseous overhead stream to one or more heat exchangers where it is allowed to exchange heat against one or more refrigerants being cycled in one or more refrigerant cycles.
FIG. 2 shows a LNG plant 2 incorporating the C₂ ⁺ separation arrangement 1 shown in FIG. 1.
FIG. 2 shows an initial feed stream 8 being cooled by three pre-cooling heat exchangers 46 (similar or equivalent to the pre-cooling heat exchanger 32 in FIG. 1) to provide a cooled initial stream 8 a, which is divided by a divider 29 into a first stream 9 which passes directly into a scrub column 34, and a second stream 9 a which passes into a main cryogenic heat exchanger 23 to provide a cooler initial feed stream 9 b, which also passes into the scrub column 34 at a higher level than the first stream 9.
The scrub column 34 provides a condensed mixed hydrocarbon feed stream 10. This mixed stream 10 is divided by a stream splitter 36 into a first part-feed stream 20 and second part-feed stream 30, whose passage is as hereinbefore described with relation to FIG. 1.
In this way, the first part-feed stream 20 passes through a valve to provide a reduced pressure first part-feed stream 20 a, which then enters a first distillation column 14. The distillation column 14 provides a first overhead gaseous stream 40 generally being methane and labelled “C1” in FIG. 2, and a first bottom liquid stream 50 which passes after cooling and expansion into a second distillation column 22.
The second distillation column 22 provides a second overhead gaseous stream 70 which is cooled in the heat exchanger 26 against the reduced pressure second part stream 30 a to provide a cooled second overhead stream in the form of an at least partly, preferably fully, condensed second stream 70 a, which is divided into a reflux stream 70 b and a product stream 70 c, which is predominantly ethane and labelled “C2” in FIG. 2.
The second distillation column 22 also provides a second bottom liquid stream 80 being a C₃ ⁺ stream, which, after expansion, can be passed into a further gas/liquid separator such as a third distillation column 52, optionally also being a de-propanizer. The third distillation column 52 can provide a third overhead stream 140 (which after cooling can provide a “C3” product stream comprising for example >95 mol %, preferably 99 mol %, propane), and a third bottom liquid stream 130 being a C₄ ⁺ stream. The third bottom stream 130 can pass into a fourth gas/liquid separator being a fourth distillation column 54, which provides a fourth gaseous overhead stream 160 (which after cooling can create a “C4” product stream comprising for example >95 mol %, preferably 99 mol %, butanes), and a fourth bottom stream 150 which can be a “C₅ ⁺” stream, (sometimes also termed a “light condensate” stream).
FIG. 2 shows a C₂ ⁺ separation scheme involving a number of separators to provide separate C₁, C₂, C₃, C₄and C₅ ⁺ streams, which can be provided as direct product streams, or otherwise used in ways known to the person skilled in the art.
Meanwhile, the initial gaseous overhead stream 110 from the scrub column 34 can pass into a main cryogenic heat exchanger 23 to provide further cooling. Commonly, the cooling provided by the pre-cooling heat exchangers 46 can be considered as a ‘pre-cooling stage’, and the cooling provided by the main cryogenic heat exchanger 23 can be considered as a ‘main or second cooling stage’.
The main cryogenic heat exchanger 23 is typically able to reduce the temperature of the initial gaseous overhead stream 110 to below −90° C. or −100° C., preferably to liquefy the initial gaseous overhead stream 110. Such cooling can be provided in a number of ways known to the person skilled in the art. One example way is use of a refrigerant circuit 25 in a manner known in the art.
The main cryogenic heat exchanger 23 provides an overhead stream 120, preferably being fully liquid. Where the initial feed stream 8 is natural gas, the overhead gaseous stream 120 will generally be LNG. In particular, the present invention improves the efficiency of the overall LNG plant 2 by reducing the complexity of integration of cooling required of at least one overhead stream with other heat exchangers (such as the pre-cooling heat exchanger 32, 46), or other heat exchanger arrangements.
Table 1 below gives an overview of estimated compositions, phases, pressures and temperatures of some of the streams at various parts of an example process of FIG. 2. In the calculations, it has been assumed that the warmer second part-feed stream 30 b has been fed into the first distillation column 14 at the 9^thtray of 12 trays while the first part-feed stream 20 a has been fed into the first distillation column 14 at the first tray (at the top). The C₁purity of the first gaseous overhead stream 40 is calculated to be about 94% for the given mixed hydrocarbon feed stream 10 with a first reboiler duty of first reboiler 17 of 2.6 MW.
Table 2 below gives results of a similar calculation as the one for Table 1, with the exception that the warmer second part-feed stream 30 b has been fed into the first distillation column 14 at the first tray, the same level as the first part-feed stream 20 a. Compared to Table 1, the C₁purity of the first gaseous overhead stream 40 has decreased to about 90% for an increase of the first reboiler duty of first reboiler 17 to 2.8 MW.
Hence, feeding the warmer second part-feed stream 30 b into the distillation column 14 at a level below the inlet 38 for the first part-feed stream 20 a improves the separation efficiency of the first distillation column 14 while reducing reboiler duty of the first distillation column 14.

TABLE 1

Temp	Pressure	Flowrate	N₂	C₁	C₂	C₃	iC₄	C₄	C₅ ⁺

Stream	Phase	° C.	Bar	kmol/s	mol %

8	V	19.4	66.0	17.11	2.7	92.3	3.5	0.9	0.2	0.2	0.3
8a	V/L	−29.3	65.0	17.11	2.7	92.3	3.5	0.9	0.2	0.2	0.3
9	V/L	−29.3	65.0	6.84	2.7	92.3	3.5	0.9	0.2	0.2	0.3
9b	V/L	−62.0	61.5	10.26	2.7	92.3	3.5	0.9	0.2	0.2	0.3
110	V	−55.1	59.6	16.91	2.7	92.9	3.4	0.8	0.1	0.1	0.0
120	L	−148.2	51.9	16.91	2.7	92.9	3.4	0.8	0.1	0.1	0.0
10	L	−33.3	59.7	0.19	0.4	44.1	9.8	8.6	4.3	8.8	24.1
20a	V/L	−42.4	35.0	0.10	0.4	44.1	9.8	8.6	4.3	8.8	24.1
30a	V/L	−41.3	37.5	0.10	0.4	44.1	9.8	8.6	4.3	8.8	24.1
30b	V/L	2.5	37.0	0.10	0.4	44.1	9.8	8.6	4.3	8.8	24.1
40	V	−42.0	35.0	0.09	0.8	94.4	3.8	0.7	0.1	0.2	0.0
50	L	129.3	35.1	0.10	0.0	1.0	14.9	15.3	7.8	16.2	44.8
50^a	L	43.2	27.5	0.10	0.0	1.0	14.9	15.3	7.8	16.2	44.8
80	L	156.0	27.7	0.09	0.0	0.0	0.0	17.4	9.4	19.4	53.7
70c	L	−2.6	36.0	0.02	0.0	6.0	89.0	5.0	0.0	0.0	0.0

V = vapour,
L = liquid

TABLE 2

Temp	Pressure	Flowrate	N₂	C₁	C₂	C₃	iC₄	C₄	C₅ ⁺

Stream	Phase	° C.	Bar	kmol/s	mol %

8	V	19.4	66.0	17.11	2.7	92.3	3.5	0.9	0.2	0.2	0.3
8^a	V/L	−29.3	65.0	17.11	2.7	92.3	3.5	0.9	0.2	0.2	0.3
9	V/L	−29.3	65.0	6.84	2.7	92.3	3.5	0.9	0.2	0.2	0.3
9b	V/L	−62.0	61.5	10.26	2.7	92.3	3.5	0.9	0.2	0.2	0.3
110	V	−55.1	59.6	16.91	2.7	92.9	3.4	0.8	0.1	0.1	0.0
120	L	−148.2	51.9	16.91	2.7	92.9	3.4	0.8	0.1	0.1	0.0
10	L	−33.3	59.7	0.19	0.4	44.1	9.8	8.6	4.3	8.8	24.1
20^a	V/L	−42.4	35.0	0.10	0.4	44.1	9.8	8.6	4.3	8.8	24.1
30^a	V/L	−41.3	37.5	0.10	0.4	44.1	9.8	8.6	4.3	8.8	24.1
30b	V/L	2.5	37.0	0.10	0.4	44.1	9.8	8.6	4.3	8.8	24.1
40	V	−16.4	35.0	0.09	0.7	89.9	6.4	1.8	0.4	0.5	0.2
50	L	135.8	35.1	0.10	0.0	1.0	12.9	14.9	7.9	16.6	46.6
50^a	L	43.2	27.5	0.10	0.0	1.0	12.9	14.9	7.9	16.6	46.6
80	L	157.8	27.7	0.09	0.0	0.0	0.0	16.7	9.2	19.4	55.6
70c	L	−4.3	36.0	0.01	0.0	6.8	88.2	5.0	0.0	0.0	0.0

V = vapour,
L = liquid

Suitable process control of embodiments of the present invention may include a level controller on the initial gas/liquid separator 34, which manipulates the flow of the first part-feed stream 20 into the first gas/liquid separator 14, for instance via manipulating the setting of valve 12. Valve 24 may be manipulated using a flow controller, of which the set point is determined by a pressure controller for the second gas/liquid separator. Equivalently, its set point may be determined by a level controller on an optional vessel 21 arranged to receive and discharge the cooled second overhead stream. This is equivalent to pressure control, since the level in the vessel is determined by the duty of the condenser condensation yielding stream 70 a.
The demonstrated embodiments of the present invention advantageously avoid complicated integration of a NGL removal process with the refrigeration systems of any associated LNG plant or facility.
The person skilled in the art will understand that the present invention can be carried out in many various ways without departing from the scope of the appended claims. For instance, instead of natural gas, the initial feed stream may be formed of other types of gas, including refinery or petroleum plant gas.

Claims

1. A method of producing a liquefied hydrocarbon stream, and recovering a mixed hydrocarbon feed stream, from an initial feed stream and fractionating the mixed hydrocarbon feed stream into one or more fractionated streams, the method comprising the step of:

(a) providing an initial feed stream;

(b) partly condensing the initial feed stream, thereby forming a partly condensed initial feed stream;

(c) separating the partly condensed initial feed stream into an initial gaseous overhead stream and a condensed mixed hydrocarbon feed stream;

(ii) liquefying at least part of the initial gaseous overhead stream to provide a liquefied hydrocarbon stream;

(d) dividing the condensed mixed hydrocarbon feed stream into at least a first part-feed stream and a second part-feed stream;

(e) passing the first part-feed stream into a first gas/liquid separator, via a first inlet into the first gas/liquid separator, to provide at least a first fractionated stream in the form of a first gaseous overhead stream and a first bottom liquid stream;

(f) passing the first bottom liquid stream into a second gas/liquid separator to provide at least a second fractionated stream in the form of a second gaseous overhead stream and a second bottom liquid stream; and

(g) cooling the second overhead gaseous stream by heat exchange against the second part-feed stream, resulting in a warmer second part-feed stream, without integration with a refrigeration circuit associated with a liquefaction process, and wherein the second part-feed stream is reduced in pressure prior to its heat exchanging against the second overhead gaseous stream;

(h) passing the warmer second part-feed stream into the first gas/liquid separator at a level gravitationally below the first inlet.

2. The method as claimed in claim 1, wherein at least part of the initial gaseous overhead stream is liquefied without passing the at least part of the initial gaseous overhead stream through the first gas/liquid separator.

3. The method as claimed in claim 1, wherein the initial gaseous overhead stream is a methane-enriched stream.

4. The method as claimed in claim 1, further comprising the steps of:

(i) dividing the cooled second gaseous overhead stream provided by the cooling of the second gaseous overhead stream in step (g) into two or more fractions; and

(j) passing at least one of said fractions back into the second gas/liquid separator.

5. (canceled)

6. The method as claimed in claim 1, wherein the first gas/liquid separator and the second gas/liquid separator are distillation columns.

7. The method as claimed in claim 1, wherein said passing of the warmer second part-feed stream into the first gas/liquid separator at the level gravitationally below the first inlet comprises passing the warmer second part-feed stream into the first gas/liquid separator at a height along the separator between the first inlet and the bottom of the separator.

8. The method as claimed in claim 1, further comprising a step of drawing a reboiler stream from the first gas/liquid separator, heating the reboiler stream to produce a bottom return stream, and feeding the bottom return stream back to the first gas/liquid separator, wherein said passing of the warmer second part-feed stream into the first gas/liquid separator at the level gravitationally below the first inlet comprises passing the warmer second part-feed stream into the first gas/liquid separator between the first inlet and the bottom return stream.

9. The method as claimed in claim 1, wherein the second overhead gaseous stream comprises >60 mol % ethane.

10. The method as claimed in claim 1, wherein the first bottom liquid stream is a C2+ hydrocarbon stream.

11. The method as claimed in claim 1, wherein the second bottom liquid stream is a C3+ hydrocarbon stream.

12. An apparatus for recovering a mixed hydrocarbon feed stream from an initial feed stream and fractionating the mixed hydrocarbon feed stream into one or more fractionated streams, the apparatus comprising:

a pre-cooling heat exchanger arranged to cool the initial feed stream to provide a partly condensed initial feed stream;

an initial gas/liquid separator arranged to separate the partly condensed initial feed stream into an initial gaseous overhead stream and a condensed mixed hydrocarbon stream;

a stream splitter to divide the condensed mixed hydrocarbon feed stream into at least a first part-feed stream and a second part-feed stream;

a first gas/liquid separator arranged to receive the first part-feed stream via a first inlet into the first gas/liquid separator, and to provide at least a first fractionated stream in the form of a first overhead gaseous stream and a first bottom liquid stream;

a second gas/liquid separator arranged to receive the first bottom liquid stream, and to provide at least a second fractionated stream in the form of a second overhead gaseous stream and a second bottom liquid stream;

a heat exchanger arranged to receive the second part-feed stream and the second overhead gaseous stream, and to provide a cooled second overhead gaseous stream and a warmer second part-feed stream; and

a second inlet into the first gas/liquid separator arranged to allow entry of the warmer second part-feed stream into the first gas/liquid separator, the second inlet being at a level gravitationally below the first inlet.

13. The apparatus as claimed in claim 12, further comprising a main cryogenic heat exchanger arranged to receive the initial gaseous overhead stream via a path that does not pass through the first gas/liquid separator, and to provide further cooling to the initial gaseous overhead stream.

14. The apparatus as claimed in claim 12, further comprising a pressure reduction valve between the stream splitter and the heat exchanger.

15. The apparatus as claimed in claim 12, wherein the cooled second overhead gaseous stream is provided from the second overhead gaseous stream without integration with a refrigeration circuit associated with a liquefaction process.

16. The apparatus as claimed in claim 12, wherein no separate refrigeration involving separate power consumption is employed for providing said cooled second overhead gaseous stream from the second overhead gaseous stream.

17. The method as claimed in claim 1, wherein no separate refrigeration involving separate power consumption is employed for said cooling of the second overhead gaseous stream in step (g).

18. The method as claimed in claim 1, wherein the initial feed stream is a natural gas stream.

19. The method as claimed in claim 4, wherein said cooling of the second overhead gaseous stream in step (g) results in condensation of at least part of the second overhead gaseous stream, and wherein the at least one of said fractions in step (j) is a condensed fraction being passed back into the second gas/liquid separator as a reflux stream.

20. A method of recovering a mixed hydrocarbon feed stream from an initial feed stream and fractionating the mixed hydrocarbon feed stream into one or more fractionated streams, the method comprising the step of:

(a) providing an initial feed stream;

(g) cooling the second overhead gaseous stream by heat exchange against the second part-feed stream, resulting in a warmer second part-feed stream;

21. The method as claimed in claim 20, further comprising cooling at least part of the initial gaseous overhead stream, without passing the at least part of the initial gaseous overhead stream through the first gas/liquid separator, thereby providing provide a cooled hydrocarbon stream.

22. The method as claimed in claim 20, further comprising liquefying at least part of the initial gaseous overhead stream, without passing the at least part of the initial gaseous overhead stream through the first gas/liquid separator, thereby providing provide a liquefied hydrocarbon stream.

23. The method as claimed in claim 20, wherein the initial feed stream is a natural gas stream.

24. The method as claimed in claim 20, wherein the initial gaseous overhead stream is a methane-enriched stream.

25. The method as claimed in claim 20, further comprising the steps of:

26. The method as claimed in claim 25, wherein said cooling of the second overhead gaseous stream in step (g) results in condensation of at least part of the second overhead gaseous stream, and wherein the at least one of said fractions in step (j) is a condensed fraction being passed back into the second gas/liquid separator as a reflux stream.

27. The method as claimed in claim 20, wherein the second part-feed stream is reduced in pressure prior to its heat exchanging against the second overhead gaseous stream in step (g).

28. The method as claimed in claim 20, wherein the first gas/liquid separator and the second gas/liquid separator are distillation columns.

29. The method as claimed in claim 20, wherein said passing of the warmer second part-feed stream into the first gas/liquid separator at the level gravitationally below the first inlet comprises passing the warmer second part-feed stream into the first gas/liquid separator at a height along the separator between the first inlet and the bottom of the separator.

30. The method as claimed in claim 20, further comprising a step of drawing a reboiler stream from the first gas/liquid separator, heating the reboiler stream to produce a bottom return stream, and feeding the bottom return stream back to the first gas/liquid separator, wherein said passing of the warmer second part-feed stream into the first gas/liquid separator at the level gravitationally below the first inlet comprises passing the warmer second part-feed stream into the first gas/liquid separator between the first inlet and the bottom return stream.

31. The method as claimed in claim 20, wherein the second overhead gaseous stream comprises >60 mol % ethane.

32. The method as claimed in claim 20, wherein the first bottom liquid stream is a C2+ hydrocarbon stream.

33. The method as claimed in claim 20, wherein the second bottom liquid stream is a C3+ hydrocarbon stream.

34. The method as claimed in claim 20, wherein the second overhead gaseous stream is cooled in step (g) without integration with a refrigeration circuit associated with a liquefaction process.

35. The method as claimed in claim 20, wherein no separate refrigeration involving separate power consumption is employed for said cooling of the second overhead gaseous stream in step (g).

36. A method of producing a liquefied hydrocarbon stream, and recovering a mixed hydrocarbon feed stream, from an initial feed stream, and fractionating the mixed hydrocarbon feed stream into one or more fractionated streams, the method at least comprising the step of:

(a) providing an initial feed stream;

(g) cooling the second overhead gaseous stream by heat exchange against the second part-feed stream, resulting in a warmer second part-feed stream.

37. The method as claimed in claim 36, wherein at least part of the initial gaseous overhead stream is liquefied without passing the at least part of the initial gaseous overhead stream through the first gas/liquid separator.

38. The method as claimed in claim 36, wherein the second part-feed stream is reduced in pressure prior to its heat exchanging against the second overhead gaseous stream in step (g).

39. The method as claimed in claim 36, wherein the second overhead gaseous stream is cooled in step (g) without integration with a refrigeration circuit associated with a liquefaction process.

40. The method as claimed in claim 36, wherein no separate refrigeration involving separate power consumption is employed for said cooling of the second overhead gaseous stream in step (g).