US20090107176A1

US20090107176A1 - Integrated Process and Gas Treatment Process

Info

Publication number: US20090107176A1
Application number: US12/348,540
Authority: US
Inventors: Alain Guillard; Patrick Le Bot; Bernard Saulnier
Original assignee: LAir Liquide SA pour lEtude et lExploitation des Procedes Georges Claude
Current assignee: LAir Liquide SA pour lEtude et lExploitation des Procedes Georges Claude
Priority date: 2004-02-13
Filing date: 2009-01-05
Publication date: 2009-04-30
Also published as: US20050178153A1; CN1918445A; WO2005080893A1; EP1716372A1; US20060000212A1; CN100451508C; US7490484B2; US20070137247A1; US7197894B2

Abstract

Integrated air separation units with a petrochemical process. This invention provides an integrated process and gas treatment process wherein at least one first pressurized gas derived from a first process at a first site is expanded. Using the work generated by the expansion of at least one pressurized gas, a first gas compressor at the first site is driven, operates, and removes compressed gas from the first gas compressor. At least part of the compressed gas from the first gas compressor is sent to a gas treatment unit located at a remote second site. At least part of the compressed gas sent from the first site to the second site is treated in the gas treatment unit. At least one fluid from the gas treatment unit is removed and at least part of the fluid removed from the gas treatment unit is sent to the first site.

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a Continuation of U.S. Non-Provisional application Ser. No. 11/159,954 filed Jun. 23, 2005 which is a Continuation-in-Part of U.S. Non-Provisional application Ser. No. 10/778,572, filed Feb. 13, 2004, the entire contents of which are incorporated herein by reference.

BACKGROUND

Current natural gas reserves are often situated far from world markets. Although it is possible to transport the natural gas, in many cases it is preferred to convert the natural gas fields in situ into more readily transportable products such as synthetic fuels, methanol or dimethyl ether. The conversion processes generally consume very large amounts of oxygen and produce excess steam. Background for this field is to be found in “Oxygen Facilities for Synthetic Fuel Projects”, by W. J. Scharle et al., Journal of Engineering for Industry, November 1981, Vol. 103, pp. 409-417, in “Fundamentals of Gas to Liquids” January 2003, The Petroleum Economist Ltd, and in EP-A-0748763.
It is not always possible to construct an air separation unit close to the site of the conversion process, for example for environmental or economic reasons. In this case, the steam generated is sent via a pipeline to the air separation unit site and there it is expanded in a turbine coupled to the main compressor of the air separation unit.
However, the cost of such steam pipelines is prohibitive since the steam has to be maintained at a high temperature to prevent condensation.
In some cases, there may be a number of processes, each producing excess energy in the form of steam or another hot gas. There may be insufficient energy available on the site of the process to justify exporting that energy and the steam or other hot gas may be vented to the atmosphere. Furthermore, the individual processes may each produce a different grade of steam, such that the two grades of steam cannot be sent to a single steam turbine.

SUMMARY

It is an object of the present invention to provide a process for separating air using the energy generated by a process remote from the air separation unit.
This invention provides an integrated process and gas treatment process wherein at least one first pressurized gas derived from a first process at a first site is expanded. Using the work generated by the expansion of at least one pressurized gas, a first gas compressor at the first site is driven, operates, and removes compressed gas from the first gas compressor. At least part of the compressed gas from the first gas compressor is sent to a gas treatment unit located at a remote second site. At least part of the compressed gas sent from the first site to the second site is treated in the gas treatment unit. At least one fluid from the gas treatment unit is removed and at least part of the fluid removed from the gas treatment unit is sent to the first site.

BRIEF DESCRIPTION OF THE DRAWINGS

For a further understanding of the nature and objects for the present invention, reference should be made to the following detailed description, taken in conjunction with the accompanying drawings, in which like elements are given the same or analogous reference numbers and wherein:

FIG. 1 illustrates one embodiment of the current invention, which includes an integrated process and air separation unit;

FIG. 2 illustrates a second embodiment, which includes an air separation unit integrated with two integrated processes; and

FIG. 3 illustrates a third embodiment with an integrated process and air separation unit.

The figures are not to scale.

DESCRIPTION OF PREFERRED EMBODIMENTS

The term “partly pressurized” implies that the oxygen or nitrogen streams may for example be pumped to a pressure less than their required pressure and then vaporised at the second site before entering the pipelines. Compressors at the first site subsequently compress the nitrogen and oxygen to their required final pressures, if needed.
FIG. 1 shows an integrated process and air separation unit.
The integrated process unit 31 is located at a first site 1 and may for example be a GTL unit, for example comprising a Fischer Tropsch unit, a methanol production unit, a DME production unit, a fuel combustion unit such as a gas turbine or any unit producing directly or indirectly steam or another hot gas.
The term “process unit” implies that a process takes place at some location and at some time within the unit. However, the unit itself does not necessarily operate according to a process, which is globally exothermic.
The steam or other hot gas 39 is expanded in a turbine 33 (which may form part of process unit 31) located at the first site 1 and work from the turbine is transferred via coupling to an air compressor 5. In this example, the air compressor 5 compresses only air 7 to be sent to the air separation unit 21. The compressed air 19 is compressed to a pressure above 8 bars, preferably above 12 bars and is sent to the air separation unit 21 at a second site 2 at least 1 km away. It is nevertheless conceivable that compressed air from the air compressor 5 could also be sent elsewhere, i.e., to another air separation unit.
Compressed air may also be sent to the air separation unit 21 from an air compressor 25 located at the second site 2.
Air to be separated in the air separation unit 21 is purified in a purification unit at the second site and all the air streams sent to the air separation unit 21 at the second site from the purification unit at the second site are at pressures less than 50 bars.
A product gas 37 (which may be replaced by a product liquid) coming from the air separation unit is also sent to another pipeline running at least substantially parallel to the air pipeline over at least part of its length, thereby saving civil engineering costs. This gas, which may be nitrogen, oxygen or argon, is unpressurized, partly pressurized or pressurized. Where the gas is unpressurized or partly pressurized, it may be compressed in a compressor 47 coupled to the turbine 33 at the first site. The gas may then be used at the first site and may for example be used in the process.
FIG. 2 shows an air separation unit 21 integrated with two integrated processes. The first process unit 31 is as described above with reference to FIG. 1. The further process unit 31A is located at a third site 3, at least 1 km from the second site, where the air separation unit 3 is located and, preferably, at least 1 km from the first site. However, the further unit 31A may be adjacent to the first site.
The further process unit 31A may operate according to the same process as the first unit 31 or according to a different process.
The unit 31A produces steam or another hot gas 39A, which is expanded in turbine 33A. Gases 39 and 39A may both be steam but the gas 39A may be steam having the same or different properties, i.e., the same or a different pressure as the gas 39 and/or the same or a different temperature as the gas 39.
Air compressor 5A driven by turbine 33A supplies air 19A only to the air separation unit via pipeline. The air 7A compressed by compressor 5A is compressed to a pressure above 8 bars, preferably above 12 bars.
Additionally, as in FIG. 1, there may a dedicated air compressor at the second site 2.
Preferably, the pipelines 19, 19A, and the compressors 5 and 5A supply the air to the second site 2 at substantially the same pressure so that only a single purification unit within the air separation unit 21 is necessary. This may mean that the compressors 5 and 5A compress the air to substantially the same pressure, if the pressure losses within the pipelines are substantially the same. Alternatively, the compressors 5 and 5A may compress the air to different pressures but the air arrives at the air separation unit at substantially the same pressure from both pipelines due to a judicious choice of the pipeline diameters and/or lengths and/or the use of an expansion means, such as a valve.
If several purification means are provided, the air supplied by the compressors 5 and 5A may arrive at the second site at different pressures (due to different pressures at the compressor outlets and/or different pressure drops within the pipeline systems). In this case, the air pressures may be selected or modified at the second site to correspond to pressures of different columns of the air separation unit. For example, one air stream may be purified at the pressure of the high pressure column of the air separation unit whereas another air stream may be purified at the pressure of an intermediate or low pressure column of the air separation unit.
A product gas 37A coming from the air separation unit is also sent to another pipeline running substantially parallel to the air pipeline for air 19A over at least part of its length. This gas, which may be nitrogen, oxygen or argon, is unpressurized, partly pressurized, or pressurized. Where the gas is unpressurized or partly pressurized, it may be compressed in a compressor coupled to the turbine 33A at the third site. The gas may then be used at the third site, for example in the process or another process.
Alternatively, the pipeline for air 19A may run substantially parallel to the pipeline for air 19 over at least a part of its length or may feed into that pipeline 19 (or vice versa depending on where the sites 1, 2, 3 are).
Similarly, the pipeline for gas 37A may run substantially parallel to the pipeline for gas 37 over at least a part of its length or may feed into that pipeline 37 (or vice versa depending on where the sites are) if the gases have substantially the same purity or can be mixed to form a mixture having a required composition.
At least one fluid produced by the air separation unit may be sent to the first or third site or both.
The third site 3 may be contiguous with the second site 2, less than 1 km from the second site, or at least 1 km from the second site, and/or the third site 3 may be contiguous with the first site 1, less than 1 km from the first site, or at least 1 km from the first site.
The air separation unit may be of any known type. Ideally, there should be no air compressor 25 located at the second site to produce air for the air separation unit. All the feed air should come from other sites. One example of an air separation process well suited to this application is that of FIG. 1 of EP-A-0504029, where all the air is compressed to a high pressure using a single compressor.
It will be appreciated that a first stream of air may be compressed using work from a first expansion step (such as a steam turbine expansion) and a second stream of air may be compressed using work from a second expansion step (such as a gas turbine expansion), the first and second air streams may be mixed, possibly after pressure equalisation and sent from the first site to the second site.
FIG. 3 shows an integrated process and air separation unit.
The integrated process unit 31 is located at a first site 1 and may for example be a GTL unit, for example comprising a Fischer Tropsch unit, a methanol production unit, a DME production unit, a fuel combustion unit such as a gas turbine or any unit producing directly or indirectly steam or another hot gas.
The term “process unit” implies that a process takes place at some location and at some time within the unit. However the unit itself does not necessarily operate according to a process, which is globally exothermic.
The steam or other hot gas 39 is expanded in a turbine 33 (which may form part of process unit 31) located at the first site 1 and work from the turbine is transferred via coupling to an air compressor 5. In this example, the air compressor 5 compresses only air 7 to be sent to the air separation unit 21. The compressed air 19 is compressed to a pressure above 8 bars, preferably above 12 bars and is sent to the air separation unit 21 at a second site 2 at least 1 km away. It is nevertheless conceivable that compressed air from the air compressor 5 could be sent elsewhere, for example to another air separation unit.
Compressed air is sent to the air separation unit 21 from an air compressor 25 located at the second site 2. The air compressor 25 is driven by a turbine 33B, which expands gas 32B from a process unit 31B at the second site. Air to be separated in the air separation unit 21 is purified in a purification unit at the second site and all the air streams sent to the air separation unit 21 at the second site from the purification unit at the second site are at pressures less than 50 bars.
A product gas 37 (which may be replaced by a product liquid) coming from the air separation unit is also sent to another pipeline running at least substantially parallel to the air pipeline over at least part of its length, thereby saving civil engineering costs. This gas, which may be nitrogen, oxygen or argon, is unpressurized, partly pressurized or pressurized. Where the gas is unpressurized or partly pressurized, it may be compressed in a compressor 47 coupled to the turbine 33 at the first site. The gas may then be used at the first site and may for example be used in the process.
It will be understood that many additional changes in the details, materials, steps and arrangement of parts, which have been herein described in order to explain the nature of the invention, may be made by those skilled in the art within the principle and scope of the invention as expressed in the appended claims. Thus, the present invention is not intended to be limited to the specific embodiments in the examples given above.

Claims

1. A method which may be used as an integrated gas treatment process, said method comprising:

a) expanding at least one first pressurized gas, wherein said first pressurized gas is derived from at least one first process performed at a first site;

b) driving at least a first gas compressor with the work generated by said expansion of said first pressurized gas, wherein said first gas compressor is located at said first site;

c) removing a first compressed gas from said first gas compressor;

d) sending at least part of said first compressed gas to a gas treatment unit, wherein:

1) said gas treatment unit is located at a second site; and

2) said second site is located at least about 1 km away from said first site;

e) treating said first compressed gas in said gas treatment unit;

f) removing at least one fluid from said first compressed gas; and

g) sending at least part of said removed fluid from said gas treatment unit to said first site.

2. The method of claim 1, wherein:

a) said work generated by said expansion of said first pressurized gas drives a first air compressor, wherein said first air compressor is located at said first site;

b) a compressed air stream is removed from said first air compressor;

c) at least part of said compressed air stream is sent to an air separation unit, wherein said air separation unit is located at said second site;

d) said air separation unit separates air and at least one fluid enriched in a component of air is removed from said unit; and

e) at least part of said fluid enriched in a component of air is sent to said first site.

3. The process of claim 1, wherein said first site is located at least about 5 km away from said second site.

4. The method of claim 1, wherein said first compressed gas removed from said first gas compressor has a pressure of at least about 8 bar.

5. The method of claim 4, wherein said first compressed gas has a pressure of at least about 12 bar.

6. The process of claim 1, wherein said first pressurized gas is steam.

7. The method of claim 1, wherein said first pressurized gas comprises at least one member selected from the group consisting of:

a) air; and

b) a hot gas produced by a combustor of a gas turbine.

8. The method of claim 1, further comprising deriving said first pressurized gas from a first process, wherein said first process comprises at least one member selected from the group consisting of:

a) a fuel combustion process;

b) a GTL process;

c) a methanol production process;

d) a gas turbine process; and

e) a DME production process.

9. The method of claim 1, wherein said first process uses said removed fluid.

10. The method of claim 1, wherein substantially all of said first compressed gas is sent to said gas separation unit.

11. The method of claim 2, wherein:

a) said gas treatment unit comprises said air separation unit;

b) air to be separated in said air separation unit is first purified in a purification unit located at said second site;

c) all the streams of air sent from said purification unit to said air separation unit have pressures less than about 50 bar.

12. An apparatus which may be used for producing a fluid by gas treatment, said apparatus comprising:

a) a first process unit, wherein said first process unit is located at a first site;

b) a first turbine, wherein:

1) said first turbine is located at said first site;

2) said first turbine is coupled to at least a first gas compressor; and

3) said first gas compressor is located at said first site;

c) a means for sending a gas derived from said first process unit to said turbine;

d) a gas treatment unit, wherein:

1) said gas treatment unit is located at a second site; and

2) said second site is located at least about 1 km away from said first site;

e) a first pipeline for sending gas from said first gas compressor to said gas treatment unit; and

f) a second pipeline for sending a fluid removed from said gas treatment unit to said first site.

13. The apparatus of claim 12, wherein said first pipeline and said second pipeline run substantially parallel to each other over at least part of their length.

14. The apparatus of claim 12, wherein:

a) said gas treatment unit is a distillation unit;

b) said distillation unit comprises:

1) a purifier for purifying a gas stream downstream of said first gas compressor; and

2) a heat exchanger for bringing said purified gas stream to a temperature suitable for distillation; and

c) said purifier and said heat exchanger are both located at said second site.

15. The method of claim 1, further comprising:

a) producing said first compressed gas stream at said first site by a first compression process, wherein said first compression process comprises at least one first expansion step;

b) producing a second compressed gas stream at said first site by a second compression process, wherein said second compression process comprises at least one second expansion step;

c) mixing said first compressed gas stream and said second compressed gas stream to form a combined gas stream; and

d) sending said combined gas stream to an air separation unit located at said second site.