Integration of cold solvent and acid gas removal

Patent metadata

Field	Value
Publication number	US-11000797-B2
Application number	US-201816102297-A
Country	US
Kind code	B2
Filing date	Aug 13, 2018
Priority date	Aug 21, 2017
Publication date	May 11, 2021
Grant date	May 11, 2021

Abstract

A method of separating impurities from a natural gas stream. The natural gas stream is cooled through heat exchange with one or more process streams to produce a chilled gas stream, which is contacted with a lean solvent stream in a contactor to separate hydrogen sulfide (H2S) from the chilled gas stream, thereby producing a rich solvent stream and a partially-treated gas stream. Carbon dioxide (CO2) and H2S are separated from the partially-treated gas stream in a membrane separation system, thereby creating a fully-treated gas stream and a permeate gas stream, the permeate gas stream being comprised primarily of H2S and CO2, and the fully-treated gas stream being comprised primarily of natural gas. The fully-treated gas stream and the permeate gas stream are at a lower temperature than the partially-treated gas stream. The fully-treated gas stream and the permeate gas stream comprise the one or more process streams.

First claim

What is claimed is:

1. A method of separating impurities from a natural gas stream, comprising:
cooling the natural gas stream through heat exchange with one or more process streams to produce a chilled gas stream;
contacting the chilled gas stream with a lean solvent stream comprising a hindered amine in a contactor to separate hydrogen sulfide (H 2 S) and carbon dioxide (CO 2 ) from the chilled gas stream, thereby producing a rich solvent stream and a partially-treated gas stream;
removing H 2 S and CO 2 from the rich solvent stream to produce the lean solvent stream;
recirculating the lean solvent stream to the contactor; and
separating CO 2 and H 2 S from the partially-treated gas stream in a membrane separation system, thereby creating a fully-treated gas stream and a permeate gas stream, the permeate gas stream being comprised of H 2 S and CO 2 and having a higher concentration of H 2 S and CO 2 than the partially-treated gas stream, and the fully-treated gas stream being comprised of natural gas and having a lower concentration of H 2 S and CO 2 than the partially-treated gas stream, wherein the fully-treated gas stream and the permeate gas stream are at a lower temperature than the partially-treated gas stream;
wherein the fully-treated gas stream and the permeate gas stream comprise the one or more process streams;
wherein the contactor is a co-current contacting system and wherein contacting the chilled gas stream with a lean solvent stream further comprises:
receiving the chilled gas stream and the lean solvent stream in the co-current contacting system located in-line within a pipe, the co-current contacting system including a droplet generator and a mass transfer section;
using the droplet generator, generating droplets from the lean solvent stream and dispersing the droplets into the chilled gas stream;
using the mass transfer section, providing a mixed, two-phase flow having a vapor phase and a liquid phase, wherein the liquid phase includes the rich solvent stream with H 2 S and/or CO 2 absorbed from the chilled gas stream, and wherein the vapor phase includes the partially-treated gas stream; and
separating the vapor phase from the liquid phase.

2. The method of claim 1 , further comprising:
removing CO 2 from the fully-treated gas stream in a polisher.

3. The method of 1 , further comprising:
compressing the CO 2 removed from the fully-treated gas stream in the polisher.

4. The method of claim 1 , further comprising:
cooling the lean solvent stream prior to recirculating the lean solvent stream to the contactor.

5. The method of claim 1 , further comprising:
further cooling the natural gas stream prior to contacting the chilled gas stream with the lean solvent stream in the contactor.

6. The method of claim 1 , further comprising:
removing water from the partially-treated gas stream prior to separating H 2 S and CO 2 from the partially-treated gas stream.

7. The method of claim 1 , wherein the droplet generator comprises:
an annular support ring securing the droplet generator in-line within the pipe;
a plurality of spokes extending from the annular support ring, the annular support ring having a plurality of liquid channels allowing the lean solvent stream to flow through the plurality of spokes and out of injection orifices disposed on the plurality of spokes; and
a gas entry cone supported by the plurality of spokes and allowing
a first portion of the chilled gas stream to flow through a hollow section of the gas entry cone and through gas exit slots included in the plurality of spokes, and
a second portion of the chilled gas stream to flow around the gas entry cone and between the plurality of spokes, wherein the second portion of the chilled gas stream is separate from the first portion of the chilled gas stream.

8. The method of claim 1 , wherein the co-current contacting system is one of a plurality of co-current contacting systems connected in series, said plurality of co-current contacting systems including a last co-current contacting system;
wherein each of the plurality of co-current contacting system comprises
a co-current contactor including a droplet generator and a mass transfer section, the droplet generator generating droplets of a liquid stream and dispersing the droplets into a gas stream received from a previous co-current contacting system, and the mass transfer section providing a mixed, two-phase flow having a vapor phase and a liquid phase; and

a separation system that separates the vapor phase from the liquid phase, wherein the vapor phase includes a gas stream and the liquid phase includes liquid from which droplets are generated in a co-current contactor of a previous co-current contacting system.

9. The method of claim 1 , wherein the natural gas stream is cooled through heat exchange with the fully-treated gas stream and the permeate gas stream.

Assignees

• Maher David W
• Ramkumar Shwetha
• Northrop P Scott
• Denton Robert D
• Exxonmobil Upstream Res Co

Inventors

• Maher David W
• Ramkumar Shwetha
• Northrop P Scott
• Denton Robert D

Classifications

• Y02C20/40

  of CO2 · CPC title

• B01D61/246

  Membrane extraction · CPC title

• C10L2290/548

  Membrane- or permeation-treatment for separating fractions, components or impurities during preparation or upgrading of a fuel · CPC title

• C10L2290/06

  Heat exchange, direct or indirect · CPC title

• C10L3/106

  of water · CPC title