Abstract:
A compact treatment apparatus and methodology is provided for scavenging at least H 2 S from an acid gas stream. The vessel is charged with a batch of an aqueous solution of H 2 S scavenging treatment liquid. Acid gas is discharged from a sparge bar fit with graduated openings, either graduated from small to large or from a few to many and spaced therealong, for distributed discharge into the treatment liquid. The acid gas percolates up through the liquid and into a vessel headspace, the gas being scrubbed of H 2 S for producing a treated discharge gas. The treatment solution can be an aqueous solution of incorporating one of several active H 2 S scavenger ingredients including amine-aldehyde compositions or triazines.

Description:
CROSS REFERENCE TO RELATED APPLICATION 
       [0001]    This application claims the benefit of U.S. Provisional Patent application Ser. No. 61/731,691, filed Nov. 30, 2012, the entirety of which is incorporated herein by reference. 
     
    
     FIELD 
       [0002]    A scrubbers and methodology is provided for removing hydrogen sulphide and volatile organics from a sour gas stream. In particular, sour gas is introduced into a compact vessel, optionally removing moisture, for distribution into an aqueous hydrogen sulphide scavenging solution. 
       BACKGROUND 
       [0003]    In response to an inefficient and environmentally damaging practice of flaring sour emissions, scrubbers have been developed for removing the problematic components for reducing or eliminating the need to store and transfer corrosive and toxic sour material. Scavengers or scrubbers are known for removing components within acid gases including hydrogen sulphide and volatile organic carbons (VOC&#39;s). In particular, scrubbers are used in the treatment of gas streams emanating from produced or stored petroleum, or from produced natural gas stream or from other sources. 
         [0004]    Current processes include amine processes, a variety of towers and various ammonia and iron-related chemical reactions. Applicant has found reluctance in the industry to adopt such process and equipment either due to the high capital cost and poor economics when applied at low gas rates or their unwieldy and inefficient nature, reducing the applicability to marginal gas wells. 
         [0005]    There is a continued need for an apparatus be developed that is both compact and portable allowing effective installation and operation at the source of the sour gas venting or production. Such a method may allow the production of low volume gas wells previously deemed uneconomical. 
       SUMMARY 
       [0006]    Acid gas and VOC removal is efficiently and effectively accomplished by contacting the gas stream with an aqueous solution of an H 2 S scavenging active ingredient purposefully designed to react substantially immediately and selectively with hydrogen sulphide (H 2 S) at about standard atmospheric pressure and at ambient temperatures. Apparatus is disclosed herein for treatment of sour gas at variable rates ranging from about 400 to about 12,000 cubic feet per minute. 
         [0007]    In an embodiment, apparatus is provided comprising closed reaction vessel having a gas inlet and gas outlet, the gas inlet fluidly connected to at least one sparge bar submerged in an engineered H 2 S scavenging solution stored in the vessel, each sparge bar having outlets for substantially distributed discharge of the feedstream into the solution. The sparge bar outlets can be graduated, either graduated from small to large or from a few to many outlets, therealong so as to allow a distributed discharge of gas even as the pressure along the bar diminishes. The gas stream is distributed substantially equally along the sparge bar and into the H 2 S scavenging solution for removal of at least the H 2 S to form a treated discharge stream 
         [0008]    In other embodiments the vessel is divided into a first moisture knockout chamber and a second treatment chamber containing the engineered H 2 S scavenging solution such as an amine-aldehyde based compound or triazine-based solution using primary and secondary amines as catalysts. In one embodiment, the active ingredient in an a H 2 S scavenging is a hexahydro-1 3 5-tris(2-hydroxyethyl)-s-triazine in water, or methanol or both. 
         [0009]    In embodiments, the vessel is a compact, horizontally-extending vessel sized for road transport. A purified or treated discharge stream gas outlet, connected to a headspace above the solution, can in one embodiment comprise a vent stack that can be pivotally connected for movement between a prone transport position and an upright stack position, and in others provide the discharge to subsequent scrubbers  10  downstream equipment. In production operations, the gas outlet can be piped for discharge to downstream equipment such as fuel or gas production lines. 
         [0010]    In an aspect, a method for removing H 2 S from a sour feedstream comprises partially filling the vessel to establish a liquid level of a engineered chemical solution of an active H2S scavenging ingredient in water that selectively reacts with the sour components, introducing the acid gas through the gas inlet and through the sparge bar in the solution which disperses the feedstream throughout and recovering the purified gas stream from the headspace. The headspace or gas outlet can be monitored with a standard gas tech monitor or personal gas detector for evidencing exhaustion of the chemical solution. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0011]      FIG. 1  is a perspective cross-sectional view of an H 2 S scrubber vessel according to one embodiment; 
           [0012]      FIGS. 2A ,  2 B and  2 C are top, side and a cross-section end view of the scrubber according to  FIG. 1 ; 
           [0013]      FIG. 2D  is a plan, cross-sectional view of a sparge bar having graduated sized outlets forked therein; 
           [0014]      FIG. 2E  is a cross-sectional view along a longitudinal axis of the sparge bar according to  FIG. 2D ; 
           [0015]      FIG. 2F  is a plan, cross-sectional view of an alternate sparge bar having graduated groupings of like-size openings; 
           [0016]      FIG. 3  is a perspective cross-sectional view of an H 2 S scrubber vessel according to a second embodiment; 
           [0017]      FIGS. 4A ,  4 B and  4 C are top, side and a cross-section end view of the scrubber according to  FIG. 3 ; 
           [0018]      FIGS. 4D and 4E  are top cross-sectional and side cross-sectional view of the sparge bars according to  FIG. 3 ; 
           [0019]      FIG. 4F  is a side, cross-sectional view of a vent stack having a pivoting stack extension shown upright and in a prone position (dotted lines); 
           [0020]      FIG. 5A  illustrates a side view of two scrubbers arranged in series; 
           [0021]      FIG. 5B  illustrates a top view of two scrubbers arranged in parallel for alternate operation and servicing; and 
           [0022]      FIG. 6  is a perspective side view of an alternate rectangular scrubber and being configured for scrubbing production gas destined for downstream processing or transport. 
       
    
    
     DETAILED DESCRIPTION 
       [0023]    As shown in  FIG. 1  and  FIGS. 2A to 2C , in a first embodiment, a scrubber  10  is shown comprising a horizontally-extending treatment vessel  12  for storing a liquid treatment solution  14 . The vessel  12  lies lengthwise such that its longitudinal axis is substantially horizontal. The vessel is compact and readily transported to site. The treatment solution  14  partially fills the vessel  12  forming a lower treatment portion  16  having a liquid level and a headspace portion  18 . One or more sparge bars  20  extend along a lower portion of the vessel  12  from about a first end  22  of the vessel to about a second end  24  of the vessel. Each sparge bar  20  has an inlet end  26  and a plurality of outlets  28  positioned therealong between the inlet end  26  and a distal end  30 . The plurality of outlets are downward facing for maximizing gas and liquid contact in the lower treatment portion  16 . A gas outlet  32  is positioned at an upper end of the vessel&#39;s headspace for discharging a treated discharge stream. The gas outlet  32  can be located at the second end  24  of the vessel, typically spaced from the inlet end  26  of the sparge bar  20 . 
         [0024]    As shown in the scrubber embodiment of  FIGS. 2A to 2B , the vessel  12  is cylindrical, the first and second ends  22 , 24  being closed with substantially flat end walls. One sparge bar  20  is shown comprising a tube or pipe having the inlet end  26  extending through the vessel&#39;s first end  22  for connection to a source of the sour gas. 
         [0025]    The sparge bar  20  extends to the distal end  30  adjacent the second end  24  of the vessel  12 . The gas outlet  32  is located at a top of the vessel  12  adjacent the second end  24 . A baffle and drip tray  40  is located below and spaced from the gas outlet  32 . The drip tray  40  can extend across a chord of the vessel  12 , sealed along three sides and open to a middle of the headspace portion  18 . Any solution  14  carried over to the gas outlet  32  and coalescing and dripping back down to the headspace  18  can be collected in the drip tray  40 , minimizing re-entrainment, for return to the lower treatment portion or removal. 
         [0026]    The vessel  12  is sized for transport and on-site portability and can include a generally centrally located lifting plate  42  having an eye or clevis connection for ease of picking and placement. The lifting plate  42  is located at about the vessel&#39;s center of gravity. 
         [0027]    As shown in  FIGS. 2D and 2E , the each of the one or more sparge bars  20  can comprise a tubular having a longitudinal axis, the sizing of the outlets  28  being graduated therealong, the outlet area of which increases a first small upstream area to a larger downstream area as the sour gas feedstream is incrementally discharged into the solution and the pressure of the feedstream drops. As the gas is discharged along the sparge bar, the pressure drops; less and less gas being available for discharge from latter outlets and at lower and lower pressures. Therefore the provided outlet area for successive outlets is configured to be larger and larger so as to maintain an even volumetric flow rate therealong. The graduated discharge assists in providing an even volume distribution of gas into the treatment solution within the vessel regardless of the reduction of pressure along the sparger. Examples of graduated discharges include using outlets of incrementally increasing diameter as shown in  FIG. 2D . Three groups of gas outlets are spaced along the sparge bar. With reference to  FIG. 2E , the gas outlets can be arranged threes, directed towards the bottom of the tank, the three outlets being spaced angularly about one quarter of the lower circumference. 
         [0028]    In detail and with reference to  FIG. 2D , the outlets  28  are shown placed in three main groups at intervals along the length of the bar  20 , the number and spacing of the groups dependent upon the process conditions. The respective outlets  28   a , 28   b , 28   c  of each group of outlets  28  has a larger discharge area than the previous group. The diameter of the outlets gradually increase over the length of the at least one sparge bar, where the smallest holes  28   a  start at the proximal or inlet end and increase toward the distal end. Of the three groupings of outlets  28  as one moves from the sparge bar&#39;s inlet end  26  to the distal end  30 , there is a first group of small outlets  28   a  closest to the inlet end  26 , an intermediate group of medium outlets  28   b , and there is a third grouping of larger outlets  28   c  towards the distal end  30 . As shown in  FIGS. 1 and 2D , the outlets  28  are oriented downwards for maximal contact with the treatment solution  14  upon exit. Of course, the number of groups and the sizing is a matter of design dependent upon factors including the sour gas inlet pressure, the flow rate, and the solution liquid head or backpressure. In another embodiment of  FIG. 2E , one can provide ever more dense or concentrated spaced groupings of like-sized outlets  28  for providing the increased outlet area as one moves from the sparge bar&#39;s inlet end  26  to the distal end  30 . Further one can use a combination of outlet size and numbers of outlets. The graduated discharge increases the effectiveness of the diminishing gas distribution as compared to using an even distribution of same-sized outlets all along the sparge bar  20 . In an embodiment, the particular form of the groupings can be a result of manufacturing efficiency to minimize handling of the bar during drilling. 
         [0029]    A Hydrogen Sulphide Scavenger (HSS) forms the active chemical or ingredient in the engineered treatment H 2 S Scavenger solution to chemically react with contaminants in the acid gas feedstream, including H 2 S and volatile organic carbons, to eliminate sulphides, aromatic hydrocarbons and basic noxious odors in the treated discharge stream. 
         [0030]    In embodiments, the active ingredient is an amine-based compositions for sulfur scavenging are employed. The compositions are liquid and will form aqueous solutions for use in the disclosed systems for scrubbing gas streams. 
         [0031]    In an embodiment, the HSS active ingredient selected from the group of triazine compositions are applicable such as those commercially available HSS such as Sulfa Clear® 8411C, is used, Sulfa Clear® being a registered trademark of Clearwater, Inc. and available from Weatherford International Ltd. The constituents of the HSS are set forth in U.S. Pat. No. 5,128,049 to Clearwater International, L.L.C. according to the patent disclosure, basically, the HSS is selected from the group consisting of: hexahydro-1,3,5-tris(2-hydroxyethyl)-s-Triazine; tris(hydroxylmethyl)nitromethane; a mixture of 4-(2-nitrobutyl)morpholine and 4,4′-(2-ethyl-2-nitrotrimethylene)-dimorpholine; a mixture of 4,4-dimethyloxazolidine and 3,4,4-trimethyloxazolidine; hexahydro-1,3,5-triethyl-s-triazine; a mixture of sodium 2-pyridinethiol-1-oxide and hexahydro-1,3,5-tris(2-hydroxyethyl)-s-triazine; 2,2-dibromo-3-nitrilopropionamide; methanol [[[2-(dihydro-5-methyl-3(2H)-oxazolyl)-1-methylethyoxy]methoxy]methoxy]; 2[(hydroxymethyl)amino]ethanol; 2[(hydroxymethyl)amino]-2-methyl-propanol; sodium dichloro-s-triazinetrione dihydrate; or 1-(hydroxymethyl)-5,5 dimethylhydantoin. 
         [0032]    In another embodiment, the HSS active ingredient comprises a chemical derived from the reaction of aldehyde and amines some of which also present as including a triazine, others not having triazine. One method for producing the HSS active chemical is as set forth in U.S. Pat. No. 8,092,431 to Falana et al. and assigned to Clearwater International LLC, Houston Tex. As disclosed therein, amine-aldehyde sulfur scavenging compositions are formed contacting an aldehyde-containing-component, including for example a formaldehyde-containing-component, with an amine-containing-component the presence of an alcohol and specified conditions to produce an amine-aldehyde adduct product that does not form a solid, nor gel. 
         [0033]    The HSS active ingredient can be diluted in water, with methanol or both. A typical triazine HSS (Sulfa Clear® 8411C) has a dilution ratio of about 50% HSS, 5% methanol, and 45% water to form the treatment solution. The solution can also act as a water-soluble corrosion inhibitor for mild steel in acidic environments. Methanol aids in freeze-protection. 
         [0034]    The amount of HSS active ingredient is dependent on the application and the level of H 2 S present. For gas applications, such as to treat sour vent gas, the scavenging rate is about 0.01 to about 0.03 litres of HSS chemical per ppm H 2 S per thousand cubic meters of inlet solution. 
         [0035]    Advantages of amine-aldehyde and triazine-based HSS active ingredients include that they are water soluble, can be used in gas scrubbers and continuous injection systems, are biodegradable and control H 2 S even in presence of CO 2 . 
         [0036]    With reference to  FIGS. 3 ,  4 A to  4 C, in another embodiment, the vessel  12  is divided into a first and second chambers  50 , 52  by a barrier  54  across the interior of the closed vessel. The first chamber  50  functions to knock out moisture from the acid gas, drying the gas prior to the dried acid gas making contact with the aqueous solution. As a result of the first chamber  50 , the dried acid gas is about 98% dry. 
         [0037]    In this embodiment, higher rates of gas flow or higher concentrations of H 2 S are treated, and as shown, the at least one sparge bar comprises three sparge bars  20 , 20 , 20 , the number and size being related to the inlet pressure, the flow rate and the backpressure of the vessel  12 . 
         [0038]    The first chamber  50  collects any liquid that may drop out of the gas stream. A gas inlet  56  is located near the top of the vessel  12 , elevated above and clear of any liquid, primarily water, to collect at the bottom of the first chamber and be subsequently drained. The second chamber  52  is partially filled with the engineered treatment solution. 
         [0039]    The three sparge bars  20 , 20 , 20  have their inlets  26  located in the first chamber  50 , isolated from the treatment solution by the barrier  54 . Each inlet  26  is elevated by extension conduit  58  to an elevation above any liquid, acting as a snorkel and directing dry sour gas down the conduit  58  into the sparge bars  20 . The sparge bars  20  pass sealably through the barrier  54  and extends horizontally along and spaced from bottom of the vessel to the distal end  30 . The sparge bars  20  are located along the bottom of the tank to place the largest volume of the treatment solution  14  above the sparge bar  20 , providing efficient contact time between the solution and the acid gas stream. 
         [0040]    As shown in  FIGS. 4D and 4E , and as stated earlier and in  FIG. 2E , each of the sparge bars  20  comprises outlets  28  along the bottom of the bar  20 . Referring to  FIG. 4D , and in this embodiment, approximately three groupings of holes are spaced along the bar and groups of three outlets are located circumferentially about one quarter of the bar&#39;s circumference ( FIG. 2E ) and located at intervals along the length of the bar ( FIGS. 4D ,  4 E). In an embodiment, the form of the groupings can be a result of manufacturing efficiency to minimize handling of the bar  20  during drilling. The outlets are arranged such that they face the bottom of the tank ( FIG. 4E ). The diameter of the outlets increases over the length of the sparge bars  20 , where the smallest outlets start at the inlet end  26  and increase toward the distal end  30 . 
         [0041]    The scrubber system  10  is designed to use either carbon steel or, if desired, more costly  316  stainless steel. The flow rate the inlet sour gas stream can be constant or variable without any negative effect on the scrubber. Ball valves are placed on the gas inlet, as required, to ensure the desired flow for the system and maintain a pressure rating below standard atmospheric pressure. 
         [0042]    With reference to  FIG. 4F , a restrictor basket  60  is placed in the gas outlet  30  of each scrubber  10  to capture any carry-over of treatment solution and to provide backpressure to enhance contact time between the acid gas and the aqueous HSS treatment solution, providing additional chemical reaction options for the elimination of volatile organic carbons as well as to disperse the outgoing sweetened gas to provide an even flow. A backpressure of about 6 to about 7 ounces is suitable. The outlet  32  further comprises a stack  62 , for discharging treated natural gas. The drip tray  40  in the tank and adjacent the outlet  32  is provided for the collection of any aqueous solution that has been carried over into the stack with the outgoing gas stream, captured at the restrictor basket  60  and deposited back into the vessel  12 . 
         [0043]    As shown in  FIG. 4H , the gas outlet  32  can be fit with stack  62  for removing treated natural gas. The stack may further comprise a hinge  64  for laying a portion of the stack in a horizontal position, for transport or if the stack is not required for the particular site. 
         [0044]    The depth of the treatment solution  14  is similarly maintained for establishing a hydraulic head to provide a backpressure, but not so as to arrest flow or adversely affect upstream equipment. 
         [0045]    With reference to  FIG. 5A , two or more scrubber vessels  12  can be operated in series so as to permit stages removal of H 2 S, the discharge of a first scrubber  10  being directed from outlet  32  into the inlet  26  of a subsequent scrubber  10 . The last of the subsequent scrubbers is fit with stack  62  or plumbed into downstream equipment. 
         [0046]    As stated, the system can be operated in a batch manner, the treatment solution being used until the HSS active ingredient remaining is no longer effective to remove H 2 S. The system is then taken offline to refresh the treatment solution. 
         [0047]    With reference to  FIG. 5B , parallel vessels  12 , 10  or systems can be used in alternating operation to ensure continuous gas processing while one vessel  12  is offline for HSS renewal. 
         [0048]    With reference to  FIG. 6  an alternate rectangular scrubber is configured for scrubbing production gas destined for downstream processing or transport. The vessel  12  discharges treated gas from gas outlet  32  to a pump  66  or other apparatus for elevating the pressure suitable for downstream equipment (not shown). 
       EXAMPLES 
       [0049]    The embodiments described in the following four examples are capable of treating Acid Gas Streams (AGS), such as sour Raw Natural Gas (RNG) at flow rates ranging from approximately 400 cfm to about 12,000 cfm at common concentrations of H 2 S with the standard ranging from approximately 2,000 ppm to 80,000 ppm. Examples of performance parameters of various embodiments of the described scrubber are provided in Tables 1, 2 and 3 below. 
         [0050]    With reference to  FIGS. 1 and 2A  through  2 F, in one embodiment, scrubber vessel  12  is provided for treating a vapour stream such as Raw Natural Gas (RNG) for the removal of odorous portions of acid gases, including hydrogen sulphide and volatile organic carbons. Typically the AGS arrives for the wellhead or earlier equipment at pressures less that 5 psig. 
         [0051]    The process is simply and conveniently operated as a batch process. Turning to  FIGS. 1 ,  2 D and  2 E, a vessel  12  is a 3′-2″ diameter, 6 foot long cylindrical tank of ¼″ thick steel. The vessel is fit with 3½″ diameter tubular sparge bar  20  that is 5′-10″ long, formed of 106 carbon steel. The sparge bar  20  extends approximately the full the length of the inside of the 10 vessel terminating adjacent the vessel&#39;s second end  24 . The sparge bar can have relief holes at the end to avoid accumulating stagnant solution therein. An HSS solution  14  of Sulfa Clear® 8411C has a liquid level of about 14″ for a hydrostatic backpressure of about 8.5 ounces. The sparge bar  20  was completely submersed in the treatment solution  14 . The vessel can accept a nominal gas flow rates of in the order of up to about 1600 cfm. 
         [0052]    The sparge bar  20  has three sets or groupings of gas outlets  28  spaced therealong. The first set of outlets are forty-five (45) ⅛″ diameter holes in 15 sets of triple drilled holes. The intermediate set of outlets comprises twenty-six (26) 3/16″ holes in 12 sets of triple drilled holes. The third and last set of outlets comprises Fifty-one (51) ¼″ holes in 17 sets of triple drilled holes. The sparge bar  20  is spaced about 4″ from the bottom the vessel. The gas outlet  32  was a 10″ diameter stack about 3′ tall. 
         [0053]    In a first example, the inlet  26  accepts an acid gas stream (AGS) of about 700 cfm at a predetermined inlet pressure being at least high enough to overcome the hydrostatic pressure of the HSS. The AGS flows into the at least one sparge bar  20  and out of the outlet holes  28  provided therein. As the AGS exits the sparge bar and traverses the HSS, the corrosive and detrimental molecules of the acid gas are removed. The treated gas flows through the gas outlet  32  whereby it can be vented to atmosphere or routed or collected in downstream equipment as a product such as a fuel source. 
         [0054]    As shown in Tables 1 and 2 for example operations a Examples 1 and 2, inlet stream containing 2,000 ppm of H 2 S was treated with analysis of the gas discharging at the gas outlet  32  having 0 ppm H 2 S. 
         [0000]    
       
         
               
             
               
               
               
               
               
             
           
               
                 TABLE 1 
               
             
             
               
                   
               
               
                 Example #1 
               
               
                 Flow = 700 cfm; H 2 S Concentration = 2,000 ppm 
               
             
          
           
               
                 Time Interval 
                 Flow 
                 Inlet 26 
                 Outlet 32 
                 Ambient 
               
               
                 Hours 
                 cfm 
                 Ppm 
                 ppm 
                 Temp C. 
               
               
                   
               
               
                 0 
                 700 
                 2000 
                 0 
                 20 
               
               
                 1 
                 700 
                 2000 
                 0 
                 20 
               
               
                 2 
                 700 
                 2000 
                 0 
                 21 
               
               
                 4 
                 700 
                 2000 
                 0 
                 21 
               
               
                   
               
             
          
         
       
     
         [0000]    
       
         
               
             
               
               
               
               
               
             
               
               
               
               
               
             
           
               
                 TABLE 2 
               
             
             
               
                   
               
               
                 Example #2 
               
             
          
           
               
                 Time Interval 
                 Flow 
                 Inlet 26 
                 Outlet 32 
                 Ambient 
               
               
                 Hours 
                 cfm 
                 Ppm 
                 ppm 
                 Temp C. 
               
               
                   
               
             
          
           
               
                 0 
                 700 
                 2000 
                 0 
                 23 
               
               
                 1 
                 700 
                 2000 
                 0 
                 23 
               
               
                 2 
                 700 
                 2000 
                 0 
                 25 
               
               
                 4 
                 700 
                 2000 
                 0 
                 28 
               
               
                 8 
                 700 
                 2000 
                 0 
                 28 
               
               
                 10 
                 700 
                 2000 
                 0 
                 26 
               
               
                   
               
             
          
         
       
     
         [0055]    With reference to  FIGS. 3 and 4A  to  4 E, in a second embodiment, flow rates of 1600 cfm were tested at high H 2 S concentrations. In this embodiment, the scrubber  10  utilizes the same sized vessel  12  as in the first embodiment, being 3′-2″ diameter by 6 feet long. In this embodiment, the vessel was fit with three, 3½″ diameter tubular sparge bars  20 . Again, the treatment solution  14  had a liquid level of about 14″ for a hydrostatic backpressure of about 8.5 ounces. The three sparge bars  20 , 20 , 20  were completely submersed in the treatment solution  14 . The sparge bar  20  has three sets or groupings of gas outlets  28  as was the case of the single bar of the 700 cfm examples. 
         [0056]    In Examples 3 and 4, the inlet  26  received 1,600 cfm of AGS at a predetermined inlet pressure. The AGS flowed into the first chamber  50  of the vessel  12  where liquids, such as entrained water, suspended in the AGS, separated from the gas stream and collected in a sump at the bottom of the first chamber  50 . The chamber was periodically drained. The dry AGS entered the elevated inlets  26  of the snorkels  58  of the three sparge bars and flowed into the second chamber  52 , traversing the HSS solution  14  for removal of noxious components. The treated gas flows through the gas outlet  32 . 
         [0057]    As shown in Tables 3 and 4 for operations in Examples 3 and 4, inlet stream containing 60,000 and 80,000 ppm of H 2 S respectively was treated, with analysis of the gas discharging at the gas outlet  32  having between 0 and 5 ppm H 2 S. 
       Example #3 
     Flow=1,600 cfm; H 2 S Concentration=60,000 
       [0058]      
         [0000]    
       
         
               
               
               
               
               
             
           
               
                   
               
               
                 Time Interval 
                 Flow 
                 Inlet 26 
                 Outlet 32 
                 Ambient 
               
               
                 Hours 
                 Cfm 
                 ppm 
                 ppm 
                 Temp C. 
               
               
                   
               
             
             
               
                 0 
                 1600 
                 60000 
                 0 
                 18 
               
               
                 1 
                 1600 
                 60000 
                 2 
                 18 
               
               
                 2 
                 1600 
                 60000 
                 2 
                 18 
               
               
                 4 
                 1600 
                 60000 
                 3 
                 18 
               
               
                 8 
                 1600 
                 60000 
                 5 
                 18 
               
               
                   
               
             
          
         
       
     
       Example #4 
     Flow=1,600 cfm; H 2 S Concentration=80,000 
     Example #4 
       [0059]      
         [0000]    
       
         
               
               
               
               
               
             
           
               
                   
               
               
                 Time Interval 
                 Flow 
                 Inlet 26 
                 Outlet 32 
                 Ambient 
               
               
                 Hours 
                 Cfm 
                 ppm 
                 ppm 
                 Temp C. 
               
               
                   
               
             
             
               
                 0 
                 1600 
                 80000 
                 0 
                 24 
               
               
                 1 
                 1600 
                 80000 
                 0 
                 24 
               
               
                 2 
                 1600 
                 80000 
                 0 
                 26 
               
               
                 4 
                 1600 
                 80000 
                 1 
                 26 
               
               
                 8 
                 1600 
                 80000 
                 4 
                 25 
               
               
                   
               
             
          
         
       
     
         [0060]    As shown in  FIG. 6 , and in a fifth example, a high capacity, yet portable vessel  12  that has a size that still fits within transport requirements and limits is a 10′ by 10′ by 16′ long square vessel  12  capable of treating gas rates in the order of about 11,000 cfm.