EP1946026A2

EP1946026A2 - Method for treating a liquefied natural gas stream obtained by cooling using a first refrigerating cycle and related installation

Info

Publication number: EP1946026A2
Application number: EP06820179A
Authority: EP
Inventors: Henri Paradowski
Original assignee: Technip France SAS
Current assignee: Technip Energies France SAS
Priority date: 2005-10-10
Filing date: 2006-10-10
Publication date: 2008-07-23
Anticipated expiration: 2026-10-10
Also published as: JP4854743B2; EA011605B1; WO2007042662A3; CA2625577A1; EP1946026B1; US20070095099A1; EA200801047A1; MY152657A; CN101313188A; FR2891900B1; JP2009512831A; KR101291220B1; CA2625577C; US7628035B2; CN101313188B; KR20080063470A; ES2665743T3; NZ567356A; FR2891900A1; WO2007042662A2

Abstract

The invention concerns a method which consists in cooling the LNG stream (11) with a coolant (83) in a first heat exchanger (19). The coolant (83) is subjected to a second semi-open refrigerating cycle (21), independent of the first cycle (15). The method includes a step of introducing the under-cooled LNG stream (59) in a distillation column (49) and a step of recovering a gas stream (69) at the head of the column (49). The second refrigerating cycle (21) includes a step of forming a coolant stream (73) from part of the head gas stream (69), a step of compressing the coolant stream (73) up to a high pressure, then a step of expanding part (81) of the compressed coolant stream (75) to form an essentially liquid under-cooling stream (83). The essentially liquid stream (83) is evaporated in the first heat exchanger (19).

Description

Process for treating an LNG stream obtained by cooling by means of a first refrigeration cycle and associated plant

The present invention relates to a method of treating an LNG stream obtained by cooling by means of a first refrigeration cycle, the process being of the type comprising the following steps:

(a) introducing the LNG stream brought to a temperature below -100 ^° C. in a first heat exchanger;

(b) the LNG stream is subcooled in the first heat exchanger by heat exchange with a coolant to form a subcooled LNG stream; and

(c) the cooling fluid is subjected to a second semi-open refrigeration cycle, independent of the first cycle.

From US Pat. No. 6,308,531, a process of the aforementioned type is known, in which a stream of natural gas is liquefied using a first refrigeration cycle which involves the condensation and vaporization of a mixture of gases. hydrocarbons. The temperature of the gas obtained is approximately -100 ^° C. Subsequently, the LNG product is subcooled to about -170 ^° C. using a second refrigeration cycle of the "inverted Brayton cycle" type. Semi-open comprising a stage compressor and a gas expansion turbine.

Such a method is not entirely satisfactory. Indeed, the maximum yield of the inverted Brayton cycle is limited to about 40%. Moreover, its operation in semi-open cycle is difficult to implement.

An object of the invention is therefore to provide an autonomous process for treating an LNG stream, which has improved efficiency and which can easily be implemented in units of various structures.

For this purpose, the subject of the invention is a treatment method of the aforementioned type, characterized in that the method comprises the following steps:

(d) dynamically expanding the subcooled LNG stream into an intermediate turbine while maintaining this stream substantially in the liquid state;

(e) cooling and expanding the stream from the intermediate turbine and then introducing it into a distillation column; (f) recovering a denitrogenated LNG stream at the bottom of the column, and a gas stream at the top of the column; and

(g) compressing the overhead gas stream in a stage compressor, and extracting, at an intermediate pressure stage of the compressor, a first portion of the compressed overhead gas stream at an intermediate pressure P1 to form a stream of combustible gas; and in that the second refrigeration cycle comprises the following steps:

(i) forming a starting coolant stream from a second portion of the compressed overhead gas stream at the intermediate pressure P1;

(ii) compressing the starting coolant stream to a high pressure PH greater than the intermediate pressure P1 to form a compressed refrigerant stream; (iii) cooling the stream of compressed refrigerant in a second heat exchanger;

(iv) separating the compressed refrigerant fluid stream from the second heat exchanger into a majority cooling stream and an LNG subcooling stream; (v) cooling the subcooling stream in a third heat exchanger and then in the first heat exchanger;

(vi) the subcooling stream from the first heat exchanger is expanded to a lower pressure lower than the intermediate pressure P1 to form a substantially liquid subcooling stream of the LNG;

(vii) vaporizing the substantially liquid subcooling stream into the first heat exchanger to form a warmed subcooling stream;

(viii) the main cooling stream is expanded substantially to the low pressure PB in a main turbine, and the main cooling stream from the main turbine is mixed with the subcooling stream heated to form a mixing stream;

(ix) heating the mixing stream successively in the third heat exchanger, then in the second heat exchanger to form a heated mixture stream; and

(x) introducing the heated mixture stream into the compressor at a low pressure stage upstream of the intermediate pressure stage.

The method according to the invention may comprise one or more of the following characteristics, taken separately or in any technically possible combination:

the high pressure PH is between approximately 40 and 100 bar, preferably between approximately 50 and 80 bar and in particular between approximately 60 and 75 bar; the low pressure PB is less than approximately 20 bar;

during step (vi), the subcooling current resulting from the first heat exchanger is dynamically expanded in a liquid expansion turbine;

during step (ii), at least partially the flow of refrigerating fluid flow is compressed in an auxiliary compressor coupled to the main turbine;

during step (i), a stream of C ₂ hydrocarbons is introduced into the compressor to form part of the starting coolant stream;

during step (iii), the stream of compressed refrigerant fluid is placed in heat exchange relation with a secondary refrigerant circulating in the second heat exchanger, the secondary refrigerant undergoing a third refrigeration cycle in which it is compressed at the outlet of the second heat exchanger, cooled, and condensed at least partially, and then expanded before vaporizing in the second heat exchanger;

the secondary refrigerant fluid comprises propane and optionally ethane; and before the expansion of step (e), the stream coming from the intermediate turbine is mixed with a natural gas make-up stream cooled by heat exchange with the overhead gas stream in a fourth heat exchanger; and the C 1 content of the overhead gas is such that the stream cooled by the second heat exchanger is purely gaseous.

The subject of the invention is also an installation for treating an LNG stream obtained by cooling by means of a first refrigeration cycle, the installation being of the type comprising: sub-cooling means of the LNG stream comprising a first heat exchanger for putting the LNG stream in heat exchange relation with a refrigerant fluid; and

a second cycle of semi-open refrigeration, independent of the first cycle, characterized in that it comprises:

an intermediate turbine for dynamic expansion of the sub-cooled LNG stream coming from the first heat exchanger;

means for cooling and expanding the stream coming from the intermediate turbine; a distillation column connected to the cooling and expansion means;

means for recovering a denitrogenated LNG stream at the bottom of the column, and means for recovering a gas stream at the top of the column; a stage compressor connected to the means for recovering the overhead gas stream from the column; and

means for extracting a first part of the head gas stream stitched at an intermediate pressure stage of the compressor, to form a fuel gas stream; and in that the second refrigeration cycle comprises: means for forming a starting refrigerant flow stream from a second portion of the overhead gas compressed at the intermediate pressure;

means for compressing the flow of refrigerant fluid at a high pressure higher than the intermediate pressure to form a compressed refrigerant fluid stream;

a second heat exchanger for cooling the stream of compressed refrigerant fluid;

means for separating the stream of compressed refrigerant fluid from the second heat exchanger into a main cooling stream and a sub-cooling stream of the LNG;

a third heat exchanger for cooling the subcooling current;

means for introducing the subcooling current from the third heat exchanger into the first heat exchanger;

means for expanding the subcooling current from the first heat exchanger to a low pressure less than the intermediate pressure to form a substantially liquid subcooling stream of the LNG; means for circulating the substantially liquid subcooling stream in the first heat exchanger to form a heated subcooling stream;

a main turbine for expanding the main cooling stream to the low pressure; means for mixing the cooling stream coming from the main turbine with the heated subcooling stream to form a mixing stream;

means for circulating the mixing stream successively in the third heat exchanger and then in the second heat exchanger to form a heated mixing stream; means for introducing the heated mixing stream into the compressor at a low pressure stage located upstream of the intermediate pressure stage.

The installation according to the invention can comprise one or more of the following characteristics, taken separately or according to any possible technical combinations:

- The expansion means of the subcooling stream from the first heat exchanger comprises a liquid expansion turbine;

the means for compressing the starting coolant stream comprise an auxiliary compressor coupled to the main turbine; the second refrigeration cycle comprises means for introducing a stream of C ₂ hydrocarbons into the compressor to form part of the flow of refrigerant starting fluid;

the second heat exchanger comprises means for circulating a secondary refrigerant fluid, the installation comprising a third refrigeration cycle comprising secondary means for compressing the secondary refrigerant fluid from the third heat exchanger, secondary means of cooling and expansion; secondary refrigerant fluid from the secondary means of compression, and means for introducing the secondary coolant from the secondary expansion means in the second heat exchanger; and

the secondary refrigerant fluid comprises propane and optionally ethane; and

it comprises means for mixing the sub-cooled LNG stream with a make-up stream of natural gas, and a fourth heat exchanger for putting the make-up stream in heat exchange relation with the overhead gas stream. Examples of implementation of the invention will now be described with reference to the accompanying drawings, in which:

- Figure 1 is a functional block diagram of a first installation according to the invention; FIG. 2 is a graph showing the efficiency curves of the second refrigeration cycle of the installation of FIG. 1, as a function of the temperature of the LNG at the inlet of the first exchanger;

- Figure 3 is a diagram similar to that of Figure 1 of a second installation according to the invention; - Figure 4 is a diagram similar to that of Figure 1 of a third installation according to the invention; and

- Figure 5 is a diagram similar to that of Figure 1 of a fourth installation according to the invention.

The first subcooling installation 9 according to the invention, represented in FIG. 1, is intended for production, from a stream 11 of liquefied natural gas (LNG) starting at a temperature below

- 9O ⁰ C, a denitrogenated LNG stream 13. The installation 9 also produces a fuel gas stream 16 rich in nitrogen.

As illustrated in FIG. 1, the starting LNG stream 11 is produced by a natural gas liquefaction unit 15 comprising a first refrigeration cycle 17. The first cycle 17 comprises, for example, a cycle comprising means for condensing and vaporizing a mixture of hydrocarbons.

The installation 9 comprises a first subcooling heat exchanger 19, a second half open refrigeration cycle 21, independent of the first cycle 17, and a denitrogenation unit 23.

The second refrigeration cycle 21 comprises a stage 25 compression apparatus having a plurality of compression stages 27.

Each stage 27 comprises a compressor 29 and a refrigerant 31. The second cycle 21 further comprises a second heat exchanger 33, a third heat exchanger 35, an expansion valve 37 and an auxiliary compressor 39 coupled to a main expansion turbine 41. The second cycle 21 also comprises an auxiliary refrigerant 43.

In the example shown in FIG. 1, the stage compressor comprises four compressors 29. The four compressors 29 are driven by the same source 45 of external energy. The source 45 is for example a gas turbine engine type.

The refrigerants 31 and 43 are cooled by water and / or air.

The denitrogenation unit 23 comprises an intermediate hydraulic turbine 47 coupled to a current generator 48, a distillation column 49, a heat exchanger 51 at the top of the column and a heat exchanger 53 at the bottom of the column. It further comprises a pump 55 for evacuating the de-nitrogenated LNG 13.

In what follows, we will designate by a single reference a liquid stream and the pipe that carries it, the pressures considered are absolute pressures, and the percentages considered are molar percentages.

The starting LNG stream 11 coming from the liquefaction unit 15 is at a temperature below -90 ^° C., for example at-130 ^° C. This stream 11 comprises, for example, substantially 5% of nitrogen, 90% of methane and 5% ethane, and its flow rate is 50,000 kmol / h.

The LNG stream 11 is introduced into the first heat exchanger 19, where it is sub-cooled to a temperature of-150 ^° C. to produce a stream 57 of sub-cooled LNG.

The stream 57 is then introduced into the hydraulic turbine 47 and dynamically expanded to a low pressure, to form a stream 59 expanded. This stream 59 is essentially liquid, that is to say that it contains less than 2 mol% of gas. The stream 59 is cooled in the foot heat exchanger 53, then introduced into an expansion valve 61 where it forms a supply stream 64 of the column 49. The stream 64 is introduced at the top of the distillation column 49, at a low distillation pressure. The low distillation pressure is slightly above atmospheric pressure. In this example, this pressure is 1.25 bar, and the temperature of stream 64 is about -165 ° C.

A make-up stream 63 of natural gas, substantially of the same composition as the starting LNG stream 11, is cooled in the head exchanger 51 and then expanded in a valve 65 and mixed with the depressurized subcooled LNG stream 59. upstream of the valve 61.

A reboiling stream 68 is extracted from the column 49 at an intermediate stage Ni, located in the vicinity of the bottom of this column. The stream 68 is introduced into the exchanger 53, where it is heated by heat exchange with the expanded sub-cooled LNG 59 stream, before being reintroduced into the column 49 under the intermediate level Ni.

A liquid foot stream 67 containing less than 1% nitrogen is withdrawn from column 49. This foot stream 67 is pumped by pump 55 to form the denitrogenated LNG stream 13 to be sent to a storage. A gaseous overhead stream 69, containing about 50% nitrogen, is withdrawn from the distillation column 49. This stream 69 is heated by heat exchange with the makeup stream 63 in the head exchanger 51 to form a heated stream 71. This stream 71 is introduced into the first stage 27A of the compression apparatus 25. The heated overhead stream 71 is successively compressed in the first stage 27A and in the second stage 27B of the compressor 25 to substantially a low cycle pressure PB, then compressed in the third compression stage 27C before being introduced into the fourth compression stage 27D. In each stage 27 of the compressor, the overhead stream 71 is compressed in the compressor 29 followed by cooling to a temperature of about 35 ⁰ C in the associated refrigerant 31.

A first portion 16 of the compressed head stream in the fourth compression stage 27D is extracted from the compressor 29D at an intermediate pressure P1 to form the fuel gas stream. The intermediate pressure P1 is for example greater than 20 bar, and preferably substantially equal to 30 bar. The low cycle pressure PB is, for example, less than 20 bar. A second portion 73 of the overhead current continues its compression in the compressor 29D to a mean pressure substantially equal to 50 bar to form a flow of refrigerant starting fluid.

The current 73 is cooled in the exchanger 31 D and then introduced into the auxiliary compressor 39.

The flow rate of the starting coolant stream 73 is much greater than the flow rate of the fuel gas stream 16. The ratio between the two flow rates is, in this example, substantially equal to 6.5.

Current 73 is then compressed in compressor 39 to a high pressure cycle PH. This high pressure is between 40 and 100 bar, preferably between 50 and 80 bar and advantageously between 60 and 75 bar.

The stream 73 coming from the compressor 39 forms, after passing through the refrigerant 43, a stream of compressed refrigerating fluid 75. The top stream

69 contains less than 5% by mass of hydrocarbons Ct, so that the stream 75 is purely gaseous. When the high pressure is greater than about 60 bar, the stream 75 is a supercritical fluid.

The stream 75 is then cooled in the second heat exchanger 33 and separated at the outlet of this exchanger 33 into a minority sub-cooling flow stream 77 and a main cooling stream 79. The ratio of these two flows is of the order of 0.5.

The subcooling stream 77 is cooled in the third exchanger 35 and then in the first exchanger 19 to form a cooled subcooling stream 81. The stream 81 is expanded to the low cycle pressure PB in the valve 37, from which it exits as a substantially liquid subcooling stream 83, i.e. containing less than 10 % mol of gas.

The stream 83 is then introduced into the first exchanger 19, where it vaporizes and cools the stream 81 and the starting LNG stream 11 by heat exchange, to form, at the outlet of the first exchanger 19, a stream 85 of heated cooling.

The main gas stream 79 is expanded in the turbine 41 to substantially the low cycle pressure PB and mixed with the heated stream 85 from the first heat exchanger 19 to form a mixing stream 87. The mixing stream 87 is then introduced successively into the third heat exchanger 35, then into the second heat exchanger 33, where it cools by heat exchange relation, respectively the heat flow. -cooling 77 and the compressed coolant stream 75.

The heated mixing stream 89 from the exchanger 33 is then introduced into the compression apparatus 25 at the inlet of the third compression stage 27C, substantially at the low pressure PB.

By way of illustration, the pressure values, the temperatures and the flow rates in the case where the high cycle pressure PH is substantially equal to 75 bars are given in the table below.

TABLE 1

In FIG. 2, the efficiency curve 91 of the cycle 21 in the process according to the invention is represented as a function of the temperature value of the LNG stream 11. As illustrated in this FIGURE, the yields are greater than 44% , which constitutes a significant gain over the methods of the state of the art involving a semi-open inverted Brayton cycle.

This result is obtained simply, since it is not necessary to provide means for storing and preparing a refrigerant, the refrigerant 73 being delivered continuously by the installation 9. The method and the Installation 9 of the present invention are used either in new liquefaction units, or to improve the performance of existing LNG production units. In the latter case, at the same power consumption, denitrogenized LNG production can be increased by 5%

20%. The method and plant 9 according to the invention can also be used to subcool and de-nitrogen LNG produced in natural gas liquids extraction (NGL) processes.

The installation 99 shown in FIG. 3 differs from the first installation 9 in that the expansion valve 37 situated downstream of the first exchanger is replaced by a dynamic expansion turbine 101 coupled to a current generator 103.

The method of treating the LNG stream in this installation is also identical to the method implemented in the installation 9, to the numerical values.

In a variant shown in dashed lines in FIG. 3, a stream of ethane 92 is mixed with the heated mixture stream 89 before it is introduced into the third compression stage 27C.

The efficiency of the cycle 21 is then further increased, as shown in curve 93 of FIG. The third installation according to the invention 104 is shown in FIG. 4. This installation 104 differs from the second installation 99 in that it also comprises a third closed refrigeration cycle 105, independent of the first and second cycles 17 and 21. The third cycle 105 comprises a secondary compressor 107, first and second secondary refrigerants 109A and 109B, an expansion valve 111 and a separator tank 113.

This cycle is carried out using a secondary refrigerant fluid stream 115 made of propane. The gaseous stream 115 at low pressure is introduced into the compressor 107, then cooled and condensed at the high pressure in the coolers 109A and 109B to form a stream 117 of partially liquid propane. This stream 117 is cooled in the exchanger 33, then introduced into the expansion valve 111, where it is expanded and forms a two-phase stream of expanded propane 119. The stream 119 is introduced into the separator tank 113 to form a liquid fraction 121. The fraction 121 is introduced into the exchanger 33, where it is vaporized by heat exchange with the stream 117 and with the stream 75 of compressed refrigerant, before being introduced into the balloon 113. The gaseous fraction from the head of the flask 113 forms the gaseous propane stream 115.

As illustrated by the curve 123 of FIG. 2, the efficiency of the cycle 21 is then increased by 4% on average with respect to the efficiency of the method implemented in the first installation 9. The fourth installation 25 according to FIG. invention 125, shown on the

Figure 5, differs from that shown in Figure 4 in that the third refrigerant cycle 105 is free of separator tank 113. The stream 119 from the valve 111 is directly introduced into the second exchanger 33 and completely vaporized in this exchanger. Moreover, the refrigerant 115 is composed of a mixture of ethane and propane. The ethane content in the fluid 115 is substantially equal to the propane content. As illustrated in curve 126 of FIG. 2, the average efficiency of the second refrigeration cycle is then increased by about 0.5% relative to the efficiency of the process implemented in the third installation 104 when the temperature is higher. below -13O ⁰ C. Taking into account the energy produced by the turbine 47, the overall efficiency of the installation of Figure 5 is slightly greater than 50%, against about 47.5% for that of Figure 1 , 47.6% for that of Figure 3 and 49.6% for that of Figure 4.

Claims

A method of treating a stream (11) of LNG obtained by cooling by means of a first refrigeration cycle (17), the process being of the type comprising the following steps: (a) introducing the LNG stream ( 11) brought to a temperature below -100 ⁰ C in a first heat exchanger (19);

(b) subcooling the LNG stream (11) in the first heat exchanger by heat exchange with a refrigerant (83) to form a subcooled LNG stream (57); and (c) the cooling fluid (83) is subjected to a second refrigeration cycle (21) semi-open, independent of the first cycle (15), characterized in that the method comprises the following steps:

(d) dynamically expanding the subcooled LNG stream (57) in an intermediate turbine (47) while maintaining this stream substantially in the liquid state;

(e) cooling and expanding the stream (59) from the intermediate turbine (47) and introducing it into a distillation column (49);

(f) recovering a denitrogenated LNG stream (67) at the bottom of the column (49), and a gas stream (69) at the top of the column (49); and (g) compressing the overhead gas stream (69) in a stage compressor (25), and extracting, at an intermediate pressure stage (29D) from the compressor (25), a first portion (16) of the a head gas stream (69) brought to an intermediate pressure P1 to form a fuel gas stream; and in that the second refrigeration cycle (21) comprises the following steps:

(i) forming a starting coolant stream (73) from a second portion of the compressed overhead gas (69) at the intermediate pressure

Pl; (ii) compressing the starting coolant stream (73) to a high pressure PH greater than the intermediate pressure P1 to form a compressed coolant stream (75); (iii) cooling the stream of compressed refrigerant (75) in a second heat exchanger (33);

(iv) separating the compressed refrigerant stream (75) from the second heat exchanger (33) into a majority cooling stream (79) and an LNG subcooling stream (77);

(v) cooling the subcooling stream (77) in a third heat exchanger (35) and then in the first heat exchanger (19);

(vi) the subcooling stream (81) from the first heat exchanger (19) is expanded to a low pressure PB lower than the intermediate pressure P1 to form a substantially liquid stream (83) of sub-cooling of the LNG ;

(vii) vaporizing the substantially subcooling liquid stream (83) in the first heat exchanger (19) to form a heated subcooling stream (85);

(viii) the main cooling stream (79) is expanded substantially to the low pressure PB in a main turbine (41), and the cooling stream from the main turbine (41) is mixed with the heated cooling (85) to form a mixing stream (87);

(ix) heating the mixing stream (87) successively in the third heat exchanger (35) and then in the second heat exchanger (33) to form a heated mixing stream (89); and

(x) introducing the heated mixing stream (89) into the compressor (25) at a low pressure stage (29C) upstream of the intermediate pressure stage (29D).

2. Method according to claim 1, characterized in that the high pressure PH is between 40 and 100 bar, preferably between 50 and 80 bar approximately and in particular between 60 and 75 bar approximately.

3. Method according to one of claims 1 or 2, characterized in that the low pressure PB is less than about 20 bar.

4. Method according to any one of the preceding claims, characterized in that, in step (vi), the subcooling current (81) is expanded dynamically from the first heat exchanger (19) in a turbine of relaxation of liquid (101).

5. Method according to any one of the preceding claims, characterized in that, during step (ii), at least partially compresses the flow of refrigerant starting fluid (73) in an auxiliary compressor (39) coupled to the main turbine (41).

6. A method according to any one of the preceding claims, characterized in that in step (i) introducing a stream (92) hydrocarbon _Σ C in the compressor (25) to form part of stream of starting refrigerant (73).

7. Method according to any one of the preceding claims, characterized in that, during step (iii), the stream of compressed refrigerant fluid (75) is put in heat exchange relation with a secondary coolant (117). circulating in the second heat exchanger (33), the secondary coolant (117) undergoing a third refrigeration cycle (105) in which it is compressed at the outlet of the second heat exchanger (33), is cooled, and is at least partially condenses, then is expanded before vaporizing in the second heat exchanger (33).

8. Method according to claim 7, characterized in that the secondary coolant (117) comprises propane and optionally ethane.

9. A method according to any one of the preceding claims, characterized in that before the expansion of step (e), the stream from the intermediate turbine (47) is mixed with a make-up stream (63) of natural gas cooled by heat exchange with the overhead gas stream (69) in a fourth heat exchanger (51).

10. Method according to any one of the preceding claims, characterized in that the C ^ content of the overhead gas (69) is such that the stream cooled by the second heat exchanger (33) is purely gaseous.

11. Installation (9; 99; 104; 125) of treatment of a stream (11) of LNG obtained by cooling by means of a first refrigeration cycle (17), the plant (9; 99; 104; 125); ) being of the type comprising:

sub-cooling means for the LNG stream (11) comprising a first heat exchanger (19) for putting the LNG stream in heat exchange relation with a refrigerant (83); and

- A second refrigeration cycle (21) semi-open, independent of the first cycle (15), characterized in that it comprises: - an intermediate turbine (47) dynamic expansion of the subcooled LNG stream (57) from the first heat exchanger (19);

means (53, 61) for cooling and expanding the current (59) coming from the intermediate turbine (47),

- a distillation column (49) connected to the means (53, 61) for cooling and expansion;

means for recovering a denitrogenated LNG stream (67) at the bottom of the column (49), and means for recovering a gas stream (69) at the top of the column (49);

- a stage compressor (25) connected to the recovery means of the overhead gas stream (69) of the column (49); and

- means for extracting a first portion (16) of the overhead gas stream (69) stitched at an intermediate pressure stage (29D) of the compressor (25), to form a fuel gas stream; and in that the second refrigeration cycle (21) comprises: - means for forming a starting coolant stream (73) from a second portion of the overhead gas (69) compressed at the intermediate pressure ;

means (39) for compressing the starting coolant stream (73) to a high pressure PH greater than the intermediate pressure P1 to form a compressed refrigerant fluid stream (75);

a second heat exchanger (33) for cooling the compressed refrigerant fluid stream (75); means for separating the compressed refrigerant fluid stream (75) issuing from the second heat exchanger (33) into a main cooling stream (79) and a sub-cooling stream of the LNG (77); a third heat exchanger (35) for cooling the subcooling current (77);

means for introducing the subcooling current (77) from the third heat exchanger (35) into the first heat exchanger (19); means (37; 101) for expanding the subcooling current (81) from the first heat exchanger (19) to a low pressure PB lower than the intermediate pressure P1 to form a substantially liquid stream (83) of sub-cooling of LNG;

circulating means of the essentially liquid subcooling stream (83) in the first heat exchanger to form a heated subcooling stream (85);

a main turbine (41) for expanding the main cooling stream (79) substantially to the low pressure PB;

means for mixing the cooling stream from the main turbine (41) with the heated subcooling stream (85) to form a mixing stream (87);

means for circulating the mixing stream (87) successively in the third heat exchanger (35) and then in the second heat exchanger (33) to form a heated mixing stream (89);

means for introducing the heated mixing stream (89) into the compressor (25) at a low pressure stage (29C) located upstream of the intermediate pressure stage (29D).

12. Installation (9; 99; 104; 125) according to claim 11, characterized in that the high pressure PH is between 40 and 100 bar approximately, preferably between 50 and 80 bar approximately and in particular between 60 and 75 bar approximately .

13. Installation (9; 99; 104; 125) according to one of claims 11 or 12, characterized in that the low pressure PB is less than about 20 bar.

14. Installation (99; 104; 125) according to any one of claims 11 to 13, characterized in that the means (37; 101) for expanding the subcooling stream (81) from the first heat exchanger (19). ) comprise a liquid expansion turbine (101).

15. Installation (9; 99; 104; 125) according to any one of claims 11 to 14, characterized in that the means (39) for compressing the starting coolant stream (73) comprise an auxiliary compressor (39). ) coupled to the main turbine (41).

16. Installation (99) according to any one of claims 11 to 15, characterized in that the second refrigeration cycle (21) comprises means for introducing a stream (92) of C ₂ hydrocarbons in the compressor (25) to form a portion of the starting coolant stream (73).

17. Installation (104; 125) according to any one of claims 11 to 16, characterized in that the second heat exchanger (33) comprises means for circulating a secondary refrigerant (117), the installation (104) ; 125) comprising a third refrigeration cycle (105) comprising secondary means (107) for compressing the secondary coolant (115) from the third heat exchanger (33), secondary means (109, 111) for cooling and expansion secondary refrigerant (117) from the secondary means of compression (107), and means for introducing the secondary refrigerant (119) from the secondary expansion means (111) in the second heat exchanger (33).

18. Installation (104; 125) according to claim 17, characterized in that the secondary coolant (117) comprises propane and optionally ethane.

19. Installation (9; 99; 104; 125) according to any one of claims 11 to 18, characterized in that it comprises means for mixing the subcooled LNG stream (59) with a make-up stream. (63) of natural gas, and a fourth heat exchanger (51) for connecting heat exchanging the makeup stream (63) with the overhead gas stream (69).