System and method for liquefying production gas from a gas source

Abstract

A method for liquefying production gas from a gas source containing a fluid having C1-C12 entrained gases includes passing the gas through a first stage of cryogenic liquefaction to cool the gas to a temperature between −50 degrees Celsius and −87 degrees Celsius to create a fluid containing a liquefied C3-C12 petroleum gas and a gaseous C1-C2 natural gas. The liquefied C3-C12 petroleum gas and gaseous C1-C2 natural gas are passed through a second phase separator to separate the liquefied C3-C12 petroleum gas from the gaseous C1-C2 natural gas. The liquefied C3-C12 petroleum gas is collected into liquefied petroleum gas storage vessels.

Claims

1. A method for liquefying production gas from a gas source, comprising the steps of: introducing a flow stream from the gas source into a first phase separator to separate C1-C12 production gases from the flow stream; passing the gas through a first stage of cryogenic liquefaction, the first stage of cryogenic liquefaction cooling the gas to create a fluid containing liquefied C3-C12 petroleum gas and a gaseous C1-C2 natural gas; passing the fluid containing liquefied C3-C12 petroleum gas and the gaseous C1-C2 natural gas through a second phase separator to separate the liquefied C3-C12 petroleum gas from the gaseous C1-C2 natural gas; collecting the liquefied C3-C12 petroleum gas into at least one liquefied petroleum gas storage vessel.

2. The method of claim 1, further comprising the steps of passing the gaseous C1-C2 natural gas through a second stage of cryogenic liquefaction for liquefying the gaseous C1-C2 natural gas and collecting the liquefied C1-C2 natural gas into at least one C1-C2 liquefied natural gas storage vessel.

3. The method of claim 2, wherein the second stage of cryogenic liquefaction cools the gaseous C1-C2 natural gas to at least −162 degrees Celsius.

4. The method of claim 2 wherein the second stage of cryogenic liquefaction occurs in a second plate exchanger.

5. The method of claim 2 wherein the at least one C1-C2 natural gas storage vessel is depressurized when the Reid vapor pressure reaches a predetermined level and C1-C2 natural gas is re-introduced to the second stage of cryogenic liquefaction.

6. The method of claim 2 wherein the at least one C1-C2 natural gas storage vessel is depressurized when the Reid vapor pressure reaches a predetermined level and the C1 and C2 are re-introduced to the first stage of cryogenic liquefaction.

7. The method of claim 2 wherein the at least one C3-C12 natural gas storage vessel is depressurized when the Reid vapor pressure reaches a predetermined level and the C3-C12 petroleum gas is re-introduced to the first stage of cryogenic liquefaction.

8. The method of claim 1 further comprising the step of passing the flow stream from the gas source into a sand catcher before injecting the flow stream into the first phase separator.

9. The method of claim 1 further comprising the use of a booster between the gas source and the first phase separator.

10. The method of claim 1 wherein liquid nitrogen is used during the cryogenic liquefaction.

11. The method of claim 1 wherein glycol that has been cooled by liquid nitrogen is used during the cryogenic liquefaction.

12. The method of claim 1 wherein the first stage of cryogenic liquefaction occurs in a first plate exchanger.

13. The method of claim 1 wherein a scavenger is injected into the flow stream prior to the fluid passing through the inlet of the first phase separator.

14. The method of claim 1 wherein a scavenger is injected into the flow stream prior to the fluid passing through the inlet of the second phase separator.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

(1) These and other features will become more apparent from the following description in which references are made to the following drawings, in which numerical references denote like parts. 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 embodiments shown.

(2) FIG. 1 is a schematic view of a system for liquefying production gas from a gas source.

(3) FIG. 2 is a schematic view of a variation of the system for liquefying production gas from a gas source.

(4) FIG. 3 is a schematic view of a variation of the system for liquefying production gas from a gas source.

(5) FIG. 4 is a schematic view of a variation of a system for liquefying production gas from a gas source.

(6) FIG. 5 is a detailed schematic view of a portion of a system for liquefying production gas from a gas source.

(7) FIG. 6 is a schematic view of a variation of a system for liquefying production gas from a gas source.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

(8) A system for liquefying production gas from a flow stream contained in a gas source containing that has C1-C12 entrained gases, generally identified by reference numeral 10, will now be described with reference to FIG. 1 through FIG. 3 and FIG. 5 through 6.

(9) Referring to FIG. 1-FIG. 4. C1-C12 production gases are found in many different sources including fluids from wellheads, pipelines and frac fluids. C1-C12 production gases can be separated out of the flow stream contained in gas sources 12. Gas source 12 may be a wellhead, a pipeline or other source from which C1-C12 gases or some of C1-C12 gases may be separated. A 3-phase separator 14 is used to separate the flow stream into water, oil and gas. 3-phase separator 14 has an inlet 16 in fluid communication with gas source 12. 3-phase separator 14 has a water outlet 18, an oil outlet 20 and a gas outlet 22. Water and oil can be transferred to water tanks 24 and oil tanks 26, respectively, while gases are transferred through gas outlet 22 and into a first cryogenic liquefaction vessel 28. The gases that are separated in the 3-phase separator 14 includes C1-C12 production gases. First cryogenic liquefaction vessel 28 has an inlet 30 which is in fluid communication with gas outlet 22 of 3-phase separator and an outlet 32. First cryogenic liquefaction vessel 28 cools the C1-C12 gases to liquefy the C3-C12 petroleum gases and create a fluid containing liquefied C3-C12 petroleum gas and a gaseous C1-C2 natural gas. First cryogenic liquefaction vessel 28 is preferably a plate exchanger, however a person of skill will understand that different types of heat exchangers may be used. Different types of heat exchanges that may be used include, but are not limited to, shell and tube heat exchangers, baffle type heat exchangers, segmental baffles, double segmental baffles, no-tube-in-window baffles, rod baffles, EM baffles, helical baffles, tube enhancements, twisted tubes, low finned tubes, tubes inserts, compact type heat exchangers and plate and frame heat exchangers. In order for the C3-C12 petroleum gases to be liquefied and the C1-C2 gases to remain in gaseous form, the gas in first cryogenic liquefaction vessel is cooled to between −50 and −87 degrees Celsius. The fluid containing liquefied C3-C12 petroleum gas and a gaseous C1-C2 natural gas is passed through a second phase separator 34. In the embodiment shown, second phase separator is a 2-phase separator 34, however it will be understood by a person skilled in the art that a 3-phase separator could also be used. The use of a 3-phase separator would allow for the removal of methanol, water and scavenger that may be introduced to the fluid prior to the fluid passing through second phase separator 34. 2-phase separator 34 has an inlet 36 in fluid communication with outlet 32 of first cryogenic liquefaction vessel 28, a liquid outlet 38 and a gas outlet 40. 2-phase separator 34 separates the C3-C12 liquefied gases from the C1-C2 gases. Storage vessels 42 are provided in fluid communication with liquid outlet 38 of 2-phase separator 34 for the collection of the liquefied C3-C12 petroleum gases.

(10) After the liquefied C3-C12 petroleum gases have been collected, there are several different options that may be utilized in relation to the C1-C2 natural gases. Referring to FIG. 1, gas outlet 40 of 2-phase separator 34 may be in fluid communication with a pipeline 41 to send the gaseous C1-C2 natural gases into a pipeline system. Referring to FIG. 2, in one alternative, gas outlet 40 of 2-phase separator 34 is in fluid communication with a flare stack 66 where the C1-C2 natural gases are burnt off.

(11) Referring to FIG. 3, in the embodiment shown, a second cryogenic liquefaction vessel 44 is provided for liquefying the C1-C2 gases. Second cryogenic liquefaction vessel 44 has an inlet 46 and an outlet 48 with inlet 46 in fluid communication with gas outlet 40 of 2-phase separator 34. Storage vessels 50 for the collection of liquefied C1-C2 gases are provided in fluid communication with outlet 48 of second cryogenic liquefaction vessel 44. In order for the C1-C2 gases to be liquefied, second liquefaction vessel 44 needs to be cooled to at least −162 degrees Celsius. Second cryogenic liquefaction vessel 44 is preferably a plate exchanger, however a person of skill will understand that different types of heat exchangers may be used. Different types of heat exchanges that may be used include, but are not limited to, shell and tube heat exchangers, baffle type heat exchangers, segmental baffles, double segmental baffles, no-tube-in-window baffles, rod baffles, EM baffles, helical baffles, tube enhancements, twisted tubes, low finned tubes, tubes inserts, compact type heat exchangers and plate and frame heat exchangers. Paraffin cutters and methanol may be injected upstream of first cryogenic liquefaction vessel 28 and/or second cryogenic liquefaction vessel 44 to maintain efficient flow through system 10. It will be understood that paraffin cutters and methanol may be injected at other locations within system 10.

(12) Other types of equipment may be included within system 10. This includes a sand catcher 52 which is positioned between gas source 12 and 3-phase separator 14. Sand catcher 52 has an inlet 54 in fluid communication with gas source 12, a fluid outlet 56 in fluid communication with inlet 16 of 3-phase separator 14 and a sand outlet 58. Sand catcher 52 is used to capture sediments that travel with fluid as it exits gas source 12. A blow down line 60 is connected to sand outlet 58 which attaches to a sand storage vessel 62. Sand storage vessel 62 may have a pressure relief line 64 for safety that is connected to a flare stack 66. Where sour gas is a concern, a scavenger may be injected to minimize entrained the sour gas when fluid travels through sand catcher 52. When sand catcher 52 is not used, scavenger may be injected prior to fluid entering 3-phase separator 14. A booster, not shown, may be connected to gas source 12 to increase the volume of fluid that can be drawn out of gas source 12 and sent through system 10. The booster may be a pump which generally increases the pressure of the flow stream from gas source 12. Generally a simpler mechanism which has a single stage of compression may be used and increases the pressure of an already pressurized gas. A two stage booster may also be used. Boosters are beneficial for increasing gas pressure, transferring high pressure gas and charging gas cylinders. Where the flow stream from gas source 12 is primarily gaseous, a compressor may be used to increase the pressure of the gas. A person of skill will understand what types of boosters may be used depending upon the type of gas source being used.

(13) For safety, a first pressure relief line 68 may be provided between 3-phase separator 14 and first cryogenic liquefaction vessel 28. First pressure relief line 68 provides for a means of quickly relieving pressure that may build up when gas exits gas outlet 22 of 3-phase separator 14 before entering inlet 30 of first cryogenic liquefaction vessel 28. First pressure relief line 68 prevents over pressurization of first cryogenic liquefaction vessel 28 in the event of increased gas rates due to well slugging. First pressure relief line 68 is provided in fluid communication with a flare stack 66. A second pressure relief line 70 may be provided on 2-phase separator 34. Second pressure relief line 70 is provided in fluid communication with a flare stack 66. Another pressure relief line 72 may be provided on 3-phase separator 14. A person of skill will understand that sand storage pressure relief line 64, first pressure relief line 68, second pressure relief line 70 and 3-phase separator pressure relief line 72 may be in fluid communication with the same flare stack 66, different flare stacks 66 or multiple flare stacks 66. A number of LNG and LPG storage vessel relief lines 73 are provided on storage vessels 42 and 50 that vent to flare stacks 66 for safety purposes.

(14) First cryogenic liquefaction vessel 28 and second cryogenic liquefaction vessel 44 are preferably cooled using liquid nitrogen. Referring to FIG. 1 and FIG. 2, a nitrogen source 74 such as a liquid nitrogen tank or a nitrogen generator is provided and a nitrogen loop is created through first cryogenic liquefaction vessel 28. Nitrogen is pumped through nitrogen loop using a pump, not shown. Nitrogen travels out of nitrogen source 74 through outlet 76 and into first cryogenic liquefaction vessel 28 through nitrogen inlet 78. The nitrogen cools gases flowing through first cryogenic liquefaction vessel 28 and flows out through nitrogen outlet 80. The nitrogen continues to flow around a nitrogen loop 82 back to nitrogen source 74. Nitrogen source 74 has a nitrogen vent 84 to vent the used nitrogen to the atmosphere. Referring to FIG. 3 and FIG. 4, when second cryogenic liquefaction vessel 44 is included in system 10, nitrogen travels out of nitrogen source 74 through outlet 76 which is split into two inlet lines 86 and 88. Each of inlet lines 86 and 88 are provided with valves 90 to control the flow to first cryogenic liquefaction vessel 28 and second cryogenic liquefaction vessel 44, respectively. A flow line 92 splits off of inlet lines 86 and 88 which connects to nitrogen loop 82 and acts as a pressure relief when necessary with valve 90 being used to control the flow of nitrogen through flow line 92 to nitrogen loop 82. Inlet line 86 is connected to nitrogen inlet 78 of first cryogenic liquefaction vessel 28 and inlet line 88 connects to a nitrogen inlet 94 of second cryogenic liquefaction vessel 44. The nitrogen cools gases flowing through second cryogenic liquefaction vessel 44 and flows out through nitrogen outlet 96. Nitrogen outlet 96 is in fluid communication with nitrogen loop 82 which loops the nitrogen back to nitrogen source 74.

(15) A person of skill will understand that different mediums may be used to cool first cryogenic liquefaction vessel 28 and second cryogenic liquefaction vessel 44. Different types of fluid loops may be used depending upon the method of cooling that is used. It may be beneficial in some instances to use glycol cooled using liquid nitrogen as opposed to liquid nitrogen itself where conditions may cause the nitrogen to be reactive within first cryogenic liquefaction vessel 28 and/or second cryogenic liquefaction vessel 44. Cooling and condensing may also be accomplished by heat exchange with several refrigerant fluids that have successively lower boiling points known as a cascade system. In the alternative, a single refrigerant may be used at several different pressures to provide several temperature levels. A multi-component system which contains several refrigerant components may also be used. A typical combination of refrigerants often includes propane, ethylene and methane. A person of skill will understand that other methods of cooling and condensing may also be used.

(16) Referring to FIG. 5, when C1 and C2 liquefied natural gas is stored within storage vessels 50, gaseous C1 and C2 can be produced as it settles out of the liquefied natural gas. When the Reid vapor pressure (RVP) within storage vessels 50 reaches a predetermined level, storage vessels 50 are depressurized and the C1 and C2 is sent back to inlet 46 and through second cryogenic liquefaction vessel 44 to be reliquefied. C1 and C2 travels through return line 98 from storage vessels 50 to inlet 46 of second cryogenic liquefaction vessel 44. This portion of system 10 is used for RVP stabilization and eliminates the need to flare off or otherwise contain the C1 and C2 gas that can form within storage vessels 50. The Reid vapor pressure at which storage vessels 50 are depressurized may be determined by the user of system 10. One determining factor in determining the level of RVP that depressurization occurs includes spec property quality. If the methane and ethane gas content is too high, it cannot be transported. The methane and ethane gas can be released to lower the RVP within storage vessels 50. Another factor may be determined by end user quality specifications. Different specifications are required for burner tip applications versus combustion requirements.

(17) Referring to FIG. 6, when the Reid vapor pressure (RVP) within storage vessels 50 reaches a predetermined level, storage vessels 50 are depressurized and the C1 and C2 is sent back to inlet 30 and through first cryogenic liquefaction vessel 28 to be reliquefied. C1 and C2 travels through return line 98 and return line 99 from storage vessels 50 to inlet 30 of first cryogenic liquefaction vessel 28. One potential reason for sending the C1 and C2 through first cryogenic liquefaction vessel 28 is to drop the temperature of gases entering first cryogenic liquefaction vessel 28 which may result in reduced power consumption required during the liquefaction process. In the embodiment shown, return line 98 and return line 99 are provided in fluid communication with each other and flow is determined through the use of valves 90. A person of skill will understand that separate return lines may be provided to send the C1 and C2 to the second cryogenic storage vessel 44 and the first cryogenic storage vessel 28.

(18) When the Reid vapor pressure within storage vessels 42 reaches a predetermined level, storage vessels 42 are depressurized and the C3-C12 is sent back to inlet 30 and through first cryogenic liquefaction vessel 28 to be reliquefied. C3-C12 travels through return line 98 and return line 99 from storage vessels 42 to inlet 30 of first cryogenic liquefaction vessel 28. In the embodiment shown, return line 98 and return line 99 are provided in fluid communication with each other and flow is determined through the use of valves 90. A person of skill will understand that a separate return line may be provided for sending C3-C12 back to first cryogenic liquefaction vessel 28.

(19) By reintroducing the gases from C1-C2 storage tanks 50 and C3-C12 storage tanks 42 into second cryogenic liquefaction vessel 44 and first cryogenic liquefaction vessel 28, the products can be further purified to prevent contamination through entrainment or turbidity that occurs during the process. This works as a “second pass” cleaning. If issues related to high water content occur, gases can be reintroduced downstream of first cryogenic liquefaction vessel 28 and prior to second cryogenic liquefaction vessel 50 to prevent fouling of hydrates caused by the inflow of cold RVP gases re-entering the system.

(20) A boost pump, not shown, may be required to overcome inlet pressures when reintroducing gases into first cryogenic liquefaction vessel 28 and second cryogenic liquefaction vessel 44 from storage tanks 50 and 42.

(21) A variation of the system for liquefying production gas from a gas source containing a flow stream with C1-C12 entrained gases, generally identified by reference numeral 100, will be described with reference to FIG. 4.

(22) A gas source 112 that contains a flow stream with C1-C12 entrained gases is provided in fluid communication with a first phase separator 114. Gas source 12 may be a wellhead, a pipeline or other source from which C1-C12 gases or some of C1-C12 gases may be separated. In the embodiment shown, first phase separator 114 is a 2-phase separator which has an inlet 116 in fluid communication with gas source 112, a gas outlet 122 and a single alternative outlet 120 for fluid. A person of skill will understand that first phase separator 114 could be a 3-phase separator which separates the fluid from gas source 112 into gas, water and oil. When a 3-phase separator is used, two alternative outlets would be provided, one being a water outlet and the second being an oil outlet. The use of a 3-phase separator is shown in FIG. 1-FIG. 3. Referring to FIG. 4, fluid traveling through alternative outlet 120 may be stored or treated further. Gases from first phase separator 114 are transferred through gas outlet 122 and into a first cryogenic liquefaction vessel 128. First cryogenic liquefaction vessel 128 has an inlet 130 which is in fluid communication with gas outlet 122 of first phase separator and an outlet 132. First cryogenic liquefaction vessel 128 cools the C1-C12 gases to liquefy the C3-C12 petroleum gases and create a fluid containing liquefied C3-C12 petroleum gas and a gaseous C1-C2 natural gas. First cryogenic liquefaction vessel 128 is preferably a plate exchanger, however a person of skill will understand that different types of heat exchangers may be used. In order for the C3-C12 petroleum gases to be liquefied and the C1-C2 gases to remain in gaseous form, the gas in first cryogenic liquefaction vessel 128 is cooled to between −42 and −126 degrees Celsius. The fluid containing liquefied C3-C12 petroleum gas and a gaseous C1-C2 natural gas is passed through a second phase separator 134. In the embodiment shown, second phase separator 134 is a 2-phase separator and has an inlet 136 in fluid communication with outlet 132 of first cryogenic liquefaction vessel 128, a liquid outlet 138 and a gas outlet 140. 2-phase separator 134 separates the C3-C12 liquefied gases from the C1-C2 gases. Storage vessels 142 are provided in fluid communication with liquid outlet 138 of 2-phase separator 134 for the collection of the liquefied C3-C12 petroleum gases. A person of skill will understand that second phase separator 134 may be a 3-phase separator, however at this point in system 100 minimal water can be separated out of fluid.

(23) Fluid traveling through alternative outlet 120 may be passed through a 3-phase separator 200 to separate gas, water and oil. 3-phase separator has an inlet 210 in fluid communication with alternative outlet 120 of first phase separator 128. 3-phase separator 200 has a gas outlet 212, a water outlet 214 and an oil outlet 216. Gas outlet 212 is in fluid communication with a pressure relief line 218 which may direct gas to a flare 66, a pipeline or to first cryogenic liquefaction vessel 128. Since the majority of gas will have been separated out in first phase separator 114, minimal gas should be separated using 3-phase separator 200. Water outlet 214 and oil outlet 216 are provided in fluid communication water tanks 24 and oil tanks 26, respectively.

(24) After the liquefied C3-C12 petroleum gases have been collected, there are several different options that may be made in relation to the C1-C2 natural gases. Gas outlet 140 of second phase separator 134 may be in fluid communication with a pipeline 41, as shown in FIG. 1, or in fluid communication with a flare stack 66 as shown in FIG. 2.

(25) Referring to FIG. 4, in the preferred embodiment, a second cryogenic liquefaction vessel 144 is provided for liquefying the C1-C2 gases. Second cryogenic liquefaction vessel 144 has an inlet 146 and an outlet 148 with inlet 146 in fluid communication with gas outlet 140 of second phase separator 134. Storage vessels 150 for the collection of liquefied C1-C2 gases are provided in fluid communication with outlet 148 of second cryogenic liquefaction vessel 144. In order for the C1-C2 gases to be liquefied, the gas in second liquefaction vessel 144 needs to be cooled to at least −162 degrees Celsius. Second cryogenic liquefaction vessel 144 is preferably a plate exchanger, however a person of skill will understand that different types of heat exchangers may be used. Paraffin cutters and methanol may be injected upstream of the first cryogenic liquefaction vessel 128 and/or second cryogenic liquefaction vessel 144 to maintain efficient flow through system 100. It will be understood that paraffin cutters and methanol may be injected at other locations within system 100.

(26) Other types of equipment may be included within system 100. This includes a sand catcher 152 which is positioned between gas source 112 and first phase separator 114. Sand catcher 152 has an inlet 154 in fluid communication with gas source 112, a fluid outlet 156 in fluid communication with inlet 116 of first phase separator 114 and a sand outlet 158. Sand catcher 152 is used to capture sediments that travel with fluid as it exits gas source 112. A blow down line 160 is connected to sand outlet 158 which attaches to a sand storage vessel 162. Sand storage vessel 162 may have a pressure relief line 164 for safety that is connected to a flare stack 66. Where sour gas is a concern, a scavenger may be injected to minimize entrained the sour gas when fluid travels through sand catcher 152. When sand catcher 152 is not used, scavenger may be injected prior to fluid entering first phase separator 114. A booster, not shown, may be connected to gas source 112 to increase the volume of fluid that can be drawn out of gas source 112 and sent through system 100. The booster may be a pump which generally increases the pressure of the flow stream from gas source 12. Generally a simpler mechanism which has a single stage of compression may be used and increases the pressure of an already pressurized gas. A two stage booster may also be used. Boosters are beneficial for increasing gas pressure, transferring high pressure gas and charging gas cylinders. Where the flow stream from gas source 12 is primarily gaseous, a compressor may be used to increase the pressure of the gas. A person of skill will understand what types of boosters may be used depending upon the type of gas source being used.

(27) For safety, a first pressure relief line 168 may be provided between first phase separator 114 and first cryogenic liquefaction vessel 128. First pressure relief line 168 provides for a means of quickly relieving pressure that may build up when gas exits gas outlet 122 of first phase separator 114 before entering inlet 130 of first cryogenic liquefaction vessel 128. First pressure relief line 168 prevents over pressurization of first cryogenic liquefaction vessel 128 in the event of increased gas rates due to well slugging. First pressure relief line 168 is provided in fluid communication with a flare stack 66. A second pressure relief line 170 may be provided on second phase separator 134. Second pressure relief line 170 is provided in fluid communication with a flare stack 66. Another pressure relief line 172 may be provided on second phase separator 114. A person of skill will understand that sand storage pressure relief line 164, first pressure relief line 168, second pressure relief line 170 and second phase separator pressure relief line 172 may be in fluid communication with the same flare stack 66, different flare stacks 66 or multiple flare stacks 66. A number of LNG and LPG storage vessel relief lines 173 are provided on storage vessels 142 and 150 that vent to flare stacks 66 for safety purposes.

(28) First cryogenic liquefaction vessel 128 and second cryogenic liquefaction vessel 144 are preferably cooled using liquid nitrogen. A nitrogen source 74 such as a liquid nitrogen tank or a nitrogen generator is provided and a nitrogen loop is created through first cryogenic liquefaction vessel 128. Nitrogen is pumped through nitrogen loop using a pump, not shown. Nitrogen travels out of nitrogen source 74 through outlet 76 and into first cryogenic liquefaction vessel 144 through nitrogen inlet 78. The nitrogen cools gases flowing through first cryogenic liquefaction vessel 144 and flows out through nitrogen outlet 80. The nitrogen continues to flow around a nitrogen loop 82 back to nitrogen source 74. Nitrogen source 74 has a nitrogen vent 84 to vent the used nitrogen to the atmosphere. When second cryogenic liquefaction vessel 144 is included in system 100, nitrogen travels out of nitrogen source 74 through outlet 76 which is split into two inlet lines 86 and 88. Each of inlet lines 86 and 88 are provided with valves 90 to control the flow to first cryogenic liquefaction vessel 128 and second cryogenic liquefaction vessel 144, respectively. A flow line 92 splits off of inlet lines 86 and 88 which connects to nitrogen loop 82 and acts as a pressure relief when necessary with valve 90 being used to control the flow of nitrogen through flow line 92 to nitrogen loop 82. Inlet line 86 is connected to nitrogen inlet 78 of first cryogenic liquefaction vessel 128 and inlet line 88 connects to a nitrogen inlet 94 of second cryogenic liquefaction vessel 144. The nitrogen cools gases flowing through second cryogenic liquefaction vessel 144 and flows out through nitrogen outlet 96. Nitrogen outlet 96 is in fluid communication with nitrogen loop 82 which loops the nitrogen back to nitrogen source 74.

(29) A person of skill will understand that different mediums may be used to cool first cryogenic liquefaction vessel 128 and second cryogenic liquefaction vessel 144. Different types of fluid loops may be used depending upon the method of cooling that is used. It may be beneficial in some instances to use glycol cooled using liquid nitrogen as opposed to liquid nitrogen itself where conditions may cause the nitrogen to be reactive within first cryogenic liquefaction vessel 128 and/or second cryogenic liquefaction vessel 144. Cooling and condensing may also be accomplished by heat exchange with several refrigerant fluids that have successively lower boiling points known as a cascade system. In the alternative, a single refrigerant may be used at several different pressures to provide several temperature levels. A multi-component system which contains several refrigerant components may also be used. A typical combination of refrigerants often includes propane, ethylene and methane. A person of skill will understand that other methods of cooling and condensing may also be used.

(30) Any use herein of any terms describing an interaction between elements is not meant to limit the interaction to direct interaction between the subject elements, and may also include indirect interaction between the elements such as through secondary or intermediary structure unless specifically stated otherwise.

(31) In this patent document, the word “comprising” is used in its non-limiting sense to mean that items following the word are included, but items not specifically mentioned are not excluded. A reference to an element by the indefinite article “a” does not exclude the possibility that more than one of the element is present, unless the context clearly requires that there be one and only one of the elements.

(32) It will be apparent that changes may be made to the illustrative embodiments, while falling within the scope of the invention. As such, the scope of the following claims should not be limited by the preferred embodiments set forth in the examples and drawings described above, but should be given the broadest interpretation consistent with the description as a whole.