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Publication numberUS3452548 A
Publication typeGrant
Publication dateJul 1, 1969
Filing dateMar 26, 1968
Priority dateMar 26, 1968
Publication numberUS 3452548 A, US 3452548A, US-A-3452548, US3452548 A, US3452548A
InventorsTullio L Pitaro
Original AssigneeExxon Research Engineering Co
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Regasification of a liquefied gaseous mixture
US 3452548 A
Abstract  available in
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Claims  available in
Description  (OCR text may contain errors)

July '1, 1969 T. PITARO 3,452,548

' REGASIIFICATION 0F A-LYIQUEFIYED GASEOUS MIXTURE Filed March 26. 1968 T. L. PITARO Inventor Patent Attorney Patented July 1, 1969 3,452,548 REGASIFICATION OF A LIQUEFIED GASEOUS MIXTURE Tullio L. Pitaro, Jersey City, N.J., assignor to Esso Research and Engineering Company, a corporation of Delaware Filed Mar. 26, 1968, Ser. No. 716,200 Int. Cl. F17c 7/02 US. CI. 6253 11 Claims ABSTRACT OF THE DISCLOSURE This invention provides a method for the regasification and pressurization of condensed low temperature gaseous mixtures by a heat integration scheme which maximizes the use of the cold in the liquid to be regasified and pressurized. This heat integration scheme, as opposed to the use of separate heat transfer media, results in substantial economic advantages in that more economical heat exchange equipment can be used, no separate handling facilities are needed for an intermediate heat transfer media and losses normally accompanying the use of intermediate heat transfer media are eliminated. The heat integration scheme makes possible the elimination of compressors and minimizes the pumping equipment used to increase the pressure of the regasified mixture.

Background of the invention The instant invention relates generally to a method of heating low temperature fluids. More particularly, the process of the instant invention provides a method for heating low temperature fluids by employing a heat integration scheme which maximizes the use of the cold in the fluid being heated and which results in the minimization of investment and operating costs. The teachings of the instant invention are particularly applicable to the regasification of liquefied natural gas (hereinafter referred to as LNG).

Natural gas is often available in areas remote to where it will be ultimately used. Quite often the source of this fuel is separated from the point of utilization by a large body of water, in which case it may prove necessary to effect bulk transfer of the natural gas by large marine tankers designed for such transport. Under these circumstances, economics dictate that the natural gas be liquefied so as to greatly reduce its volume and that it be transported at essentially atmospheric pressure. Under these conditions the LNG is at a temperature of approximately 258 F. This temperature represents the boiling point of methane at atmospheric pressure. It is to 'be noted, however, that the LNG often contains amounts of heavier hydrocarbons, such as ethane, propane, butane and the like. These will vary the boiling range of the LNG so that it usually will fall somewhere between 240 F. and 258 F. However, nitrogen, which may also be present, can cause the low end of the temperature range to approach temperatures as low as 270 F.

When the LNG arrives at the point of utilization, it is, of course, in liquefied form, and it becomes necessary to regasify it before it is used as a fuel. In addition, it may prove necessary to adjust the heating value of the natural gas to conform to local requirements prior to its entrance into the actual fuel distribution system. Where this is required, adjustment may be conveniently achieved by use of a reforming operation of the type to be more fully discussed hereinafter. It may also become necessary to increase the pressure of the regasified product from atmospheric pressure to the distribution pipeline pressure, which in some cases may be as high as 1000 p.s.i.a.

It will be appreciated that the reconversion of the LNG to a gaseous form requires the addition of a substantial amount of heating. When heating cryogenic streams such as LNG, many problems both of an economic and technical nature are often encountered. For example, when heating such streams, direct heat exchange is only feasible with heating streams which are dry, since any moisture present would freeze out and deposit and would eventually block or plug the heat exchangers employed. Coupling this with the fact that the least expensive heat sources are wet (e.g., water, steam, air and flue gas), it is not surprising that problems in this area are often encountered. In the past problems of this nature have been solved by using a separate intermediate heat exchange fluid contained in a closed. cycle or the like. The function of this type of intermediate fluid system is to absorb heat from a hot wet heat source and inject it to the cold LNG stream. However, there are numerous economic disadvantages which accompany the use of such a system. For example, heat exchanger area requirements are in effect doubled since the number of needed exchangers are usually as high. Furthermore, separate facilities are required to store, handle and possibly produce the separate intermediate exchange fluid.

In contrast, the teachings of the instant invention provide a method for heating cryogenic fluids such as LNG, which avoids the above mentioned difficulties. Thus, utilization of the method to be herein described in further detail results in substantial reductions in heat exchange costs and eliminates need for separate handling facilities. Also the need to make up losses in the amount of intermediate heat exchange media is avoided.

Summary of the invention According to the instant invention, the above highly desirable results may be achieved by using recycled process streams in lace of an intermediate heat exchange fluid. In a preferred embodiment of the invention, the LNG regasification is accomplished in combination with a reforming operation of a type known in the art and to be hereinafter discussed. In a preferred embodiment of the instant invention a cold liquid LNG stream is warmed by being passed through a series of heat exchangers, which exchangers serve to condense overhead vapors from a flashing drum and a distillation column (the column serving to effect the separation of C constituents from the lighter constituents of the natural gas). Upon its passage through this series of heat exchangers, the entering LNG is then heat exchanged with a portion of the bottoms from a second flashing drum and then enters the first flashing drum as feed. A portion of the bottoms from the second drum is passed in heat exchange with one or more hot streams available from the reforming operation. The overhead from the second flashing drum and the remaining portion of the bottoms product from said drum are combined and passed to the fractionating column. The bottoms of this column, comprising C and heavier hydrocarbons, are fed to the reforming operation, as will be further discussed hereinafter. The top products from the tower are passed in heat exchange with the LNG as hereinbefore indicated and the condensed liquids are recycled into the upper region of the column. The uncondensed vapors are also passed in a second heat exchange with the LNG (which serves to warm the latter) and are then pumped up to suitable pipeline pressures. Following this increase in pressure, these materials are passed in heat exchange with the overhead vapors from the first drum and then are fed into a suitable gas dis tribution system.

Accordingly, an important object of the invention is to provide an efficient method for heating a cold fluid without the need for separate intermediate heat exchange media.

Another important object of this invention is to facilitate the regasification of LNG so that it is in suitable condition for delivery and use as a fuel.

Still another object is to provide a system which allows the use of more economical heat exchange equipment and no separate intermediate heat transfer fluid facilities, thereby elfecting substantial economies in equipment cost.

Yet another object is to provide a system which allows the use of lower pressure heat exchange equipment in the initial LNG heating, and which requires fewer pumps needed to effect the desired pipeline pressure.

Another object is to minimize operating costs in bringing the LNG from atmospheric pressure to the relatively high pipeline pressure.

Other objects and a fuller understanding of the invention may be had by referring to the following description and claims taken in conjunction with the accompanying drawing.

Brief description of the drawing TABLE I Constituent: Mole percent C 60-70 15-25 c 8-15 C 2-4 0 0 1 C -I- 0-1 The LNG from tank 2 is fed through the line 3 into pump 4 wherein its pressure is increased to from about 14.7 to about 500 and preferably about 450 p.s.i.a. The pump 4 causes the pressurized LNG stream to flow via the lines 6, 12, 14 and 18 through a series of heat exchangers 8, 10, 16 and 20, to be further discussed hereinafter. Upon exiting from exchanger 20 via the line 22, the LNG stream has been heated to a temperature in the range of 30 F. to -70 F. and preferably around -58 F. The heated LNG stream is then fed into a first flashing drum 24. Drum 24 may be operated in the range of 300 to 500 p.s.i.a. with a preferable range of from about 350 to about 400 p.s.i.a. The flashed vapors from drum 24 will be mostly methane and will have a composition range such as shown in Table II. This composition will, of course, depend on the composition of the initial feedstock and the exact temperature and pressure of the drum 24.

From drum 24 these vapors are fed via conduit 26 through heat exchanger 10. A portion of the vapors from drum 24 branch off into conduit 30 and are fed through heat exchanger 32. Vapors in exchanger serve to warm the entering LNG in line 12. The splitting of the overhead from flashing drum 24 into conduits 26 and 30 insures that the temperature approaches in heat exchangers 10 and 32 do not fall below allowable limits. Upon exit from exchangers 10 and 32, the overhead is merged in line 34 and has a temperature in the range of from about 140 .4 F. to about F. (depending on the composition of the overhead from drum 24 and the feed composition to the plant) and preferably at about -160 F. The material in line 34 is then combined with the fractionator overhead which has been condensed and pumped from about 320 p.s.i.a. to 380 p.s.i.a. After combining the effiuent streams from exchangers 8, 10 and 32, resulting in a combined stream pressure in the range of 350 to 450 p.s.i.a. and more preferably about 380 p.s.i.a. and in a temperature in the range of -140 F. to F. (about 10 F. below the stream bubble point) depending on the stream composition, the material in line 38 is pumped up to a pressure in a range of 900 to 1100 p.s.i.a. and preferably about 1000 p.sli.a. by pump 40. This high pressure stream is then used to make possible the condensation of the overhead vapors from drum 24 in exchanger 32. Upon exit from exchanger 32, they are conducted via the line 44 through heat exchanger 46, which exchanger serves to vaporize and superheat the methane rich product gas so that when combined with the reformed gas in line 49 gives a suitable pipeline temperature in the range of 32 F. to 104 F. and preferably 50 F. Upon exiting from exchanger 46 via the line 47 the material is at about 1000 p.s.i.a. and at about 5 F. according to the preferred embodiment. This material has a composition as indicated in Table III.

The material in line 47, which when combined with the reformed product in line 49, is at suitable pipeline distribution conditions and is fed from the line 51 to a suitable distribution network (not shown).

Returning once again to drum 24, the bottom products leaving drum 24 via the line 48 and having a temperature of approximately 5 8 F., are combined with part of the bottoms from drum 52. The combined stream serves as a heat transfer media in a pump-around circuit. The combined stream in line 50, having a temperature of approximately 50 F., is fed to drum 52. The feed to drum 52 has a composition in the ranges indicated in Table IV below.

Drum 52 is operated at a pressure of from about 300 to about 450 p.s.i.a. and preferably about 380 p.s.i.a. A portion of the bottoms leaving drum 52 (called the pumparound) is conducted via the line 88 through exchanger 90, wherein it is heated by passing it in heat exchange with a hot reformate stream entering exchanger 90 via the line 82 and exiting exchanger 90 via the line 84. Upon exit from exchanger 90, said portion of the bottoms from drum 52 is conducted via line 91 through exchanger 46, where the methane rich gas is vaporized. Upon leaving exchanger 46, the pump-around is conducted via line 92 through exchanger 20, where it serves to further heat the incoming LNG feed. Upon exit from exchanger 20, this bottom fraction is combined with the bottoms from drum 24 and introduced via the line 50 back into drum 52.

The remaining portion of the bottoms from drum 52 are combined with the products leaving the top of drum 52 via the line 54, and this recombined stream is then fed via the line 58 into a fractionating column 60. Tower 60 effects the separation of C and C constituents. The C material leaves the bottom of the tower via the line 74 and enters reboiler 76. A portion of the material entering reboiler 76 isreintroduced into the bottom of the tower via the line 78. The remaining portion of the bottoms from column 60 leaves reboiler 76 via the line 79 and is then fed to a reforming complex indicated as 80. The material entering reforming complex 80 has a composition as indicated in Table V below.

TABLE V Constituent: Mole percent C C 0 C 60-70 C; 20-30 Others 5-15 In the reforming operation this composition is converted so that the reformate will have a composition as indicated in Table VI.

TABLE VI Constituent: Mole percent CO 3-7 CO 1-2 H 20-30 CH 60-70 A great deal of water, comprising about 50 percent of the molar flow, will also be present. This water is removed (in suitable apparatus not shown) after the reformate gas is heat exchanged with the portion of the bottoms from drum 52 as hereinbefore discussed. After this heat exchange, the reformate gas is ultimately fed via the line 86 to a compressor 87 where its pressure is raised to approximately 1000 p.s.i.a. The material leaving compressor 87 is then fed via the line 49 into the product gas line 51.

1. A process for regasifying a feed of liquefied gas comprising the following steps in combination:

(a) pressurizing and heating said liquefied gas feed;

(b) flashing said feed into a first flashing drum;

(c) passing the bottoms from said first drum to a second flashing drum;

(d) drawing off a portion of the stream from the bottom of said second drum;

(e) heating said portion by use of an external process stream;

(f) passing the heated portion resulting from step (e) in heat exchange with the incoming liquefied gas feed to said first drum; and then (g) combining said portion with said bottoms from said first drum and passing the resulting combined stream into said second drum.

2. The process of claim 1 wherein the heating in step (a) is partially accomplished by utilizing heat from the materials leaving the top of said first flashing drum.

3. The process of claim 1 wherein said first drum is operated at a pressure in the range of from about 300 to about 500 p.s.i.a. and said second drum is operated in a range of from about 300 to about 450 p.s.i.a.

4. The process of claim 1 wherein said liquefied gas is liquefied natural gas and said external process stream is a hot reformate gas stream obtained by reforming the heavy ends of said natural gas.

5. In a process of the type wherein a liquefied natural gas feed is regasified, fractionated and subjected in part to a reforming operation, the improvement which comprises the following steps in combination:

(a) pressurizing said liquefied natural gas feed;

(b) heating the pressurized feed resulting from step (a) by passing it in heat exchange relationship with in- Example.-Starting with a typical LNG feedstock comternal process Streams; Posed of (c) flashing the resulting pressurized and heated feed TABLE VII in a first flashing drum; Constltuent: Mole Percent (d) passing the bottom products from said first drum 1 68 to a second drum; 2 19 (e) drawing off a portion of the stream from the bots 10 tom of said second drum; C 2 (f) heating said portion by passing it in heat exchange C 1 relationship with a hot process stream from said reand operating in the aforesaid preferred temperature and formlqg operatlon; pressure ranges, the following table indicates the ap- Passmg the heated P9 1 Te$1 11t1ng f10m p proximate temperatures, pressures and stream composi- 1n heat exchange relfilltlonshlp Wlth 531d natural tions present at various locations in the depicted process. feed to f hfiat sald' ffied; and These locations are designated by referring to their ascomblnlng Sald P 9 Wlth the Pottom Product signed reference numerals appearing in the figure. from said first drum being fed to said second drum.

TABLE VIII Typical stream composition (mole percent) Temperature Pressure Location F (p.s.i.a.) C5 02 Ca C4 C5 C0 C02 N2 CO Hz Line s -250 450 as 19 Line 14 -s5 425 as 19 Line 22.. -58 400 68 19 Line 26 -58 400 85 13 Line 4s, -58 400 25 35 Line 5s. 380 25 35 Line 62 -15 355 36 Line 79. 160 360 Line 51 50 1, 000 74. 2 11. 8

It is to be understood that the foregoing arrangement can be modified in various details and need not necessarily be restricted to the processing of natural gas, per se. The flow diagram and description are given by Way of example for the purposes of illustrating more clearly how the invention may be performed. Moreover, the operating percentages, temperatures and pressures specified hereinabove can be varied considerably for given mixtures. Accordingly, reference should be had to the following appended claims in determining the full scope of the invention.

What is claimed is:

and said second drum is operated in a pressure in the range of about 380 p.s.i.a.

9. An improved process for heating and regasifying a liquefied hydrocarbon gaseous feed which comprises, pressurizing said feed, flashing said pressurized feed in a first flashing drum, utilizing the overhead from said drum to heat the incoming feed, passing the bottoms from said drum to a second drum, passing a portion of the bottoms product from said second drum in heat exchange with an external process stream whereby said portion is heated and utilizing said heated portion to further heat said incoming feed.

10. The process of claim 9 wherein vapors from the top of said second drum and the remaining part of the bottoms from said second drum are combined and fractionated in a C and heavier cut and a C and lighter cut, with the C and lighter cut being passed in heat exchange with said pressurized feed.

References Cited UNITED STATES PATENTS 5/1966 Reed 62-45 7/ 1967 Proctor et a1 62--52 LLOYD L. KING, Primary Examiner.

U.S. Cl. X.R. 62-52

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
US3251191 *Oct 16, 1964May 17, 1966Phillips Petroleum CoFrozen earth storage for liquefied gas
US3331214 *Mar 22, 1965Jul 18, 1967Conch Int Methane LtdMethod for liquefying and storing natural gas and controlling the b.t.u. content
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US4331129 *Jul 5, 1979May 25, 1982Columbia Gas System Service CorporationSolar energy for LNG vaporization
US4438729 *Mar 31, 1980Mar 27, 1984Halliburton CompanyMethod of heating a first fluid
US5551242 *Mar 14, 1984Sep 3, 1996Halliburton CompanyFlameless nitrogen skid unit
US6089028 *Mar 26, 1999Jul 18, 2000Exxonmobil Upstream Research CompanyProducing power from pressurized liquefied natural gas
US7678951Nov 17, 2006Mar 16, 2010Total S.A.extraction of at least one part of the ethane from the natural gas, reforming of at least one part of the extracted ethane into a synthesis gas, methanation of the synthesis gas into a methane-rich gas, and mixing of the methane-rich gas with the natural gas
US8156758Aug 17, 2005Apr 17, 2012Exxonmobil Upstream Research CompanyMethod of extracting ethane from liquefied natural gas
U.S. Classification62/50.2
International ClassificationF17C7/04, F17C9/02, F25J3/02, F17C9/04
Cooperative ClassificationF25J2205/82, F17C7/04, F25J2200/02, F17C2265/05, F25J3/0242, F25J2235/60, F25J3/0233, F25J2245/02, Y02E60/321, F25J3/0214, F17C9/04
European ClassificationF25J3/02A2L, F25J3/02C2, F17C9/04, F25J3/02C6, F17C7/04