Patent Publication Number: US-2016237363-A1

Title: Gas processing system

Description:
CROSS REFERENCE TO RELATED APPLICATION 
     This is a continuation-in-part from, and claims the benefit of, prior U.S. patent application Ser. No. 14/873,657 filed on Oct. 2, 2015, which claims the benefit of and priority to U.S. Provisional Application Ser. No. 62/060,899, filed Oct. 7, 2014: the disclosures of each are entirely incorporated herein by reference as if fully rewritten. 
    
    
     BACKGROUND 
     1. Technical Field 
     The present disclosure relates generally to the field of fossil fuel processing devices. More particularly, the present disclosure relates to separators for separating fuel from non-fuels. Specifically, the present disclosure relates to a gas processing apparatus including two sets of vertically stacked gas separators configured to separate fuel from non-fuel inside two respective housings. 
     2. Background Information 
     Fossil fuel exploration and drilling is a booming industry that often requires extracting operations to occur in remote areas. The remoteness of some well sites increases the difficulty for transporting drilling components and processing units as the roadway infrastructure may not be fully developed to handle such an aggressive construction timeline for extracting the fossil fuels. Some gas processing systems require two separators to cooperate together in separating fuel from non-fuel, particulates, and other liquids as natural gas or fossil fuels are extracted from the ground. 
     After extracting fossil fuel from an in-ground well, the fossil fuel must be processed in a gas processing system before it can be sold to and consumed by the public. Many types of gas processing systems are known to exist, and there are a variety of components in gas processing systems. 
     One common component in a gas processing system is a separator. A separator is a pressure vessel configured to separate fuel from the non-fuel matter, such as particulates and water that are extracted with the fossil fuel from the well head during the gas extraction process. Some gas processing systems include two or more separators, such as a first high pressure separator and a second lower pressure separator. They cooperate to route separated and processed gas to a sales pipeline for consumption. 
     To date, two separator systems are aligned in a side-by-side basis that require a housing to be quite wide. These wide housings are very often wider than the federal highway maximum width for transporting goods on a highway. As such, suppliers of these vessels must obtain a special wide load permit to ship these two side-by-side separators. 
     SUMMARY 
     Issues continue to exist with gas processing systems that include two or more gas separators. These separators are large devices and often take up a significant amount of space which increases costs of materials for housing components, shipping/transport costs associated with moving large items, amongst other things, for both consumers and suppliers in the gas processing industry. The present disclosure addresses these and other issues. 
     In one aspect, the disclosure may provide a gas processing apparatus comprising: a first gas processing vessel; and a second gas processing vessel positioned above the first vessel, the first and second vessels configured to separate fuel from non-fuel in a footprint area as the fuel moves from upstream to downstream through a gas processing system. 
     In another aspect, the disclosure may provide at least two gas processing pressure vessels positioned above a single pressure vessel footprint area, the at least two vessels configured to process fuel moving from upstream to downstream through a gas processing system. 
     In yet another aspect, an embodiment of the disclosure may provide a method of use for a stacked gas processing vessel comprising the steps of: moving fuel into a first gas processing vessel through an inlet; moving fuel out of the first gas processing vessel through an outlet; moving fuel vertically towards a second gas processing vessel; moving fuel into the second gas processing vessel through an inlet; and moving fuel out of the second gas processing vessel through an outlet. 
     In another aspect, an embodiment of the disclosure may provide a method of use for stacked gas processing separators comprising the steps of: providing at least two gas separators configured to process fuel moving through a gas processing system by separating fuel matter from non-fuel matter; and positioning the two separators above a footprint area to form a vertically stacked configuration, the footprint area generally defined as the length of about one separator multiplied by the width of about one separator, the footprint area on a floor with a floor width less than a width of two separators in a side-by-side configuration. 
     In another aspect, the disclosure may provide a gas processing apparatus that includes two pressure vessels, or two separators, above a single vessel footprint area in a vertically stacked configuration. The stacked configuration permits the processing of gas to occur in a space having less length or less width than that of two separators arranged tip-to-end or side-by-side, respectively. The first and second separators are configured to separate fuel from non-fuel in a footprint area of a single gas separator as the fuel moves from upstream to downstream through a gas processing system. Further, the gas processing apparatus of the present disclosure permits the two separators to fit in a housing compartment that is more easily transportable via tractor-trailer. 
     Further, issues continue to exist with dual separators arranged in a side-by-side configuration. The present disclosure addresses these and other issues by providing a gas processing housing box able to retain two gas processing pressure vessels therein while maintaining a width narrower than the United States Department of Transportation Federal Highway Administration maximum width for a commercial vehicle. 
     In one aspect, an embodiment of the disclosure may provide a transportable housing for a gas processing apparatus comprising: a chamber defined by a plurality of housing walls joined together to therein retain at least two gas processing pressure vessels in a vertically stacked configuration; and a housing width narrower than the United States Department of Transportation Federal Highway Administration maximum width for a commercial vehicle to allow transportation of the housing without the need for an oversized/wide load shipping permit. 
     In one aspect, an embodiment of the disclosure may provide a housing for two vertically stacked fuel separators comprising: a first sidewall on a housing box therein defining a chamber; a second sidewall on the housing box spaced apart from the first sidewall; a housing width distance, defined from the first sidewall to the second sidewall, less than about 102 inches; the chamber adapted to therein contain two vertically stacked gas processing separators and a gas processing heater; and a heat exchanging container within the chamber. 
     In another aspect, the disclosure may provide a gas processing apparatus housing comprising: a floor having a width; a housing chamber defined by the floor and connected walls, the chamber adapted to retain a pair of gas processing pressure vessels in a vertically stacked configuration; and the floor width less than a width for the pair of pressure vessels if the vessels were in a side-by-side configuration. 
     In yet another aspect, an embodiment may provide a method of constructing a housing for a stacked gas processing apparatus, comprising the steps of: forming a housing first section to retain a stacked gas processing apparatus therein; connecting the housing first section to a housing second section to form a box-like structure and having a housing width narrower than the United States Department of Transportation Federal Highway Administration maximum width for a commercial vehicle to permit transportation of the housing without the need for an oversized/wide load shipping permit. 
     In another aspect, an embodiment may provide a method of use for two gas processing pressure vessels comprising the steps of: mounting two gas processing pressure vessels in a stacked configuration within a chamber of a gas processing housing; and attaching a wall to the housing to enclose the chamber, wherein the housing includes a housing width narrower than the United States Department of Transportation Federal Highway Administration maximum width for a commercial vehicle to allow transportation of the housing without the need for an oversized load shipping permit. Then, further comprising the step of transporting the housing on a road without an oversized load shipping permit. 
     In another aspect, the disclosure may provide a housing for a gas processing apparatus formed by a plurality of walls joined together to form a box-like structure defining a chamber therein. The chamber is configured to retain a pair or more of gas processing pressure vessels in a vertically stacked configuration. The housing has a width less the United States Department of Transportation Federal Highway Administration maximum width for a commercial vehicle to allow transportation of the housing without the need for an oversized load shipping permit. The floor width inside the chamber less than a width for said pair of pressure vessels if said vessels were in a side-by-side configuration. 
     Further, issues may continue to exist with gas processing housings that can only hold two or three units therein. For example, at some well site locations, there may be up to six or more wells pumping fossil fuel from the ground. Thus, there exists a need for an improved transportable gas processing system that is formed from a first gas processing modular unit and a second gas processing modular unit; wherein each unit houses or supports a plurality of gas processing vessels at least equal to the number of wells at the site location. 
     In another aspect, the disclosure may provide a gas processing system comprising: a first module unit supported by a first frame having a first width and a first length dimensionally sized for transport by a tractor trailer without a wide load permit; a first set of gas processing devices supported by the first module unit; a second module unit supported by a second frame having a second width and a second length dimensionally sized for transport by a second tractor trailer without a wide load permit; a second set of gas processing device supported by second module unit; and a junction directly connecting the first module to the second module. 
     Another aspect may provide, a method of processing fossil fuel comprising the steps of: pumping fossil fuel from a first well head at a well site location along a first gas flow pathway; pumping fossil fuel from a second well head at the well site location along a second gas flow pathway; decreasing pressure of the fossil fuel along the first gas flow pathway in a first set of heat exchanging pipeline submerged in heated fluid; decreasing pressure of the fossil fuel along the second gas flow pathway in a second set of heat exchanging pipeline submerged in heated fluid; separating fossil fuel from other constituents along the first gas flow pathway in a first gas separator; separating fossil fuel from other constituents along the second gas flow pathway in a second gas separator; wherein the first and second gas separators are housed in a first module and aligned in a vertically stacked configuration; combining the first and second gas flow pathways downstream from the first and second gas separators. 
     In yet another aspect, an embodiment of the present disclosure may provide a method for installing a gas processing system comprising the steps of: hauling a first gas processing module by a tractor trailer to adjacent a fossil fuel well site location without an oversized load permit; unloading the first gas processing module from the tractor trailer; hauling a second gas processing module by a tractor trailer to the well site location without an oversized load permit; unloading the second gas processing module from the tractor trailer; and joining the first gas processing module with the second gas processing module at a junction. 
    
    
     
       BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS 
       A sample embodiment of the disclosure, illustrative of the best mode in which Applicant contemplates applying the principles, is set forth in the following description, is shown in the drawings and is particularly and distinctly pointed out and set forth in the appended claims. The accompanying drawings, which are incorporated in and constitute a part of the specification, illustrate various example methods, and other example embodiments of various aspects of the disclosure. It will be appreciated that the illustrated element boundaries (e.g., boxes, groups of boxes, or other shapes) in the figures represent one example of the boundaries. One of ordinary skill in the art will appreciate that in some examples one element may be designed as multiple elements or that multiple elements may be designed as one element. In some examples, an element shown as an internal component of another element may be implemented as an external component and vice versa. Furthermore, elements may not be drawn to scale. 
         FIG. 1  is a side elevation view of a gas processing apparatus of the present disclosure depicting two pressure vessels, a first separator and a second separator, in a vertically stacked configuration; 
         FIG. 2  is a top view of the gas processing apparatus shown installed in a housing; 
         FIG. 3  is a side elevation view of the gas processing apparatus shown installed in the housing; 
         FIG. 4  is an end elevation view of the gas processing apparatus shown installed in the housing; 
         FIG. 5  is an end elevation view of an alternative embodiment of the present disclosure depicting a gas processing apparatus including offset stacked separators installed in the housing; 
         FIG. 6  is a first schematic view depicting the first and second separators of the gas processing apparatus connected via pipeline in a series configuration; 
         FIG. 7  is a second schematic view depicting the first and second separators of the gas processing apparatus connected via pipeline in a series configuration with a heating unit positioned downstream from the first separator and upstream from the second separator; 
         FIG. 8A  is an assembled perspective view of an exemplary housing for a gas processing apparatus having a single column of stacked separators; 
         FIG. 8B  is a perspective view of the housing in a separated state (i.e., an exploded perspective view) and depicting that two sections are joined together to form the assembled housing; 
         FIG. 9  is a left side elevation view of the housing; 
         FIG. 10  is an end elevation view of the housing taken along line  10 - 10  in  FIG. 9 ; 
         FIG. 11  is a top section view taken along line  11 - 11  in  FIG. 9 ; 
         FIG. 12  is a side section view taken along line  12 - 12  in  FIG. 10 ; 
         FIG. 13  is an end section view taken along line  13 - 13  in  FIG. 9 ; 
         FIG. 14  is an environmental left side view of the housing on a trailer towed by a tractor-truck atop a trailer for shipment; 
         FIG. 15  is an end section view taken along line  15 - 15  in  FIG. 14  depicting the housing on the trailer having a width less than the federal maximum for a commercial vehicle; 
         FIG. 16  is top schematic view of a well site layout including an exemplary embodiment of a gas production unit having two sets of three vertically stacked gas separators, each set of three separators housed within its own housing and each separator in fluid communication with a respective gas production well, depicting six total wells; 
         FIG. 16A  is top schematic view of a well site layout including an exemplary embodiment of another gas production unit having two sets of two vertically stacked gas separators, each set of two separators housed within its own housing and each separator in fluid communication with a respective gas production well, depicting four total wells; 
         FIG. 17  is a representation depicting that the side views of  FIG. 17A ,  FIG. 17B , and  FIG. 17C  are to be viewed collectively and arranged left-to-right to produce a large composite side view of the gas production unit; 
         FIG. 17A  is a partial side view of one end of the gas production unit to be viewed collectively with  FIG. 17B  and  FIG. 17C ; 
         FIG. 17B  is a partial side view of the mid-section of the gas production unit to be viewed collectively with  FIG. 17A  and  FIG. 17C ; 
         FIG. 17C  is a partial side view of an opposite end of the gas production unit to be viewed collectively with  FIG. 17A  and  FIG. 17B ; 
         FIG. 18  is a representation depicting that the top views of  FIG. 18A ,  FIG. 18B , and  FIG. 18C  are to be viewed collectively and arranged left-to-right to produce a large composite top view of the gas production unit; 
         FIG. 18A  is a partial top view of one end of the gas production unit to be viewed collectively with  FIG. 18B  and  FIG. 18C ; 
         FIG. 18B  is a partial top view of the mid-section of the gas production unit to be viewed collectively with  FIG. 18A  and  FIG. 18C ; 
         FIG. 18C  is a partial side view of an opposite end of the gas production unit to be viewed collectively with  FIG. 18A  and  FIG. 18B ; 
         FIG. 19  is an end view taken along line  19 - 19  in  FIG. 17A ; 
         FIG. 20  is an opposite end view taken along line  20 - 20  in  FIG. 17C  depicting a set of sand separators connected to the gas production unit; 
         FIG. 21  is an end view similar to  FIG. 20  but depicted with the sand separator removed; 
         FIG. 22  is a cross section view of a heat exchanger fluid bath in one embodiment; 
         FIG. 22A  is a cross section view of a heat exchanger fluid bath in another embodiment; 
         FIG. 23  is a vertical cross section taken along line  23 - 23  in  FIG. 17B  depicting three stacked separators and heat exchanging pipeline submerged in fluid inside the heat exchanger; 
         FIG. 23A  is a vertical cross section of another embodiment of heat exchanger taken along a line similar to  23 - 23  in  FIG. 17B  depicting three stacked separators and heat exchanging pipeline submerged in independent fluid chambers inside the heat exchanger; and 
         FIG. 23B  is a vertical cross section of another embodiment of heat exchanger taken along a line similar to  23 - 23  in  FIG. 17B  depicting two stacked separators and heat exchanging pipeline submerged inside the heat exchanger. 
     
    
    
     Similar numbers refer to similar parts throughout the drawings. 
     DETAILED DESCRIPTION 
     As depicted in  FIG. 1 , a gas processing apparatus  50  of the present disclosure includes at least two gas processing pressure vessels  52  positioned above a single pressure vessel footprint area  54  ( FIG. 2 ). The at least two pressure vessels  52  are configured to process fuel moving from upstream to downstream through a gas processing system. In one particular embodiment of the gas processing apparatus  50 , the least two gas processing pressure vessels  52  include a longitudinally oriented first gas separator  56  and a longitudinally oriented second gas separator  58 . 
     With continued reference to  FIG. 1 , first separator  56  includes a generally cylindrical vessel body  60  extending along a longitudinal axis  62  and supported by a frame  64 . Vessel body  60  defines a chamber  66  for therein separating fuel from non-fuel (particulates and non-fuel liquids such as water) as fuel is moved from upstream to downstream through the separator inlet  68  and outlet  70 , respectively, as one having ordinarily skill in the fossil fuel or gas processing field would understand. A separator radius  72  ( FIG. 4 ) extends from longitudinal axis  62  to inner surface of vessel body  60 . In the shown embodiment, cylindrical vessel body  60  of first separator includes an outer circumferential surface capped at each end with hemispherical ends  74 . 
     The second separator  58  is configured similarly to the first separator  56  and includes a generally cylindrical vessel body  76  extending along a longitudinal axis  78  and supported by a frame  80 . Vessel body  76  defines a chamber  82  for therein separating fuel from non-fuel as fuel is moved from upstream to downstream through the separator inlet  84  and outlet  86 , respectively, as one having ordinarily skill in the gas processing field would understand. A second separator radius  88  ( FIG. 4 ) extends from longitudinal axis  78  to inner surface of vessel body  76 . In the shown embodiment, cylindrical vessel body  76  of second separator  58  includes an outer circumferential surface capped at each end with hemispherical end caps  90 . 
     As depicted in  FIG. 2 , first and second separators  56 ,  58  are mounted to a platform or floor surface  92  above the footprint area  54 . The footprint area  54  is on the floor surface  92  and generally defined as the space directly beneath the first separator  56  equal to the length  94  of the first separator multiplied by the width  96  of the first separator  56 . Platform  92  is on a gas processing box-housing  101  for containing the gas processing apparatus  50  of the present disclosure therein. The housing  101  may also retain therein additional elements ordinarily associated with a gas processing system, by way of non-limiting example, valves, hoses, gauges, or pressure chokes. 
     As depicted in  FIG. 3 , when the gas processing apparatus is mounted on the platform  92  above the footprint area  54 , a section of the first separator  56  is radially coplanar with a section on the second separator  58  along a radial plane P 1 . Further in one particular embodiment, a surface on the first separator  56 , such as the tip of the first separator hemispheric end cap  74 , is in the same radial plane P 2  or radially coplanar with a surface on the second separator  58 , such as the tip of the second separator hemispheric end cap  90 . 
     As depicted in  FIG. 4 , when the gas processing apparatus is mounted on the platform  92  above the footprint area  54  in the housing  101 , the longitudinal axis  62  of the first separator  56  and the longitudinal axis  78  of the second separator  58  are axially coplanar along an axial plane P 3 . Further in one particular embodiment, an axially extending outer surface on the first separator  56 , such as vessel body outer surface on the first separator  56 , is in the same axial plane P 4  or axially coplanar with an outer surface on the second separator  58 , such as the vessel body outer surface on the second separator  58 . 
     With continued reference to  FIG. 4 , an inter-vessel space  99  is defined between the two pressure vessels (first separator  56  and second separator  58 ). The bottom of the inter-vessel space  99  is bound by the top circumferential outer surface on the first separator  56 . The top of the inter-vessel space  99  is bound by the bottom circumferential outer surface on the second separator  58 . 
     These respective radial ( FIG. 3 ) and longitudinal ( FIG. 4 ) coplanar configurations ensure the second separator  58  alignment directly above first separator  56 , and the stacked two separators are above the footprint area  54  of a single separator. In the shown embodiments, first and second separators have similar dimensions, yet there may be instances where the second or upper vessel may have a smaller diameter, which would permit the longitudinal axis of the second separator to be offset from a first separator axial plane while still being located above the first separator in the footprint area. The outer surfaces may remain coplanar along plane P 4  even though there are different radiuses. Similarly, the outer surfaces may remain coplanar along plane P 2  even though upper separator may have a different (i.e., shorter) length than the first separator  56 . 
     As depicted in  FIG. 5 , an alternate embodiment of the present disclosure includes stacked separators  50 A wherein the top of first separator  56  is adjacent the bottom of second separator  58 . In this way, the two separators  56 ,  58  are not directly vertical. Separators  56 ,  58  may be slightly offset from each other while second separator  58  still is generally above first separator  56 . In this embodiment, the right outer circumferential of edge of the first separator  56  is in plane P 5 . The centerline axis  62  of first separator  56  is coplanar with the outer circumferential edge of second separator  58  in plane P 6 . The centerline axis  78  of second separator  58  is coplanar with a left outer circumferential edge of first separator  56  in plane P 7 . 
     In accordance with an aspect of the present disclosure, the gas processing apparatus including two pressure vessels  52 , or two separators, above a single vessel footprint area permits the processing of gas to occur in a space having less length and less width than that of two separators arranged tip-to-end or side-by-side, respectively. The gas processing apparatus of the present disclosure permits the two separators  52  to fit inside a chamber  113  defined by housing  101  that is more easily transportable via tractor-trailer, since the gas processing apparatus  50  occupies less longitudinal distance and less width distance than two separators arranged tip-to-end or side-by-side, respectively. While the stacked configuration of two gas separators  52  disclosed herein may have a larger height than a tip-to-end or a side-by-side arrangement of two separators, tractor-trailer size limitations ordinarily are more limited by length and width, rather than height. 
     In operation and as detailed throughout  FIGS. 2-5 , a method for use of the stacked gas processing separator apparatus  50  of the present disclosure includes the steps of: providing at least two gas separators  52  configured to process fuel moving through a gas processing system by separating fuel matter from non-fuel matter; and positioning the two separators  52  above a single separator footprint area  54  to form a vertically stacked configuration, the footprint area  54  generally defined as the length  94  of about one separator multiplied by the width  96  of about one separator. Then, installing the stacked two separators in a box-housing  101 , wherein the box-housing has a floor width  102  ( FIG. 5 ) less than the combined width of the two separators if they were in a side-by-side configuration. Stated otherwise, the sum of width  96  of the two separators  56 ,  58  is greater than the floor width  102 . 
     In operation and as detailed in the schematic of  FIG. 6 , first separator  56  and second separator  58  are connected via gas pipeline  104  in a series configuration wherein the first separator  56  is upstream from the second separator  58 . Fossil fuels extracted from a well are processed moving downstream through a gas processing system in the pipeline  104  into the first separator  56  through inlet  68  ( FIG. 3 ) wherein fuel is separated from non-fuels and exits through outlet  70  ( FIG. 3 ). Fuel then moves in an angled direction between −90 and 90 degrees relative to horizontal. Preferably the fuel moves between 45 and 90 degrees upward from first separator  56  to second separator  58 . Alternatively, the separators  56 ,  58  could be arranged such that the fuel moves downward between first and second separators. The fuel continues to flow via pipeline  104  into second separator  56  through inlet  84  ( FIG. 3 ) wherein the fuel is separated again from any remaining non-fuel that remained after flowing through the first separator  56 . Fuel exits second separator  58  through outlet  86  ( FIG. 3 ) and flows downstream through the remaining portions of the gas processing system. While the schematic of  FIG. 6  is shown in a linear relationship, this only represents the series configuration of the two separators and the actual physical arrangement of the two separators will be vertically above the single footprint area. 
     In operation and as detailed in the schematic of  FIG. 7 , fuel moves from a well through a gas processing system via pipeline  104  where the fuel is separated from a non-fuel in the first separator  56 . In this particular embodiment, non-fuel refers to particulates and non-fuel liquids such as water. A first amount of separated fuel is then metered off in a metering device and sent to a downstream destination such as a holding tank or a sales pipeline  105 . A second amount of the fuel is sent to a heating unit  106 . The second amount of fuel is heated in the heating unit  106  via submerged heating element  107  to create a fuel vapor. The fuel vapor is then sent downstream via pipeline  104  to a vapor recovery unit  108 . The fuel vapors are separated from any remaining non-fuel vapors in the second separator  58 . From the second separator outlet the separated fuel vapors may flow to and be recovered in an additional vapor recovery unit. After recovering the fuel vapor, the second amount of fuel may be metered through outlet leading to a holding tank or sales line  110 , or may be sent to a flume stack  112  to be burned off. Again, while the schematic of  FIG. 7  is shown in a linear relationship, this only represents the series configuration of the two separators and the heating unit positioned between the two separators. In one particular embodiment, the actual physical arrangement of the two separators will be vertically above the single footprint area, and the heating unit will be adjacent the two stacked separators outside the footprint area. 
     Further, the broken lines along pipeline indicated in schematic views  FIGS. 6-7  indicate that additional gas processing components may be located between the identified components of the present disclosure along the gas processing stream as one in the art would comprehend. 
     One preliminary exemplary housing  101  for a gas processing apparatus of the present disclosure is depicted throughout  FIGS. 8A-15 . Housing  101  is an improved device including a chamber  113  ( FIG. 8B ) defined by a plurality of housing walls  114  joined together to therein retain at least two gas processing pressure vessels  50  in a vertically stacked configuration. Housing  101  includes a housing width  118  ( FIG. 13 ) narrower than the United States Department of Transportation Federal Highway Administration maximum width for a commercial vehicle to permit transportation (i.e., shipment) of the housing without the need for an oversized load shipping permit. 
     As detailed in  FIG. 8A  and  FIG. 8B , housing  101  includes a left wall  120  spaced apart from a right wall  122  that therebetween define a lateral or transverse direction. Housing  101  further includes a first end wall  124  spaced apart from a second end wall  126  that therebetween define a longitudinal direction. Housing  101  further includes a top wall  128  spaced apart and opposite a bottom wall  130  therebetween defining a vertical direction. Walls  120 ,  122 ,  124 ,  126 ,  128 , and  130  are joined together to form a general box-like structure therein defining chamber  113 . 
     With continued reference to  FIG. 8A  and  FIG. 8B , a plurality of apertures  132  may be formed in the walls permitting gas pipeline to extend therethrough. In one particular embodiment apertures  132  are shown formed in second end wall  126 . However, it is clearly to be understood that apertures may be formed in any or each of the walls  120 ,  122 ,  124 ,  126 ,  128 , and  130  as necessary to permit gas to flow into one of the vessels  50  or another component in chamber  113  of housing  101 . An access opening  134  with a door  136  may also be formed in one of the walls permitting ingress and egress of a human operator into chamber  113 . 
     As detailed in  FIG. 8B , housing  101  includes a housing first section  138  and a housing second section  140 . The respective housing sections  138 ,  140  are configured to be assembled separately and then joined together to create the box-like structure of housing  101 . In one particular embodiment, housing first section  138  includes left wall  120 , a first section  124   a  of first end wall  124 , a first section  126   d  of second end wall  26 , a first section  128   a  of top wall  128 , and a first section  130   a  of bottom wall  130 . First section  138  is joined to second section  140  along a housing seam union  142 . Union seam  142  extends along a longitudinal plane from first end wall  124  to second end wall  126 . Housing second section  140  includes right wall  122 , a second section  124   b  of first end wall  124 , a second section  126   b  of second end wall  126 , a second section  128   b  of top wall  128 , and a second section  130   b  of bottom wall  130 . 
     As will be detailed further below, housing  101  is assembled in two sections  138 ,  140  to permit the stacked vessels  50  to be installed on floor surface above the single vessel footprint area within chamber  113  prior to housing  101  being joined and sealed along union seam  142 . In one particular embodiment, assembled housing  101  may sit on or be supported by frame  146  to permit safe and sturdy transport of housing  101 . 
     A left side elevation view is detailed in  FIG. 9 . Left wall  120  extends vertically upwards from frame  146  towards top wall  128 . Left wall  120  extends from first wall  124  longitudinally to second wall  126 . The longitudinal axis of left wall  120  substantially defines the length of housing  101 . Length  148  of housing  101  is long enough to retain two or three vertically stacked pressure vessels  50  such as particulate or gas separators as understood in the gas processing industry but shorter than any length prescribed as a maximum length for a commercial vehicle by the United States Department of Transportation Federal Highway Administration to permit transportation of the housing without the need for an Oversized Load Shipping Permit. 
     As detailed in  FIG. 10 , housing  101  has a width  118  measured laterally from left wall  120  to right wall  122 . The housing width  118  being narrower than the maximum width for a commercial vehicle by the United States Department of Transportation Federal Highway Administration allows the transportation of housing  101  without the need for an Oversized Load Shipping Permit. Currently, the United Stated Department of Transportation Federal Highway Administration maximum width for a commercial vehicle is 112 inches. It is contemplated that generally the width  118  of housing  101  will be from about 85 inches to about 102 inches. More particularly in one embodiment, the width  118  of housing  101  is about 96 inches. One exemplary non-limiting advantage of having width  118  be about 96 inches is that it is wide enough to allow a human to enter chamber  113  through door  136  to service vessels  50 , but still narrow enough to require vessels  50  to be arranged in a stacked configuration. 
     With respect to the section views detailed in  FIG. 11 ,  FIG. 12 , and  FIG. 13 , housing  101  houses the pair of pressure vessels  50  in chamber  113 . In one particular embodiment, pressure vessels  50  include the first separator  56 , and the second separator  58 . First and second separators  56 ,  58  are stacked in a vertical configuration. When viewed from the end, as in  FIG. 6 , first vessel  56  has a width  154  and second vessel  58  has a width  156 . The present disclosure is configured to house the stacked separators  56 ,  58  above the floor space  144  having a width  158 . Floor width  158  is less than the sum of first and second separator widths  154 ,  156 . Stated otherwise, if separators  56 ,  58  were arranged in a side-by-side configuration, floor width  158  would be less than the width of the two side-by-side separators  56 ,  58 . Stacked configuration allows housing  101  to be transported on a conventional tractor-trailer device as overall housing width  118  is less than the Federal Highway maximum as described above. 
     With continued reference to  FIGS. 11-13 , a gas processing heat exchanging unit  160  (also referred to as heat exchanger  160 ) may also be included within chamber  113  on housing  101 . Heat exchanger  160  includes heat exchanging container wall  162  extending from front end  124  extending longitudinally towards and connecting with second end  126 . A fluid filled chamber  164  is defined by heat exchanger  160 . Chamber  164  includes heat exchanging pipeline extending and winding in a serpentine manner therein to, heat fuel moving through pipeline  104  along the flow stream of the gas processing system. Heat exchanger  160  has a width  163  that extends from container wall  162  to left wall  122 . Heat exchanger width  163  defines a portion of housing width  118 . Further, heat exchanger width  163  plus floor width  158  substantially define housing width  118 . 
     As depicted in  FIG. 11 , a control system  180  is adjacent one of the housing walls configured to operate the at least two gas processing pressure vessels  50 . A mounting bracket  182  connects the control system  180  to an inner surface on one of the housing walls to dispose the control system  180  within the chamber. Control system  180  may include gas processing logic to actuate a valve to send gas through one of the stacked separators  50 . “Logic”, as used herein, includes but is not limited to hardware, firmware, software and/or combinations of each and a computer to perform a function(s) or an action(s), and/or to cause a function or action from another logic, method, and/or system. For example, based on a desired application or needs, logic may include a software controlled microprocessor, discrete logic like a processor (e.g., microprocessor), an application specific integrated circuit (ASIC), a programmed logic device, a memory device containing instructions, an electric device having a memory, or the like. Logic may include one or more gates, combinations of gates, or other circuit components. Logic may also be fully embodied as software. Where multiple logics are described, it may be possible to incorporate the multiple logics into one physical logic. Similarly, where a single logic is described, it may be possible to distribute that single logic between multiple physical logics. 
     With reference to  FIG. 14  and  FIG. 15 , housing  101  is shown in a transportation environmental side view and cross section end view respectively. Housing  101  is configured to be transported on a trailer  166 , towed by tractor-truck or vehicle  168 . When housing  101  is on trailer  166  for shipment, the height  170  of the loaded housing  101  on trailer  166  is preferably less than about 14 feet measured from the ground to the top of the housing  101  on trailer  166 . One exemplary non-limiting purpose is that, generally heights less than about 14 feet maybe moved along the Federal Highway System. In one particular embodiment, the height of housing  101  itself measured from floor  144  to top wall  128  is from about 100 inches to about 115 inches and even further, in the shown embodiment, housing height from floor  144  to top  128  is 108½ inches. Trailer width  172  is equal to or narrower than the United States Department of Transportation Federal Highway Administration maximum for a commercial vehicle (112 inches at the time of this disclosure). Further, as shown in one particular embodiment ( FIG. 15 ), housing width  118  may be substantially equal or similar to trailer width  172 . 
     In accordance with one aspect of an embodiment of the present disclosure, housing  101  permits a supplier within the oil and gas processing fields to provide a housing for a two separator system that is transportable along the Federal Highways without the need for a special Oversized Load Permit. This is extremely advantageous for shipping costs which ultimately reduces cost to the end consumer. 
     While it is contemplated that walls  120 ,  122 ,  124 ,  126 ,  128 , and  130  used to construct housing  101  will be constructed from heavy steel ordinarily used in the gas processing housing industry, other materials may suffice to provide adequate security for storing the complex gas processing components contained inside chamber  113 . 
     In operation, housing  101  is constructed by providing first section  138  and second section  140  in pre-assembled form. First section  138  is constructed by welding partial sections  124   a ,  126   a ,  128   a , and  130   a  to left wall  120 . Second section  40  is constructed by welding partial sections  124   b ,  126   b ,  128   b , and  130   b  to right wall  122 . First section  138  and second section  140  are longitudinally aligned such that their interior chambers are facing each other. With the chambers aligned, the vertically stacked pressure vessels  50  are installed on the floor space  144  in either one of the first section  138  or the second section  140 . The two sections  138 ,  140  are moved laterally inwards in the direction of Arrow(s) A ( FIG. 8B ) towards each other mating a long union seam  142 . 
     When the two sections  138 ,  140  are in a mated position ( FIG. 8A ), manufacturer welds or otherwise joins sections  138 ,  140  together along union seam  142 . While it is contemplated that the manner in which sections  138 ,  140  are joined is via weld, clearly other means of coupling section  38 ,  40  together such as rivets or bolts are entirely possible. 
     Once the structure of housing  101  has been assembled ( FIG. 8A ), pipeline may be connected to ensure the pressure vessels or the separators work as designed. In one particular embodiment, first and second separators  56 ,  58  are aligned and connected via pipeline in a series configuration with the heater being connected via pipeline in series between the two separators  56 ,  58 . 
     In operation and with respect to transportation/shipment, housing  101  is loaded onto trailer  166  and towed or hauled by truck  168  to an end destination, such as a gas production well site. The transporting of the housing  101  on a road is done without the need for an oversized load shipping permit. In one particular embodiment, the end destination is a well site for extracting fossil fuel such as natural gas. As previously discussed, the transport of housing  101  on trailer  166  does not require any special permit because the width  118  of housing  101  is narrower than the federal maximum width for transporting goods via a commercial vehicle on the highway. By way of non-limiting example, this is advantageous as the two vessels  50  are necessary for the gas processing operation occurring at the end destination or the well site. 
     After transportation and shipment has been completed and housing  101  has been unloaded and placed adjacent a well site, housing  101  operates by processing gas incoming through the inlet and flowing into the first separator  56  where fuel is separated from non-fuels. The fuels may be sent to a downstream pipeline, and the other matter may flow into heat exchanger  160  to be heated and then sent via pipeline to second separator  58  where any fuel remaining is separated out a second time and sent to a downstream destination such as a sales pipeline. 
     Further, when housing is deposited at a site location an operator may enter the chamber  113  through the door  136  formed in a sidewall of the housing. The operator may then contact a component on a control system  180  to actuate an element (e.g. a valve) along a pipeline to manipulate gas in the pipeline. Alternatively, after depositing the housing having the stacked pressure vessels therein at a site location, an element may be actuated along a pipeline in communication with the two pressure vessels remotely via a control system  180  mounted to the housing. 
     As depicted in  FIG. 16  through  FIG. 23B , another exemplary gas processing system is presented in accordance with the present disclosure and is generally depicted at  200 . System  200  includes a gas production unit  202 , a plurality of sand separators  204 , and a plurality of fossil fuel producing wells  206  located at a well site. 
     As depicted in  FIG. 16 , gas production unit  202  includes a first end  209  opposite a second end  210  defining a longitudinal direction therebetween. Production unit  202  includes a first side  212  opposite a second  214  defining a transverse or lateral direction therebetween. Gas production unit includes a first modular unit, or first module,  216  and a second modular unit, or second module,  218 . First module  216  and second module  218  are arranged side by side and adjoined to each other at a longitudinally extending junction  220  such that the first module  216  defines the first side  212  and the second module  218  defines second side  214 . 
     A plurality of sand separators  204  are operatively connected to gas production unit  202  via a pipeline. The plurality of sand separators  204  includes a first sand separator  204   a , a second sand separator  204   b , a third sand separator  204   c , a fourth sand separator  204   d , a fifth sand separator  204   e , and a sixth sand separator  204   f . A first sand separator, second sand separator, and third sand separator  204   a ,  204   b , and  204   c , are connected to first module  216 . The fourth sand separator, the fifth sand separator, and the sixth sand separator  204   d ,  204   e , and  204   f , are connected to second module  218 . Generally, each respective sand separator is connected to a single gas separator housed within one of the modules that each collectively define a portion of a gas flow pathway as will be described in greater detail below. Stated otherwise, in this embodiment, the wells and gas processing devices are distinct and their pipelines are not connected in series. Rather, they are connected in parallel operation and merge at a downstream destination, such as a sales pipeline  22 B. 
     The plurality of wells  206  includes a first well  206   a , a second well  206   b , a third well  206   c , a fourth well  206   d , a fifth well  206   e , and a sixth well  206   f . First well  206   a  produces fossil fuel and is operatively connected to either the first sand separator  204   a  or a first gas separator within first module  216 . Pipeline  208   a  feeds wet well head gas along a first gas flow pathway towards either first sand separator  204   a  or the first module  216 . A second set of pipeline  208   b  connects second well  206   b  producing fossil fuel to either the second sand separator  204   b  or a second gas separator within the first module  216 . A third set of pipeline  208   c  connects fossil fuel producing third well  206   c  to either the third sand separator  204   c  or a third gas separator within the first module  216 . A fourth set of pipeline  208   d  connects the fourth fossil fuel producing well  206   d  to either the fourth sand separator  204   d  or a fourth gas separator within the second module  218 . A fifth set of pipeline  208   e  connects the fifth fossil fuel producing well  206   e  to either the fifth sand separator  204   e  or a fifth gas separator within the second module  218 . A sixth set of pipeline  208   f  connects the sixth fossil fuel producing well  206   f  to either the sixth sand separator  204   f  or a sixth gas separator within the second module  218 . 
     As described in greater detail below, after the gas separators contained in each of the first module  216  and the second module  218  separate the fossil fuel from the non-fuel constituents, clean fossil fuel is output from the first module  216  along first output  222  and clean output gas is output from second output  224  from second module  218 . The first output  222  and the second output  224  are combined together in an overall combined output pipeline  226  which may be transferred to a downstream destination such as a sales pipeline or a storage holding tank. 
     As depicted in  FIG. 16A , an alternative embodiment of the gas processing system  200  is identified generally at  200 A. System  200 A is similar to gas processing system  200  but rather than having six sets of wells, six sand separators, and six gas separators within the first and second modules, there exists only four wells, four sand separators, and four gas separators in the first and second modules. System  200 A is depicted to indicate that while system  200  utilizes six wells, six sand separators, and six gas separators in two production units, any number of wells, sand separators, and gas separators may be used in accordance with the present disclosure. 
       FIG. 17  is a schematic representation depicting that the side elevation views of  FIG. 17A ,  FIG. 17B , and  FIG. 17C  are to be viewed collectively and arranged in a side to side manner. In keeping with this, the descriptions made herein will be made with reference to  FIG. 17A ,  FIG. 17B , and  FIG. 17C . 
     As depicted in  FIG. 17A ,  FIG. 17B , and  FIG. 17C , the first module  216  of gas production unit  202  includes a plurality of connected outer walls  228  defining a box-like configuration generally similar to that identified in the previous embodiments of  FIG. 1  through  FIG. 15 . Housing walls  228  are supported by a skid frame  230  having a length extending from first end  209  to second end  210 . Skid frame  230  has a width  232  ( FIG. 21 ) extending from junction  220  to first side  212 . The width  232  is sized to fit upon a traditional flatbed trailer  166  towed by a truck  168 . The advantage of width  232  being sized to fit upon a traditional flatbed trailer  166  is that it allows first module  216  to be towed by a truck  168  without the need for an oversize load shipping permit from any state, federal, or local agency overseeing highway or roadway regulations. 
     Housing walls  228  supported by frame  230  generally include five walls arranged in a box-like manner wherein one longitudinal wall is absent. Particularly, a first end wall  228   a  is opposite a second end wall  228   b , a top wall  228   c  is opposite a bottom wall  228   d , and first sidewall  228   e  is opposite an opening to the inner chamber  234  defined by the plurality of connected housing walls  228 . 
     Gas production unit  202  includes a plurality of stacked separators  240  within chamber  234  above bottom wall  228  and supported by skid frame  230 . A plurality of stacked separators  240  are directly vertically aligned above each other defining a stacked configuration that was previously identified in general versions with respect to  FIG. 1  through  FIG. 15 . The first set of the plurality of stacked separators  240  are associated with first module  216 . It is to be understood that second module  218  has another set of stacked separators identical to those identified in  FIG. 17  but are not shown in the longitudinal cross section view. The plurality of stacked separators  240  in first module  216  include an upper first separator  242 , an intermediate second separator  244 , and a lower third separator  246 . Each of these respective separators is coupled to a single well defining their respective gas flow pathways. For example, first well  206   a  is connected via pipeline  208   a  to upper first separator  242 , second well  206   b  is connected via pipeline  208   b  to intermediate second separator  244 , and third well  206   c  is connected via pipeline  208   c  to lower third separator  246 . 
     Each of the separators  242 ,  244 , and  246 , have respective inlets and outlets. A first separator inlet  248   a  permits fossil fuels flowing into first separator  242  and first separator outlet  248   b  carries the separated and extracted fossil fuels out from first separator  242 . A first set of outlet piping  250   a  carries fossil fuel separated in first separator  242  to a combining pipeline  252 . The respective flow stream pathways from well  206   a , well  206   b , and well  206   c  converge in combining and blending pipeline  252 . Notably, each of these respective pathways from a given well remain independent from each other until the gas reaches combining pipeline  252  which is downstream from each respective outlet on the plurality of stacked separators  240 . 
     Intermediate second separator  244  includes an inlet  254   a  and an outlet  254   b . Outlet  254   b  is connected to outlet pipeline  250   b  which connects the intermediate second separator  244  to combining and blending pipeline  252 . Combining and blending pipeline  252  is downstream from outlet  254   b  on intermediate second separator  244 . Lower third separator  246  includes an inlet  256   a  and an outlet  256   b . Outlet  256   b  is coupled to outlet piping  250   c  which is connected to combining pipeline  252 . Combining pipeline  252  is downstream from outlet  256   b  on lower third separator  246 . 
     As is understood in the art, a plurality of valves  258  or secondary filters  259  may be incorporated along the respective outlet discharge pathways of first separator  242 , second separator  244 , and third separator  246  between their respective outlets and their outlet piping. 
     Combining pipeline  252  is depicted as positioned within chamber  234  adjacent first end  208 . However, it is clearly contemplated that this position is not a limitation on system  200 , as one having ordinary skill in the art could easily understand that combining pipeline  252  could be located outside of first module  216 . It may be alternatively be possible to position a combining pipeline upstream from the respective inlets of the plurality of stacked separators and include a manifold device to send combined fossil fuel stream pathways through any one of the stacked separators  242 ,  244 , and  246 . 
     Reference is now made to a first heat exchanger unit which is part of first module  216 . First heat exchanger unit  260  on first module  216  is opposite a second heat exchanging unit  262  on module  218 . The description of first heat exchanger  260  will apply in a similar fashion to second heat exchanger  262 . However, for brevity purposes, only first heat exchanger  260  is described with the understanding that the second module  218  operates in a similar manner to that of first module  216 . 
     First heat exchanger  260  includes at least heat source, at least one fuel line  266 , at least one air intake duct  268 , at least one exhaust stack  270 , at least one fluid filled chamber  272 , and at least one serpentine pipeline  274 . Shown throughout this disclosure, the at least one heat source is identified as burner tube  264  burning fuel from line  266 , however, it is entirely possible that other types of heat sources may be used, such as electrical resistance heat, chemical reactive heat, or others. 
     As generally seen throughout the figures, first heat exchanger  260  is generally associated with first side  212  of gas production unit  202  on first module  216 . However, it is clearly understood that the position of first heat exchanger  260  may be varied according to driller needs and gas processing system  200  will still accomplish its broad goals disclosed herein. 
     As depicted in  FIG. 17A ,  FIG. 18A , and  FIG. 19 , the at least one air intake  268  and the at least one exhaust stack  270  are positioned outside of chamber  234  beyond wall  228 B while still supported by skid frame  230 . Gas production unit  202  may further include a second air intake  276  positioned directly below the at least one air intake  268 . With continued reference to  FIG. 19 , a second burner tube  278  is fed with a second fuel line  280 . Second burner tube  278  is submerged within the fluid filled chamber  272  directly below the at least one burner tube  264 . 
     As depicted in  FIG. 23 , fluid filled chamber  272  may extend vertically from mostly adjacent top wall  228   c  to bottom wall  228   d . Chamber  272  is bound by a portion of top wall  228   c , a portion of bottom wall  228   d , first wall  228   e , and a chamber wall  282  which is located near the mid-portion of width  232  of first module  216 . The plurality of stacked separators  240  are positioned closely adjacent chamber wall  282  and their direct vertical alignment is best seen in  FIG. 23 . 
     With continued reference to  FIG. 23 , the at least one serpentine winding and heat exchanging pipeline  274  submerged in the fluid of fluid filled chamber  272  is depicted as being in an upper portion of the fluid filled chamber  272  above first burner tube  264 . The at least one serpentine heat exchanging pipeline  274  is a portion of the gas flow pathway extending from first wall  206   a  along pipeline  208   a  then into serpentine pipeline  274  then into first gas separator  242 . Stated otherwise, the at least one serpentine heat exchanging pipeline  274  is associated with first gas separator  242  and its fuel contents flowing downstream do not mix with the other serpentine heat exchanging pipeline which will be described in greater detail below. 
     A second serpentine heat exchanging pipeline  284  and a third serpentine heat exchanging pipeline  286  are provided within the fluid filled chamber. Second serpentine heat exchanging pipeline  284  is positioned between first burner tube  264  and second burner tube  278 . The second serpentine heat exchanging pipeline is associated with the second separator  244  and is configured to keep gas warm as it expands and prevents freezing as the fossil fuel moves downstream from second well  206   b  towards second separator  244 . Similarly, third serpentine heat exchanging pipeline  286  is a heat exchanging pipeline submerged in the bath that is associated with third well  206   c  and third separator  246 . The third set of heat exchanging serpentine pipeline  286  is positioned at the lowest portion of the fluid filled chamber  272  closely adjacent bottom wall  228  and beneath both the first burner tube  264  and the second burner tube  278 . Pipelines  274 ,  284 , and  286  keep gas moving therethrough warm as the gas expands and decreases pressure therein to prevent the gas and pipes from freezing. 
     As depicted in  FIG. 22A  and  FIG. 23A , an alternative embodiment may include a heat exchanger  260 A including a plurality of separate and distinct fluid filled chambers. Particularly, a first fluid filled chamber  288 , a second fluid filled chamber  290 , and a third fluid filled chamber  292 . First fluid filled chamber  288  is separated from second fluid filled chamber  290  by a rigid first wall  294 . Second fluid filled chamber  290  is separated from third fluid filled chamber  292  by a second wall  296 . Heat exchanger  260 A may include a plurality of burner tubes equal to the number of fluid filled chambers such that a single burner tube is disposed within a single chamber. As shown in  FIG. 22A  and  FIG. 23A , three burner tubes are provided. A first burner tube  264  is submerged within first fluid filled chamber  288  adjacent first set of heat exchanging serpentine pipeline  274 . A second burner tube  278  is submerged within second fluid filled chamber  290  adjacent second set of heat exchanging serpentine pipeline  284 . A third burner tube  298  is submerged within third fluid filled chamber  292  adjacent third set of heat exchanging serpentine pipeline  286 . Third air intake  277  feeds air to third burner tube  298 . 
     Each burner tube heats the fluid within each distinct chamber to warm the fossil fuel moving downstream through the serpentine pipeline submerged within the fluid of that chamber as the gas expands and decreases pressure. For example, as fossil fuel moves downstream from the first well  206   a  along pipeline  208   a  and through the sand separator  204   a , the fossil fuel then enters first fluid filled chamber  288  within the first set of heat exchanging serpentine pipeline  274 . The first burner tube  264  submerged within the distinctly filled fluid chamber  288  warms the fluid in which heat exchanging serpentine pipeline  274  is submerged. As pressure in the fluid moving downstream along serpentine pipeline  274  is lowered, the heated fluid prevents the fossil fuel moving within pipeline  274  from freezing as the pressure is decreased. 
     As depicted in  FIG. 23B , gas production unit  202  may include an embodiment where only two gas separators are stacked within each modular unit. Particularly, system  200 A includes a first separator  300  and a second separator  302  stacked vertically above one another. In this embodiment, only two sets of serpentine pipeline are contained within fluid filled chamber  272 . Particularly, a first heat exchanging serpentine pipeline  304  finds a pathway in fluid communication with an inlet  306   a  of first separator  300  and an outlet  306   a . Outlet  306   a  may be in fluid communication with outlet piping  308   a  which can lead downstream to another combining pipeline similar to that of combining pipeline  252 . The second separator  302  of system  200 A is directly below first separator  300  and includes an inlet  310   a  and an outlet  310   a . Outlet  310   a  is in fluid communication with outlet piping  308 B which leads downstream to a combining pipeline similar to that of combining pipeline  252 . 
     System  200  may include one or more fluid pumps or impellers or propellers to keep the fluid moving within the heat exchangers. This assists with even heat distribution. 
     Turning back to  FIG. 17C  and  FIG. 18C , first module  216  of gas production unit  202  may be operatively connected to the plurality of sand separators  204 . First sand separator  204   a  may be supported by a frame  310   a , second sand separator  204   b  may be supported by a second frame  310   b , and third sand separator  204   c  may be supported by a third frame  310   c . Each of the sand separating frames may be coupled together via a rigid longitudinally extending cross member  312   a ,  312   b ,  312   c  securing the frames together. 
     As depicted in  FIG. 19  and  FIG. 20 , the plurality of sand separators  204  are positioned laterally outside or outboard or to the right of first side  212  in an assembled position. A width  314  of the plurality of sand separators  204  is equal to or less than the width  232  of first module  216 . Width  314  of the plurality of sand separators  204  is configured to be less than the National Highway Transportation Administration maximum width for an item to be towed by a tractor trailer. This enables the plurality of sand separators to be transported separate from the first module  216  to a well site location and be installed adjacent the first module  216 . 
     Each of the sand separators has an inlet and an outlet. First sand separator  204   a  includes an inlet  316   a  and an outlet  316   b . Outlet  316   b  is connected to pipeline  316   c  which is operatively connected to an inlet  318   a  controlled by a valve  320   a  of the fluid stream pathway associated with the first set of serpentine pipeline  274  and the first gas separator  242 . 
     Second sand separator  204   b  includes an inlet  322   a  and an outlet  322   b  and outlet piping  322   c  in fluid communication with an inlet  318   b  controlled by valve  320   b . Inlet  318   b  controlled by valve  320   b  is part of the second flow stream gas pathway associated with the second set of heat exchanging serpentine pipeline  284  and second gas separator  244 . 
     Third sand separator  204   c  includes and inlet  324   a  and an outlet  324   b . Outlet  324   b  is connected to outlet piping  324   c  which is operatively connected to an inlet  318   c  controlled by a valve  320   c . Inlet  318   c  is operatively connected and in fluid communication with a third set of heat exchanging serpentine pipeline  286  which is connected to third gas separator  246 . 
     In accordance with one exemplary non-limiting aspect the present disclosure, gas processing system  200  comprising transportable gas production unit  202  having first and second modules  216 ,  218  sized to fit atop a flatbed trailer  166  without the need for extra permitting enables significant fossil fuel processing while simultaneously allowing easy installation and removal. 
     A manufacturer assembles the rigid walls of the five-side box-like structure of each module atop a skid frame at a manufacturing location. Once the wall of the box are fabricated, the manufacture may install the pipeline that is associated with the heat exchanger  260 . Alternatively, the heat exchanger pipeline may be fitted between the walls of the box-like housing and the heat exchanger walls during fabrication of the housing. 
     The plurality of stacked separators  240  are then installed within the housing by loading them in through the open side of the housing free of any upstanding vertical wall. Then, the remaining pipeline connections may be connected to established three distinct gas flow pathways associated with the first module. 
     The same assembly is repeated for the second module. After each module has been assembled, the module is loaded onto a flatbed trailer  166  for towing behind a truck. As stated previously, the width of each module is less than the federal maximum width for transporting goods on a highway/freeway/expressway etc. 
     In one embodiment, the first module is loaded onto a first trailer and towed by a first truck to a well site location. The second module is loaded onto a second trailer and towed by a second truck to the well site location such that the two modules arrive at the well site location close in time to each other. Alternatively, if advantageous to the gas producer/operator, a single trailer and truck combination may be used to haul the first and second modules to the well site location. In this scenario, the first truck could tow the first module to the well site location and unload the first module. The first truck would then return to the second module and load it onto the trailer, turn around and deliver the second module to the well site location for unloading adjacent the first module. 
     In a similar manner, the same truck or another set of trucks will deliver the plurality of sand separators  204  to the well site location. The sand separators are also sized to have a width less than the federal maximum permitted for roadway transport. The plurality of sand separators should also be at the well site location before connecting components of gas processing system  200  together to establish the respective production gas flow stream pathways from each well. 
     Now that the first and second modules and the plurality of sand separators have been delivered to the well site location, the assembly of system  200  may begin at the well site location. 
     As stated previously, each module is a five sided box-like structure having a side that is free of any wall. The first and second modules are positioned in a manner such that the free opening side of each module faces the complementary opening on the other module. The modules are mated together in a side-by-side manner forming a longitudinally extending junction  220  running from the first end  209  to the second end  210 . 
     Each end wall in the first and second sidewall forms half of a doorway cutout  328  such that when the first and second modules are mated together in the side-by-side configuration a whole doorway is formed. While not shown directly in the figures, clearly, an access door may fill the formed doorway. 
     Once the first and second modules have been fitted together, the sand separators and the wells may be connected to the gas production unit  202  via pipeline. In one particular embodiment, the well site location plurality of fossil-fuel producing wells at one site location. This may be viewed as a drilling lease on a piece of real property having multiple wells in the real property. Some of the figures depict instances in which the site location has four wells drilled on the property, and other figures depict instances where the site location has six well drilled on the property. Again, the number of wells on the property is clearly variable to suit the needs of a gas producer and are entirely within the real of possibility of the present disclosure. 
     Referring to  FIG. 16 , the first well may be connected via pipeline to the first sand separator. Pipeline may also extend from the first well to a bypass valve or bypass assembly  326  which bypasses the sand separator  204  if the extracted fossil fuel is sufficiently free of sand. Pipeline then connects the sand separator to the heat exchanging serpentine pipeline in the heat exchanger and then to the first gas separator. This downstream connection establishes a first gas flow stream pathway for the fossil fuel to travel from the upstream source of the first well downstream through the first gas separator. 
     Each of the other wells and separators are connected in a similar manner establishing distinct gas flow pathways from the respective upstream source well downstream to a gas separators. 
     Processing system  200  combines the processed gas downstream from each respective gas separator in a combining pipeline  252 . While the combining pipeline is depicted as installed within the housing, clearly it may be exterior to housing, so long as it is downstream from each gas separator. However, it is entirely possible for the combining pipeline to be position upstream from each separator. This type of installation may be advantageous for gas production scenarios in which one well may be producing less fossil fuel than the other wells and the combined pipeline can then be fed into the plurality of stack gas separators to evenly distribute the separating workload performed by the separators. 
     The combining pipeline is then fed to a downstream destination, such as a sales line  226 . The sales line may be connected to the fossil fuel grid/network or it may be fed to a storage tank for later use at the well site location. 
     One exemplary and non-limiting description of a heat exchanger is described in greater detail in co-pending and co-owned U.S. application Ser. No. 14/662,698, filed on Mar. 19, 2015, and in U.S. application Ser. No. 14/662,833, filed on Mar. 19, 2015, and in U.S. application Ser. No. 14/662,929, filed on Mar. 19, 2015, the entirety of each is herein incorporated by reference as if fully rewritten. Namely, in one exemplary embodiment, the burner tube is maintained at a temperature in a range from about 600° F. to about 800° F. This imparts heat to the fluid mixture (glycol, ethylene, and water) in chamber. The fluid mixture is in a range from about 150° F. to 200° F., more particularly in a range from 170° F. to 180° F., and preferably at 175° F. This heated fluid keeps serpentine heat changing pipes at a warm temperature while gas is expanded therein to reduce the pressure from a high first pressure to a lower second pressure. 
     Other examples of gas processing system  200  contemplated by the present disclosure include wherein the first module unit  216  supported by a first frame  230  having a first width  232  and a first length dimensionally sized for transport by a tractor pulled trailer  166  without a wide load permit, and a first set of gas processing devices  240  supported by the first module unit  216 . A second module unit  218  supported by a second frame (not shown for brevity but similar to  232 ) having a second width and a second length dimensionally sized for transport by a second tractor trailer without a wide load permit, and a second set of gas processing devices (not shown for brevity but similar to  240 ) supported by second module unit. Junction  220  directly connecting the first module to the second module. The junction  220  extends lengthwise along the first and second modules  216 ,  218  thereby positioning the first and second modules side-by-side. This exemplary version may further include an assembled array configuration of the first and second set of gas processing devices when viewed from an end; wherein the first set of gas processing devices  240  includes a first gas separator  242  and a second gas separator  244  aligned with each other; and wherein the second set of gas processing devices includes a fourth gas separator (not shown for brevity but similar to  242 ) and a fifth gas separator aligned therewith (not shown for brevity but similar to  244 ). 
     Additionally, system  200  includes a third gas separator  246  and the first, second, and third gas separators  242 ,  244 ,  246  are vertically aligned in a stacked configuration. The second set of gas processing devices in module  218  includes a sixth gas separator (not shown for brevity but similar to  246 ) and the fourth, fifth, and sixth gas separators are vertically aligned in a stacked configuration. 
     System  200  defines a first gas flow pathway directing gas from an first upstream source, such as one of the wells  206   a , to a downstream destination, such as sales pipeline  226 , through the first gas separator  242 . A second gas flow pathway directing gas from a second upstream source, such as one of the wells  206   b , to the downstream destination through the second gas separator  244 . These first and second gas flow pathways are independent and distinct from one another upstream from the first and second gas separators. A merged gas flow pathway formed from blending the first and second flow pathways in combining pipeline  252  is downstream from the first and second gas separators. 
     The sand separators also respectively define portions of the gas flow pathways. For example, first sand separator  204   a  defines a portion of the first gas flow pathway exterior the first module  216 , and second sand separator  204   b  defining a portion of the second gas flow pathway exterior the first module  216 . A bypass assembly  326  is operatively connected to the first and second sand separators, wherein the bypass assembly permits fuel moving downstream along the first pathway to bypass the first sand separator and flow directly from a fuel source to the first gas separator; and the bypass assembly permits fuel moving downstream along the second pathway to bypass the second sand separator and flow directly from a second fuel source to the second gas separator. 
     Exemplary methods of use relating to system  200  may include the steps of pumping fossil fuel from a first well head  206   a  at a well site location along a first gas flow pathway; pumping fossil fuel from a second well head  206   b  at the well site location along a second gas flow pathway; decreasing pressure of the fossil fuel along the first gas flow pathway in a first set of heat exchanging pipeline  274  submerged in heated fluid; decreasing pressure of the fossil fuel along the second gas flow pathway in a second set of heat exchanging pipeline  284  submerged in heated fluid; separating fossil fuel from other constituents along the first gas flow pathway in a first gas separator  242 ; separating fossil fuel from other constituents along the second gas flow pathway in a second gas separator  244 ; wherein the first and second gas separators are housed in a first module and aligned in a vertically stacked configuration, the having a width less than the minimum width requiring a wide/oversized load permit; combining the first and second gas flow pathways downstream, in combining pipeline  252 , from the first and second gas separators. 
     In the foregoing description, certain terms have been used for brevity, clearness, and understanding. No unnecessary limitations are to be implied therefrom beyond the requirement of the prior art because such terms are used for descriptive purposes and are intended to be broadly construed. 
     Moreover, the description and illustration of the preferred embodiment of the disclosure are an example and the disclosure is not limited to the exact details shown or described.