Method to produce liquefied natural gas (LNG) at midstream natural gas liquids (NGLs) recovery plants

• US 10,634,426 B2
• Filed: 12/20/2012
• Issued: 04/28/2020
• Est. Priority Date: 12/20/2011
• Status: Active Grant

• Current Assignee: 1304338 Alberta, Ltd., 1304342 Alberta, Ltd.
• Original Assignee: 1304338 Alberta, Ltd.
• Inventors: Lourenco, Jose, Millar, MacKenzie
• Primary Examiner(s): King, Brian M
• Application Number:
  US13/722,910
• Publication Number:
  US 20130152627A1
• Time in Patent Office: 2,686 Days
• Field of Search: 62618, 62619, 62620, 62621, 62622
• CPC Class Codes: F25J 1/0022 Hydrocarbons, e.g. natural gas
• CPC Class Codes: F25J 2200/02 in a single pressure main column system
• CPC Class Codes: F25J 2200/74 Refluxing the column with at least a part of the partially condensed overhead gas
• CPC Class Codes: F25J 2205/04 in the feed line, i.e. upstream of the fractionation step
• CPC Class Codes: F25J 2215/04 Recovery of liquid products
• CPC Class Codes: F25J 2220/04 Separating impurities in general from the product stream
• CPC Class Codes: F25J 2220/66 Separating acid gases, e.g. CO2, SO2, H2S or RSH
• CPC Class Codes: F25J 2240/02 Expansion of a process fluid in a work-extracting turbine (i.e. isentropic expansion), e.g. of the feed stream
• CPC Class Codes: F25J 2245/02 Recycle of a stream in general, e.g. a by-pass stream
• CPC Class Codes: F25J 2270/02 Internal refrigeration with liquid vaporising loop
• CPC Class Codes: F25J 2270/04 Internal refrigeration with work-producing gas expansion loop
• CPC Class Codes: F25J 2280/02 Control in general, load changes, different modes ("runs"), measurements
• CPC Class Codes: F25J 3/0209 Natural gas or substitute natural gas
• CPC Class Codes: F25J 3/0233 separation of CnHm with 1 carbon atom or more
• CPC Class Codes: F25J 3/0238 separation of CnHm with 2 carbon atoms or more

Abstract

A method for production of liquid natural gas (LNG) at natural gas liquids (NGLs) recovery plants that maximizes NGLs recovery by producing LNG and using the produced LNG as an external cooling source to control the operation of a de-methanizer column at the NLG recovery facility. In at least one embodiment, LNG is added from an LNG overhead receiver by direct mixing to control the temperature profile in the NGL de-methanizer column. The temperature in an overhead product of the de-methanizer column is controlled by controlling addition of LNG as a reflux stream. The temperature in an expanded feed gas to the de-methanizer column is controlled by controlling addition of LNG as a tempering gas, while stripping of carbon dioxide from an NGL product stream is controlled by controlling the addition of LNG as stripping gas.

Claims

1. A method for production of liquid natural gas (LNG) at natural gas liquids (NGLs) recovery plants and improvements to recovery of natural gas liquids from natural gas using LNG, comprising:

providing a pressurized natural gas stream to an NGL recovery plant, the pressurized natural gas stream being diverted from a natural gas pipeline at a pipeline pressure;

operating a de-methanizer column of the NGL recovery plant to produce an overhead stream and an NGL product stream from the pressurized natural gas stream, wherein operating the de-methanizer column comprises at least controlling a temperature within the de-methanizer column;

passing at least a portion of the overhead stream of the de-methanizer column through a carbon dioxide removal unit;

producing LNG at a pressure and temperature below which carbon dioxide condenses by reducing the pressure and temperature of the output of the carbon dioxide removal unit;

transferring a portion of the produced LNG to storage; and

using a further portion of the produced LNG as an external cooling source to condition an input stream to the de-methanizer column by directly mixing the portion of the produced LNG with an input stream, the input stream being derived from the pressurized natural gas stream,

wherein the temperatures to produce the NGL product stream and the produced LNG are exclusively derived by reducing the pressure of natural gas from the pressurized natural gas stream within the NGL recovery plant.

2. The method as defined in claim 1, where the LNG is produced by reducing the pressure and temperature of the output of the carbon dioxide removal unit through one of a gas expander or JT valve.

3. The method as defined in claim 1, where a further portion of the produced LNG is provided as a reflux stream by a temperature control of an overhead gas stream by mixing of LNG with a rising gas stream in the de-methanizer column.

4. The method as defined in claim 1, wherein the input stream is an un-distilled, expanded, feed gas stream, and wherein the produced LNG is mixed with the input stream to condition the input stream entering the de-methanizer column.

5. The method as defined in claim 1, further comprising the step of preheating LNG and adding the preheated LNG to the de-methanizer column for use as a stripping fluid for reducing a carbon dioxide concentration in the NGL product stream of the de-methanizer column.

11. The method as defined in claim 1, wherein the at least a portion of the overhead stream is passed to the carbon dioxide removal unit at substantially the same pressure as the de-methanizer column.

6. A method for recovery of natural gas liquids (NGLs) from a natural gas by using a portion of produced liquid natural gas (LNG) at an NGL recovery plant facility, the NGL recovery plant facility having at least one de-methanizer column fed by a feed gas, the method comprising the steps of:

adding the portion of produced LNG from an LNG overhead receiver by directly mixing the LNG and the feed gas prior to being fed to the de-methanizer column to control a temperature profile of an NGL de-methanizer column;

a temperature in an overhead product of the NGL de-methanizer column being controlled by controlling addition of LNG as a reflux stream;

a temperature in the feed gas to the de-methanizer column being controlled by controlling addition of LNG to the feed gas as a tempering fluid; and

preheating a stream of LNG and reducing a carbon dioxide concentration in an NGL product stream by controlling the addition of the preheated LNG as stripping fluid to the lower section of the de-methanizer column.

7. The method as defined in claim 6, wherein produced LNG is used to cool an inlet plant gas feed.

8. The method as defined in claim 7, where a gaseous stream from the LNG overhead receiver is used as a source of cooling for the inlet plant gas feed.

9. The method as defined in claim 6, wherein the feed gas to the at least one de-methanizer column is an expanded feed gas.

10. The method as defined in claim 6, wherein a further portion of the produced LNG is used in a heat exchanger to condition the temperature of the feed gas prior to being injected into the de-methanizer column.