CA2588664C - Method to produce natural gas liquids (ngl's) at gas pressure reduction stations - Google Patents
Method to produce natural gas liquids (ngl's) at gas pressure reduction stations Download PDFInfo
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- CA2588664C CA2588664C CA2588664A CA2588664A CA2588664C CA 2588664 C CA2588664 C CA 2588664C CA 2588664 A CA2588664 A CA 2588664A CA 2588664 A CA2588664 A CA 2588664A CA 2588664 C CA2588664 C CA 2588664C
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
- F25J3/06—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation
- F25J3/063—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation characterised by the separated product stream
- F25J3/064—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation characterised by the separated product stream separation of CnHm with 2 carbon atoms or more
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
- C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
- C10L3/10—Working-up natural gas or synthetic natural gas
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
- F25J3/06—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation
- F25J3/0605—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation characterised by the feed stream
- F25J3/061—Natural gas or substitute natural gas
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
- F25J3/06—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation
- F25J3/063—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation characterised by the separated product stream
- F25J3/0635—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by partial condensation characterised by the separated product stream separation of CnHm with 1 carbon atom or more
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2220/00—Processes or apparatus involving steps for the removal of impurities
- F25J2220/60—Separating impurities from natural gas, e.g. mercury, cyclic hydrocarbons
- F25J2220/68—Separating water or hydrates
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2240/00—Processes or apparatus involving steps for expanding of process streams
- F25J2240/02—Expansion of a process fluid in a work-extracting turbine (i.e. isentropic expansion), e.g. of the feed stream
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2240/00—Processes or apparatus involving steps for expanding of process streams
- F25J2240/40—Expansion without extracting work, i.e. isenthalpic throttling, e.g. JT valve, regulating valve or venturi, or isentropic nozzle, e.g. Laval
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2260/00—Coupling of processes or apparatus to other units; Integrated schemes
- F25J2260/02—Integration in an installation for exchanging heat, e.g. for waste heat recovery
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
- F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
- F25J2260/00—Coupling of processes or apparatus to other units; Integrated schemes
- F25J2260/10—Integration in a gas transmission system at a pressure reduction, e.g. "let down" station
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- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Physics & Mathematics (AREA)
- Mechanical Engineering (AREA)
- Thermal Sciences (AREA)
- General Engineering & Computer Science (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Engine Equipment That Uses Special Cycles (AREA)
Abstract
A method to recover NGL's at gas Pressure Reducing Stations. A first step involve providing at least one heat exchanger having a flow path for passage of high pressure natural gas with a counter current depressurized lean cold gas. A second step involves passing the high pressure natural gas stream in a counter current flow with the lean cold gas and cooling it before de-pressurization. A third step involves the expansion of the high pressure cooled gas in a gas expander. The expansion of the gas generates shaft work which is converted into electrical power by the power generator and the expanded low pressure and cold gas enters a separator where NGL's are recovered. This process results in the recovery NGL's, electricity and the displacement of a slipstream of natural that is presently used to pre- heat gas at Pressure Reduction Stations.
Description
TITLE OF THE INVENTION:
Method to produce Natural Gas Liquids (NGL's) at Gas Pressure Reduction Stations.
FIELD OF THE INVENTION
The present invention relates to a method of producing NGL's at gas Pressure Reduction Stations when the pressure is letdown from gas main transmission lines to local gas distribution lines.
BACKGROUND OF THE INVENTION
In gas Pressure Reduction Stations, the gas is pre-heated before the pressure is dropped to prevent the formation of hydrates which can cause damage to the pipeline and associated equipment. The typical pressure reduction varies between 400 to 900 PSIG
(pounds per square inch gage) for main transmission gas lines to local distribution lines and from 50 to 95 PSIG from local distribution lines to consumers. When gas is depressurised the temperature drops. The rule of thumb is that for every 100 pounds of pressure drop across a pressure reducing valve the gas temperature will drop by 7 F. When the pressure is reduced by the use of an expander, the temperature drop is greater because it produces work. The heat required to prevent formation of hydrates is normally provided by hot water boilers, gas fired line heaters or waste heat from; gas turbines, gas engines or fuel cells. In some stations, due to its large volumetric flows and pressure drops, energy can be and is recovered, by a combination of gas expander and boiler. For a more efficient recovery, combinations of gas expanders with CHP processes (Combined Heat and Power) or CCHP (Combined Cooling Heat and Power) processes are possible. The limitation in these applications are the economics which are driven by flow volumes, pressure delta, seasonal volumetric flows and 24 hour volumetric flows. Because of so many variables that impact on the economics of adding a gas expander be it with: a boiler, CHP or CCHP the current gas pipeline operators choose to pre-heat the gas by the use of boilers and or heaters. In all of the above practices, there is no attempt made to recover NGL's present in the natural gas stream at Metering and Pressure Reduction Stations. The typical practice is to have large facilities upstream in the transmission line known as Straddle Plants which recover a percentage of the NGL's for feedstock to the petrochemical industry.
Method to produce Natural Gas Liquids (NGL's) at Gas Pressure Reduction Stations.
FIELD OF THE INVENTION
The present invention relates to a method of producing NGL's at gas Pressure Reduction Stations when the pressure is letdown from gas main transmission lines to local gas distribution lines.
BACKGROUND OF THE INVENTION
In gas Pressure Reduction Stations, the gas is pre-heated before the pressure is dropped to prevent the formation of hydrates which can cause damage to the pipeline and associated equipment. The typical pressure reduction varies between 400 to 900 PSIG
(pounds per square inch gage) for main transmission gas lines to local distribution lines and from 50 to 95 PSIG from local distribution lines to consumers. When gas is depressurised the temperature drops. The rule of thumb is that for every 100 pounds of pressure drop across a pressure reducing valve the gas temperature will drop by 7 F. When the pressure is reduced by the use of an expander, the temperature drop is greater because it produces work. The heat required to prevent formation of hydrates is normally provided by hot water boilers, gas fired line heaters or waste heat from; gas turbines, gas engines or fuel cells. In some stations, due to its large volumetric flows and pressure drops, energy can be and is recovered, by a combination of gas expander and boiler. For a more efficient recovery, combinations of gas expanders with CHP processes (Combined Heat and Power) or CCHP (Combined Cooling Heat and Power) processes are possible. The limitation in these applications are the economics which are driven by flow volumes, pressure delta, seasonal volumetric flows and 24 hour volumetric flows. Because of so many variables that impact on the economics of adding a gas expander be it with: a boiler, CHP or CCHP the current gas pipeline operators choose to pre-heat the gas by the use of boilers and or heaters. In all of the above practices, there is no attempt made to recover NGL's present in the natural gas stream at Metering and Pressure Reduction Stations. The typical practice is to have large facilities upstream in the transmission line known as Straddle Plants which recover a percentage of the NGL's for feedstock to the petrochemical industry.
SUMMARY OF THE INVENTION
According to the present invention there is provided a method to remove water present in the gas stream, produce NGL's and then pre-heat the gas to meet pipeline specifications. This method recovers NGL's, removes water and eliminates the present practice of using natural gas as a fuel for; boilers, heaters, gas turbines, gas engines or fuel cells to pre-heat the natural gas before pressure reduction. Moreover, the present invention provides the ability to recover most of the energy available for recovery at pressure reduction stations. A first step has at least one heat exchanger, with a first flow path for passage of incoming high pressure gas that indirectly exchanges heat with a counter current lower pressure cold gas stream. The low pressure cold gas stream flow can be controlled to meet desired temperatures in the high pressure gas stream through the use of a by-pass around the heat exchanger. The now cold high pressure gas enters a vessel separator, where water is removed. A second step involves passing the high pressure cold and water free gas stream through a gas expander, dropping the pressure to local distribution pipeline spec generating shaft work and a further drop in temperature. The shaft rotates a power generator producing electricity and the lower pressure colder gas enters a separator where NGL's are recovered.
The objective being to control the temperature upstream of the gas expander to meet the desired NGL's recovery. The third step involves the use of the generated electricity as an heat source to the heat exchanger that controls the gas supply temperature to the local distribution pipeline. This eliminates the existing practice of combusting natural gas to pre-heat the gas to prevent the formation of hydrates. The fourth step involves the use of air exchangers to release part or all of the cold energy to the surroundings, this provides the ability to export electricity at warm atmospheric conditions.
BRIEF DESCRIPTION OF THE DRAWINGS
These and other features of the invention will become more apparent from the following description in which reference is made to the appended drawings, the drawings are for the purpose of illustration only and are not intended to in any way limit the scope of the invention to the particular embodiment or embodiments shown, wherein:
FIG. 1 is a schematic diagram of a typical method to pre-heat gas at gas Pressure Reduction Stations (PRS) in the prior art.
FIG. 2 is a schematic diagram that depicts the embodiment of the invention.
FIG. 3 is a variation on the embodiment of the invention.
FIG. 4 is another variation on the embodiment of the invention.
FIG. 5 is another variation of the embodiment of the invention to liquefy gases.
DETAILED DESCRIPTIONS OF A TYPYCAL PRS AND THE PREFERRED
EMBODIMENT
The typical method that presently is used to pre-heat natural gas at Pressure Reduction Stations will now be described with reference to FIG. 1.
In this typical gas pre-heating process, gas enters a station via gas supply line 1.
The gas stream enters filter 20 to remove any debris in the stream. The filtered gas exits the filter through line 2 and enters heat exchanger 21 for pre-heating. The heated gas exits through line 3 and the pressure is reduced at Pressure Reducing Valve (PRV) 22. A by-pass with PRV 23 is provided for service reliability, for scheduled and unscheduled maintenance. The PRV pressure is controlled by Pressure Transmitter (PT) 27 at a pre-set pressure. The low pressure controlled gas stream 4 feeds a gas slipstream 5 for combustion in a heater/boiler 24. The gas slipstream flow 5 is controlled by Temperature Controller (TC) 26 at a pre-set temperature. The gas stream 6 is metered at Flow Meter (FM) 25 and delivered to consumers.
The preferred embodiment will now be described with reference to FIG. 2. In the preferred embodiment, the gas enters a station through supply line 1. The high pressure gas stream enters filter 50 to remove any debris in the stream. The filtered gas exits filter 50 through gas line 2 and passes through heater exchanger 51. At heater exchanger 51 the high pressure gas is cooled by the counter current depressurized gas stream to condense any water present in the high pressure gas stream. The cooled high pressure gas stream in line 5 is discharged into separator 52. The water exits through line 7 and the dried gas exits through line 6. The high pressure gas is routed through line 9 to gas expander 54, producing shaft work and a drop in gas temperature. The shaft rotates power generator 55, producing electricity. The produced electricity is carried by electrical wires 23 to electrical heater 58. A by pass JT valve 53, supplied by line 8 is provided for startup and emergency services.
The low pressure cold gas in line 10 flows into separator 56 where NGL's are separated and recovered. The NGL's exit through line 11. The lean cold gas exits the separator through line 12 and can be routed through line 13 and line 15 to meet desired operations temperatures. The lean gas stream in line 13 enters an air exchanger 57 where the cold energy is dissipated into the atmosphere by natural draft, the amount of cold energy dissipated to the atmosphere is dependent on the choice and objectives of the local plant. The lean stream exits air exchanger 57 through line 14 at near atmospheric temperatures. The warmer lean gas stream 14 can be blended through line 16 or line 18 to meet desired operations temperatures. The lean and cold gas stream in line 15 can be sent directly or blended with stream 16 and sent to heat exchanger 51 to cool in a counter current flow the incoming high pressure rich gas stream. The lean depressurized gas exits heat exchanger 51 through line 19 and blends with stream 18 into stream 20.
The blended stream 20 enters line 4 and is routed to heater 58 to increase the lean gas temperature to local distribution pipeline specifications. The heat is supplied by the power generator 55 and transmitted through electrical wires 23 to the heating elements in heater 58. The heated lean gas in line 21 is measured in meter 59. A temperature controller 60 controls the heat supplied to heater 58. A pressure controller 61 controls the pressure to the local distribution pipeline 22.
A variation is depicted in FIG. 3, which shows stream 6 passing through a JT
valve rather than through a gas expander as shown in FIG. 2. There is no power generation and no air/heat exchangers just NGL's recovery. Moreover, the cold temperatures generated by dropping the pressure through a JT valve will not be as cold as through the expander since no work is done.
A further variation is depicted in FIG. 4, which shows stream 3 going straight into separator 51, no pre-cooling heat exchange upstream of this separator as in FIG. 2 and FIG.
3. The NGL's are recovered and separated in vessel 55 and removed through line 9. The lean gas flow 10 is pre-heated in a atmospheric air/heat exchanger.
A further variation is depicted in FIG. 5, which shows the pre-heating exchanger 56 being through a waste heat stream 14. This stream could be hot water, steam, flue gases, etc.
According to the present invention there is provided a method to remove water present in the gas stream, produce NGL's and then pre-heat the gas to meet pipeline specifications. This method recovers NGL's, removes water and eliminates the present practice of using natural gas as a fuel for; boilers, heaters, gas turbines, gas engines or fuel cells to pre-heat the natural gas before pressure reduction. Moreover, the present invention provides the ability to recover most of the energy available for recovery at pressure reduction stations. A first step has at least one heat exchanger, with a first flow path for passage of incoming high pressure gas that indirectly exchanges heat with a counter current lower pressure cold gas stream. The low pressure cold gas stream flow can be controlled to meet desired temperatures in the high pressure gas stream through the use of a by-pass around the heat exchanger. The now cold high pressure gas enters a vessel separator, where water is removed. A second step involves passing the high pressure cold and water free gas stream through a gas expander, dropping the pressure to local distribution pipeline spec generating shaft work and a further drop in temperature. The shaft rotates a power generator producing electricity and the lower pressure colder gas enters a separator where NGL's are recovered.
The objective being to control the temperature upstream of the gas expander to meet the desired NGL's recovery. The third step involves the use of the generated electricity as an heat source to the heat exchanger that controls the gas supply temperature to the local distribution pipeline. This eliminates the existing practice of combusting natural gas to pre-heat the gas to prevent the formation of hydrates. The fourth step involves the use of air exchangers to release part or all of the cold energy to the surroundings, this provides the ability to export electricity at warm atmospheric conditions.
BRIEF DESCRIPTION OF THE DRAWINGS
These and other features of the invention will become more apparent from the following description in which reference is made to the appended drawings, the drawings are for the purpose of illustration only and are not intended to in any way limit the scope of the invention to the particular embodiment or embodiments shown, wherein:
FIG. 1 is a schematic diagram of a typical method to pre-heat gas at gas Pressure Reduction Stations (PRS) in the prior art.
FIG. 2 is a schematic diagram that depicts the embodiment of the invention.
FIG. 3 is a variation on the embodiment of the invention.
FIG. 4 is another variation on the embodiment of the invention.
FIG. 5 is another variation of the embodiment of the invention to liquefy gases.
DETAILED DESCRIPTIONS OF A TYPYCAL PRS AND THE PREFERRED
EMBODIMENT
The typical method that presently is used to pre-heat natural gas at Pressure Reduction Stations will now be described with reference to FIG. 1.
In this typical gas pre-heating process, gas enters a station via gas supply line 1.
The gas stream enters filter 20 to remove any debris in the stream. The filtered gas exits the filter through line 2 and enters heat exchanger 21 for pre-heating. The heated gas exits through line 3 and the pressure is reduced at Pressure Reducing Valve (PRV) 22. A by-pass with PRV 23 is provided for service reliability, for scheduled and unscheduled maintenance. The PRV pressure is controlled by Pressure Transmitter (PT) 27 at a pre-set pressure. The low pressure controlled gas stream 4 feeds a gas slipstream 5 for combustion in a heater/boiler 24. The gas slipstream flow 5 is controlled by Temperature Controller (TC) 26 at a pre-set temperature. The gas stream 6 is metered at Flow Meter (FM) 25 and delivered to consumers.
The preferred embodiment will now be described with reference to FIG. 2. In the preferred embodiment, the gas enters a station through supply line 1. The high pressure gas stream enters filter 50 to remove any debris in the stream. The filtered gas exits filter 50 through gas line 2 and passes through heater exchanger 51. At heater exchanger 51 the high pressure gas is cooled by the counter current depressurized gas stream to condense any water present in the high pressure gas stream. The cooled high pressure gas stream in line 5 is discharged into separator 52. The water exits through line 7 and the dried gas exits through line 6. The high pressure gas is routed through line 9 to gas expander 54, producing shaft work and a drop in gas temperature. The shaft rotates power generator 55, producing electricity. The produced electricity is carried by electrical wires 23 to electrical heater 58. A by pass JT valve 53, supplied by line 8 is provided for startup and emergency services.
The low pressure cold gas in line 10 flows into separator 56 where NGL's are separated and recovered. The NGL's exit through line 11. The lean cold gas exits the separator through line 12 and can be routed through line 13 and line 15 to meet desired operations temperatures. The lean gas stream in line 13 enters an air exchanger 57 where the cold energy is dissipated into the atmosphere by natural draft, the amount of cold energy dissipated to the atmosphere is dependent on the choice and objectives of the local plant. The lean stream exits air exchanger 57 through line 14 at near atmospheric temperatures. The warmer lean gas stream 14 can be blended through line 16 or line 18 to meet desired operations temperatures. The lean and cold gas stream in line 15 can be sent directly or blended with stream 16 and sent to heat exchanger 51 to cool in a counter current flow the incoming high pressure rich gas stream. The lean depressurized gas exits heat exchanger 51 through line 19 and blends with stream 18 into stream 20.
The blended stream 20 enters line 4 and is routed to heater 58 to increase the lean gas temperature to local distribution pipeline specifications. The heat is supplied by the power generator 55 and transmitted through electrical wires 23 to the heating elements in heater 58. The heated lean gas in line 21 is measured in meter 59. A temperature controller 60 controls the heat supplied to heater 58. A pressure controller 61 controls the pressure to the local distribution pipeline 22.
A variation is depicted in FIG. 3, which shows stream 6 passing through a JT
valve rather than through a gas expander as shown in FIG. 2. There is no power generation and no air/heat exchangers just NGL's recovery. Moreover, the cold temperatures generated by dropping the pressure through a JT valve will not be as cold as through the expander since no work is done.
A further variation is depicted in FIG. 4, which shows stream 3 going straight into separator 51, no pre-cooling heat exchange upstream of this separator as in FIG. 2 and FIG.
3. The NGL's are recovered and separated in vessel 55 and removed through line 9. The lean gas flow 10 is pre-heated in a atmospheric air/heat exchanger.
A further variation is depicted in FIG. 5, which shows the pre-heating exchanger 56 being through a waste heat stream 14. This stream could be hot water, steam, flue gases, etc.
5 The preferred embodiment in FIG. 2 has the advantage over the present practice in that it substantially reduces and or eliminates the use of a gas slipstream to pre-heat the gas prior to de-pressurization and recovers NGL's, a feedstock to the petrochemical industry. This is significant when one considers that it can replace existing PRV's (known in the industry as JT valves) and line heaters. Associated with it is the reduction or elimination of emissions presently generated in these line heaters. Moreover, the energy used to replace the slipstream gas is recovered energy (no new emissions generated) which presently is dissipated across a PRV.
Claims (6)
1. A method to recover natural gas liquids (NGL's) at pressure reduction stations, comprising the steps of:
providing at least one heat exchanger, each heat exchanger having a flow path for passage of a high pressure natural gas stream and a counter current passage for a depressurised cold lean gas stream;
passing the high pressure natural gas stream along the heat exchanger in order to cool the high pressure natural gas stream through a heat exchange with the depressurized cold lean gas stream before pressure reduction, such that hydrates are condensed out of the high pressure natural gas stream;
removing hydrates from the high pressure natural gas stream;
passing the high pressure natural gas stream, which has had hydrates removed, through a gas expander to reduce pressure of the natural gas stream;
passing the natural gas stream, which has been reduced in pressure through a separator to produce a first stream of depressurized cold lean natural gas and a second stream of NGL's.
providing at least one heat exchanger, each heat exchanger having a flow path for passage of a high pressure natural gas stream and a counter current passage for a depressurised cold lean gas stream;
passing the high pressure natural gas stream along the heat exchanger in order to cool the high pressure natural gas stream through a heat exchange with the depressurized cold lean gas stream before pressure reduction, such that hydrates are condensed out of the high pressure natural gas stream;
removing hydrates from the high pressure natural gas stream;
passing the high pressure natural gas stream, which has had hydrates removed, through a gas expander to reduce pressure of the natural gas stream;
passing the natural gas stream, which has been reduced in pressure through a separator to produce a first stream of depressurized cold lean natural gas and a second stream of NGL's.
2. The method of Claim 1, including a step of heating a portion of the first stream and then blending selected quantities of the heated portion of the first stream with selected quantities of an unheated portion of the first stream.
3. The method of Claim 1, including a step of heating at least a portion of the first stream by passing the portion of the first stream through a heat exchanger.
4. The method of Claim 3, including a step of heating at least a portion of the first stream by passing the portion of the first stream through a heat exchanger to effect a heat exchange with ambient outdoor air.
5. The method of Claim 3, including a step of heating at least a portion of the first stream by passing the portion of the first stream through a heat exchanger having a counter current waste heat stream.
6. The method of Claim 1, including a step of connecting the gas expander to a power generator and using the power generated to run heaters and heating at least a portion of the first stream with the heaters.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2588664A CA2588664C (en) | 2007-05-09 | 2007-05-09 | Method to produce natural gas liquids (ngl's) at gas pressure reduction stations |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2588664A CA2588664C (en) | 2007-05-09 | 2007-05-09 | Method to produce natural gas liquids (ngl's) at gas pressure reduction stations |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2588664A1 CA2588664A1 (en) | 2008-11-09 |
| CA2588664C true CA2588664C (en) | 2011-08-16 |
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2588664A Active CA2588664C (en) | 2007-05-09 | 2007-05-09 | Method to produce natural gas liquids (ngl's) at gas pressure reduction stations |
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| CN104632128B (en) * | 2014-12-31 | 2018-03-13 | 西南石油大学 | The anti-frozen block system of gas condensate field high pressure flowline |
| CN106281523A (en) * | 2016-07-25 | 2017-01-04 | 北京建筑大学 | Skid-mounted type diffuses retracting device and the method for natural gas |
| CN109054915B (en) * | 2018-07-10 | 2020-10-30 | 中石化石油工程技术服务有限公司 | Natural gas dehydration system and method for throttling pre-dehydration and entrainer regeneration |
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| Publication number | Publication date |
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| CA2588664A1 (en) | 2008-11-09 |
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