Patent Publication Number: US-2018051929-A1

Title: System and Method to Integrate Condensed Water with Improved Cooler Performance

Description:
REFERENCE TO RELATED APPLICATIONS 
     This application claims the priority benefit of U.S. Patent Application No. 62/375,705 filed Aug. 16, 2016 entitled SYSTEM AND METHOD TO INTEGRATE CONDENSED WATER WITH IMPROVED COOLER PERFORMANCE, the entirety of which is incorporated by reference herein. 
     This application is related to U.S. Provisional Patent Application No. 62/375,700 entitled “SYSTEM AND METHOD FOR LIQUEFYING NATURAL GAS WITH TURBINE INLET COOLING”, having a common assignee as this application and filed on the same day herewith. The disclosure of this related application is incorporated by reference herein in its entirety. 
    
    
     BACKGROUND 
     Field of Disclosure 
     The disclosure relates generally to gas turbines, and more particularly, to inlet air cooling of a gas turbine or another process component. 
     Description of Related Art 
     This section is intended to introduce various aspects of the art, which may be associated with the present disclosure. This discussion is intended to provide a framework to facilitate a better understanding of particular aspects of the present disclosure. Accordingly, it should be understood that this section should be read in this light, and not necessarily as an admission of prior art. 
     Many industrial processes use a gas turbine or turbines to generate power or drive a mechanical load. For example, hydrocarbon production facilities use combustion gas turbines to drive the compressors needed to refrigerate the natural gas from a gaseous to a liquid state. More specifically, LNG production facilities typically use two or more refrigeration circuits to at least pre-chill the incoming natural gas and then to liquefy it. Often the use of the various refrigeration circuits in these facilities is not optimized and spare refrigeration capacity in one or more of the refrigeration circuits cannot be fully used for all operating conditions. 
     Operating at a wide range of ambient temperatures may be a factor that can result in such an imbalance of the various refrigeration circuits. 
     Further, the combustion gas turbine drivers are also sensitive to ambient temperature and can lose about 0.7% of available power for each 1 degree Celsius increase of the ambient temperature. This means that most LNG plants have to be significantly overdesigned to ensure the required horsepower is available regardless of ambient temperature. 
     U.S. Pat. No. 6,324,867 to Fanning, et al. describes a system and method to liquefy natural gas that utilizes the excess refrigeration capacity in one refrigeration circuit to chill the inlet air for the gas turbine driver or drivers of another refrigeration circuit and thus increase the overall capacity of the LNG plant. The disclosure of Fanning is incorporated by reference herein in its entirety. By maintaining the inlet air for the turbines at a substantially constant low temperature, the amount of power generated by the turbines remains at a high level regardless of the ambient air temperature. This allows the LNG plant to be designed for more capacity and allows the plant to operate at a substantially constant production rate throughout the year. Further, since the system of Fanning uses the first refrigerant circuit, for example a circuit comprising propane as a refrigerant, already present in LNG systems of this type, no addition cooling source is required. 
     U.S. Pat. No. 8,534,039 to Pierson, et al. describes using moisture condensed via gas turbine inlet air chilling for psychometric cooling to improve the performance of an organic Rankine cycle condenser and refrigerant condenser. This refrigerant condenser is part of the system that provides the gas turbine inlet air chilling. In Pierson, the condensed moisture is collected in a basin located below a wet air fin cooler and a pump sprays the collected water onto the tubes of the air fin. Pierson also describes adding makeup water to maintain a minimum level in the basin. It is desired, however, to provide a such a cooling system that does not require the use of a basin as disclosed in Pierson, and that minimizes possible contamination of the cooling water from atmospheric contaminants. 
     SUMMARY 
     The present disclosure provides a method for cooling a process fluid according to disclosed aspects. An inlet air stream of a turbine is cooled with an inlet air cooling system. Moisture contained in the cooled inlet air stream is condensed and separated from the cooled inlet air stream to produce a water stream in an open-loop circuit. The water stream is sprayed into an air cooler air stream. The combined air cooler air stream and sprayed water stream is directed through an air cooler. Heat is exchanged between the process fluid and the combined air cooler air stream and sprayed water stream to thereby condense, chill, or sub-cool the process fluid. 
     The present disclosure also provides a system for cooling a process fluid in a hydrocarbon process processing natural gas to produce liquefied natural gas. A chiller is located at an inlet of a gas turbine. The chiller is configured to chill an inlet air stream from about its dry bulb temperature to a temperature below its wet bulb temperature. A separator is located downstream of the chiller and is configured to separate water in the chilled inlet air stream and produce a water stream in an open-loop circuit. A wet air fin cooler combines the water stream with an air cooler air stream to condense, chill, or sub-cool the process fluid passing through the wet air fin cooler. 
     The present disclosure also provides a method for cooling a process fluid. An inlet air stream of a process component is cooled with an inlet air cooling system. Moisture contained in the cooled inlet air stream is condensed. The moisture is separated from the cooled inlet air stream to produce water stream in an open-loop circuit. The water stream is sprayed into an air cooler air stream. The combined air cooler air stream and sprayed water stream is directed through an air cooler. Heat is exchanged between the process fluid and the combined air cooler air stream and sprayed water stream to thereby condense, chill, or sub-cool the process fluid. 
     The foregoing has broadly outlined the features of the present disclosure so that the detailed description that follows may be better understood. Additional features will also be described herein. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       These and other features, aspects and advantages of the disclosure will become apparent from the following description, appending claims and the accompanying drawings, which are briefly described below. 
         FIG. 1  is a schematic diagram of an LNG liquefaction system according to aspects of the present disclosure. 
         FIG. 2  is a schematic diagram of a detail of  FIG. 1  according to aspects of the present disclosure. 
         FIG. 3  is a schematic diagram of an inlet air cooling system used with an LNG liquefaction system according to aspects of the present disclosure. 
         FIG. 4  is a graph showing the relation between refrigeration duty of a chiller, gas turbine inlet air temperature, and ambient air flow rate as a percentage of base air flow, according to aspects of the present disclosure. 
         FIG. 5  is a schematic diagram of an inlet air cooling system according to aspects of the present disclosure. 
         FIG. 6  is a method according to aspects of the present disclosure. 
     
    
    
     It should be noted that the figures are merely examples and no limitations on the scope of the present disclosure are intended thereby. Further, the figures are generally not drawn to scale, but are drafted for purposes of convenience and clarity in illustrating various aspects of the disclosure. 
     DETAILED DESCRIPTION 
     To promote an understanding of the principles of the disclosure, reference will now be made to the features illustrated in the drawings and specific language will be used to describe the same. It will nevertheless be understood that no limitation of the scope of the disclosure is thereby intended. Any alterations and further modifications, and any further applications of the principles of the disclosure as described herein are contemplated as would normally occur to one skilled in the art to which the disclosure relates. For the sake of clarity, some features not relevant to the present disclosure may not be shown in the drawings. 
     At the outset, for ease of reference, certain terms used in this application and their meanings as used in this context are set forth. To the extent a term used herein is not defined below, it should be given the broadest definition persons in the pertinent art have given that term as reflected in at least one printed publication or issued patent. Further, the present techniques are not limited by the usage of the terms shown below, as all equivalents, synonyms, new developments, and terms or techniques that serve the same or a similar purpose are considered to be within the scope of the present claims. 
     As one of ordinary skill would appreciate, different persons may refer to the same feature or component by different names. This document does not intend to distinguish between components or features that differ in name only. The figures are not necessarily to scale. Certain features and components herein may be shown exaggerated in scale or in schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. When referring to the figures described herein, the same reference numerals may be referenced in multiple figures for the sake of simplicity. In the following description and in the claims, the terms “including” and “comprising” are used in an open-ended fashion, and thus, should be interpreted to mean “including, but not limited to.” 
     The articles “the,” “a” and “an” are not necessarily limited to mean only one, but rather are inclusive and open ended so as to include, optionally, multiple such elements. 
     As used herein, the terms “approximately,” “about,” “substantially,” and similar terms are intended to have a broad meaning in harmony with the common and accepted usage by those of ordinary skill in the art to which the subject matter of this disclosure pertains. It should be understood by those of skill in the art who review this disclosure that these terms are intended to allow a description of certain features described and claimed without restricting the scope of these features to the precise numeral ranges provided. Accordingly, these terms should be interpreted as indicating that insubstantial or inconsequential modifications or alterations of the subject matter described and are considered to be within the scope of the disclosure. 
     The term “heat exchanger” refers to a device designed to efficiently transfer or “exchange” heat from one matter to another. Exemplary heat exchanger types include a co-current or counter-current heat exchanger, an indirect heat exchanger (e.g. spiral wound heat exchanger, plate-fin heat exchanger such as a brazed aluminum plate fin type, shell-and-tube heat exchanger, etc.), direct contact heat exchanger, or some combination of these, and so on. 
     The present disclosure is a system and method of using an open loop circuit of the condensed water collected in an inlet air cooler (IAC), and transferring the water to a wet air fin cooler to increase the effective heat transfer relative to a traditional fin fan cooler with no water spray. The disclosed method and system results in improved overall process efficiency. The water condensed downstream of at least one filter element in an IAC is expected to be chilled and generally clean, but additional water treatment may be required in the water spray system to reduce corrosion, biological growth, and the like. 
     In an aspect of the disclosure, the disclosed system and method may be used in any process that uses a gas turbine, such as (for example) air separation, pharmaceutical processing, integrated gasification combined cycle power plants, other power generation processes, pharmaceutical manufacturing, organic and/or non-organic chemical manufacturing, other processes in the oil and gas industry, and the like. As a non-limiting example, the disclosed system may be used in a natural gas liquefaction process where using the excess refrigeration capacity in one refrigeration circuit to chill the inlet air for the gas turbine driver or drivers of another refrigeration circuit, and thus increase the overall capacity of an LNG plant. The disclosed aspects improve upon previous solutions in which moisture condensed via gas turbine inlet air chilling is used for psychometric cooling to improve the performance of a refrigerant condenser that forms part of the system that provides the gas turbine inlet air chilling. Such previous solutions collected condensed moisture in a basin located below a wet air fin cooler and sprayed the collected water onto the tubes of the air fin. According to aspects of the present disclosure, no basin is required to collect condensed moisture, and essentially all of the moisture collected from the gas turbine inlet air chilling system is subsequently vaporized within the wet air fin air stream to minimize overspray. The condensed moisture is collected downstream of at least one air filter element within the gas turbine air inlet to minimize contamination of the water by atmospheric contaminants. Each of these measures is intended to minimize the risk of corrosion and fouling of the wet air fin device, the gas turbine inlet air chiller and the gas turbine inlet air moisture separation device. Furthermore, optional control of the air flow to the wet air fin via adjustable fan speed, pitch, louvers, or the like, can be used to improve the air fin performance by trading between lower air temperature due to psychometric cooling at lower air flows and velocities vs. higher air temperature and higher velocities. 
     The present disclosure improves upon known cooling systems by sub-cooling the refrigerant slipstream used for gas turbine inlet air chilling, and further by using psychometric cooling using moisture condensed during the inlet air chilling to improve the performance of this refrigerant sub-cooling. 
       FIGS. 1 and 2  illustrate a system  10  and process for liquefying natural gas (LNG) according to aspects of the present disclosure. It is to be understood that system  10  is a non-limiting example of how the disclosed aspects may be applied. In system  10 , feed gas (natural gas) enters through an inlet line  11  into a preparation unit  12  where it is treated to remove contaminants. The treated gas then passes from preparation unit  12  through a series of heat exchangers  13 ,  14 ,  15 ,  16 , where it is cooled by evaporating the first refrigerant (e.g. propane) which, in turn, is flowing through the respective heat exchangers through a first refrigeration circuit  20 . The cooled natural gas then flows to fractionation column  17  wherein pentanes and heavier hydrocarbons are removed through line  18  for further processing in a fractionating unit  19 . 
     The remaining mixture of methane, ethane, propane, and butane is removed from fractionation column  17  through line  21  and is liquefied in the main cryogenic heat exchanger  22  by further cooling the gas mixture with a second refrigerant that may comprise a mixed refrigerant (MR) which flows through a second refrigeration circuit  30 . The second refrigerant, which may include at least one of nitrogen, methane, ethane, and propane, is compressed in compressors  23   a,    23   b  which, in turn, are driven by a process component such as a gas turbine  24 . After compression, the second refrigerant is cooled by passing through air or water coolers  25   a,    25   b  and is then partly condensed within heat exchangers  26 ,  27 ,  28 , and  29  by the evaporating the first refrigerant from first refrigerant circuit  20 . The second refrigerant may then flow to a high pressure separator  31 , which separates condensed liquid portion of the second refrigerant from the vapor portion of the second refrigerant. The condensed liquid and vapor portions of the second refrigerant are output from the high pressure separator  31  in lines  32  and  33 , respectively. As seen in  FIG. 1 , both the condensed liquid and vapor from high pressure second refrigerant separator  31  flow through main cryogenic heat exchanger  22  where they are cooled by evaporating the second refrigerant. 
     The condensed liquid stream in line  32  is removed from the middle of main cryogenic heat exchanger  22  and the pressure thereof is reduced across an expansion valve  34 . 
     The now low pressure second refrigerant is then put back into the main cryogenic heat exchanger  22  where it is evaporated by the warmer second refrigerant streams and the feed gas stream in line  21 . When the second refrigerant vapor stream reaches the top of the main cryogenic heat exchanger  22 , it has condensed and is removed and expanded across an expansion valve  35  before it is returned to the main cryogenic heat exchanger  22 . As the condensed second refrigerant vapor falls within the main cryogenic heat exchanger  22 , it is evaporated by exchanging heat with the feed gas in line  21  and the high pressure second refrigerant stream in line  32 . The falling condensed second refrigerant vapor mixes with the low pressure second refrigerant liquid stream within the middle of the main cryogenic heat exchanger  22  and the combined stream exits the bottom of the main cryogenic heat exchanger  22  as a vapor through outlet  36  to flow back to compressors  23   a,    23   b  to complete second refrigeration circuit  30 . 
     The closed first refrigerant circuit  20  is used to cool both the feed gas and the second refrigerant before they pass through main cryogenic heat exchanger  22 . The first refrigerant is compressed by a first refrigerant compressor  37  which, in turn, is powered by a process component such as a gas turbine  38 . The first refrigerant compressor  37  may comprise at least one compressor casing and the at least one casing may collectively comprise at least two inlets to receive at least two first refrigerant streams at different pressure levels. The compressed first refrigerant is condensed in one or more condensers or coolers  39  (e.g. seawater or air cooled) and is collected in a first refrigerant surge tank  40  from which it is cascaded through the heat exchangers (propane chillers)  13 ,  14 ,  15 ,  16 ,  26 ,  27 ,  28 ,  29  where the first refrigerant evaporates to cool both the feed gas and the second refrigerant, respectively. Both gas turbine systems  24  and  38  may comprise air inlet systems that in turn may comprise air filtration devices, moisture separation devices, chilling and/or heating devices or particulate separation devices. 
     Means may be provided in system  10  of  FIG. 1  for cooling the inlet air  70 ,  71  to both gas turbines  24  and  38  for improving the operating efficiency of the turbines. Basically, the system may use excess refrigeration available in system  10  to cool an intermediate fluid, which may comprise water, glycol or another heat transfer fluid, that, in turn, is circulated through a closed, inlet coolant loop  50  to cool the inlet air to the turbines. 
     Referring to  FIG. 2 , to provide the necessary cooling for the inlet air  70 ,  71 , a slip-stream of the first refrigerant is withdrawn from the first refrigeration circuit  20  (i.e. from surge tank  40 ) through a line  51  and is flashed across an expansion valve  52 . Since first refrigeration circuit  20  is already available in gas liquefaction processes of this type, there is no need to provide a new or separate source of cooling in the process, thereby substantially reducing the costs of the system. The expanded first refrigerant is passed from expansion valve  52  and through a heat exchanger  53  before it is returned to first refrigeration circuit  20  through a line  54 . The propane evaporates within heat exchanger  53  to thereby lower the temperature of the intermediate fluid which, in turn, is pumped through the heat exchanger  53  from a storage tank  55  by pump  56 . 
     The cooled intermediate fluid is then pumped through air chillers or coolers  57 ,  58  positioned at the inlets for turbines  24 ,  38 , respectively. As inlet air  70 ,  71  flows into the respective turbines, it passes over coils or the like in the air chillers or coolers  57 ,  58  which, in turn, chill or cool the inlet air  70 ,  71  before the air is delivered to its respective turbine. The warmed intermediate fluid is then returned to storage tank  55  through line  59 . Preferably, the inlet air  70 ,  71  will be cooled to no lower than about 5° Celsius (41° Fahrenheit) since ice may form at lower temperatures. In some instances, it may be desirable to add an anti-freeze agent (e.g. ethylene glycol) with inhibitors to the intermediate fluid to prevent plugging, equipment damage and to control corrosion. 
     One aspect of the present disclosure is illustrated in detail in  FIG. 2 , in which a wet air fin cooler  104  is connected to the first refrigeration circuit  20 . As used with the present disclosure, wet air fin cooler  104  combines the cooling effectiveness of (a) a conventional air fin heat exchanger, which may use a fan  108  to pass ambient air over finned tubes through which pass the fluid (e.g. liquid or gas) to be cooled to near ambient temperature (e.g. dry bulb temperature), with (b) psychometric cooling by vaporizing a liquid, typically water, within the ambient air stream using, for example, nozzles  110  in a spray header  112 , to approach the lower wet bulb temperature of the ambient air. 
     Wet air fin cooler  104  is used to sub-cool the slip-stream of liquid first refrigerant in line  51  from surge tank  40 . The sub-cooled first refrigerant is directed through line  105  to heat exchanger  53 . Sub-cooling this propane increases both the refrigeration duty of heat exchanger  53  and the coefficient of performance of the refrigeration system. This coefficient of performance is the ratio of the refrigeration duty of the heat exchanger  53  divided by the incremental compressor power to provide that refrigeration. The wet air fin cooler  104  is positioned to cool the slip-stream of first refrigerant in line  51  in  FIGS. 2 and 3 . Alternatively, the wet air fin cooler  104  could be incorporated as part of the one or more condensers or coolers  39  to sub-cool liquid propane that serves the other parts of the liquefaction process before the slip-stream of first refrigerant in line  51  is removed to provide a source of cooling (direct or indirect) to air chillers or coolers  57 ,  58 . However, it is preferred to sub-cool only the slip-stream of propane in line  51  to maximize the benefit with respect to gas turbine inlet air chilling. 
     According to disclosed aspects, separators  101  and  102  are positioned in the gas turbine air inlet following the air chillers or coolers  58 ,  57 , respectively. These separators  101 ,  102  remove the water that is condensed from the inlet air  70 ,  71  as the inlet air is cooled from its ambient dry bulb temperature to a temperature below its wet bulb temperature. Separators  101 ,  102  may be of the inertial type, such as vertical vane, coalescing elements, a low velocity plenum, or any other type of moisture separator or de-mister known to those skilled in the art. The gas turbine air inlet may include filtration elements, such as air filters  41 , that may be located either upstream or downstream or both up and downstream of the air chillers or coolers  57 ,  58  and the separators  101 ,  102 , respectively. Preferably, at least one filtration element is located upstream of the chiller(s) and separator(s). This air filtration element may include a moisture barrier, such as an ePTFE (expanded PTFE) membrane which may be sold under the GORETEX trademark, to remove atmospheric mist, dust, salts or other contaminants that may be concentrated in the condensed water removed by separators  101 ,  102 . By locating at least one filtration element or similar device upstream of the chiller and separator associated with gas turbines  24  and/or  38 , atmospheric contaminants in the collected moisture (water) can be minimized, fouling and corrosion of the chiller(s) and separator(s) can be minimized, and fouling and corrosion of the wet air fin cooler  104  can also be controlled and minimized. 
     During the chilling of the gas turbine inlet air  70 ,  71 , a significant portion of the refrigeration duty is used to condense the moisture in the gas turbine inlet air  70 ,  71  rather than simply reducing the dry bulb temperature of the inlet air. As an example, if inlet air with a dry bulb temperature of 40° Celsius and a wet bulb temperature of 24° Celsius is chilled, the effective specific heat of the air is about 1 kJ/kg/° C. between 40° C. and 24° C. but increases dramatically to about 3 kJ/kg/° C. below the wet bulb temperature of 24° C. as the dry bulb temperature is reduced and moisture is condensed from the air. From this, one could conclude that about two-thirds of the refrigeration duty used to chill the air below the wet bulb temperature (dew point) is wasted since the small compositional change of the air to the gas turbine  24  and/or  38  has only a small effect on the available power of the gas turbine. This condensed moisture is essentially at the same temperature as the chilled inlet air to the gas turbine and could be used to provide some precooling of the inlet air  70 ,  71  using another chilling coil similar to air chillers or coolers  57  or  58  that is positioned ahead of the air chillers or coolers  57  or  58  in the air flow. However, this arrangement can only recoup the part of the refrigeration duty used to reduce the temperature of the water but not the part used to condense it. That is, the heat of vaporization of the water cannot be recouped by heat transfer or psychometric cooling with the gas turbine inlet air. 
     A much greater portion of the refrigeration duty used to cool and condense the moisture from the gas turbine inlet air  70 ,  71  can be recouped by collecting this chilled water from separators  101  or  102 , pumping it with a pump  103  and spraying the water onto the tubes of the wet air fin cooler  104  or otherwise mixing the water with the air flow  106  to the wet air fin cooler  104 . Based on the ambient conditions and the actual flow rate of air conveyed by the fan associated with the wet air fin cooler  104 , the water pumped by pump  103  may be sufficient to saturate the air flow of wet air fin cooler  104  and bring it to its wet bulb temperature. Excess water flow from separators  101 ,  102  may be available that could be used for another purpose, or may be insufficient to saturate the air flow. In this later case, additional water from another source may be provided. Additionally, the water separated by separators  101 ,  102  is supplied to the wet air fin cooler  104  in an open-loop circuit, or in other words, the water is not recycled or re-used by the wet air fin cooler  104 . As the cooling of the gas turbine inlet air  70 ,  71  provides a constant source of chilled water to be used by the wet air fin cooler  104 , it is not necessary to recycle or re-use the water after it has been sprayed in the wet air fin cooler. Employing such an open-loop water circuit reduces the need to re-cool and/or filter the water after being used by the wet air fin cooler, thereby reducing the cost and complexity of system  10  or any other system using the disclosed aspects. Additionally or alternatively, as the water sprayed in the wet air fin cooler has been filtered and is relatively clean, it may be either disposed of with minimal additional processing required, or may be used as a water source for other processes within system  10 . 
     An example of the effectiveness of the use of water collected from separators  101  or  102  to improve the air inlet cooling is shown in Table 1. The three columns show the impact of no cooler such as wet air fin cooler  104 , an air fin cooler with no water spray, and a wet air fin cooler  104  using condensed moisture from separators  101  or  102 . 
     
       
         
           
               
               
               
               
             
               
                   
                 TABLE 1 
               
               
                   
                   
               
               
                   
                   
                 Air fin cooler 
                 Air fin cooler 
               
               
                   
                   
                 without water 
                 with water 
               
               
                   
                 No cooler 
                 spray 
                 spray 
               
               
                   
                   
               
             
            
               
                   
               
            
           
           
               
               
               
               
               
            
               
                 Ambient temperature (dry bulb) 
                 40° 
                 C. 
                 Same 
                 Same 
               
               
                 Ambient wet bulb temperature 
                 24° 
                 C. 
                 Same 
                 Same 
               
               
                 Gas turbine inlet air flow rate (at 
                 1,528,000 
                 kg/hr 
                 Same 
                 Same 
               
               
                 wet condition) 
               
               
                 Compressor refrigeration power 
                 4,000 
                 kW 
                 Same 
                 Same 
               
               
                 Condenser (39) outlet 
                 47.8° 
                 C. 
                 Same 
                 Same 
               
               
                 temperature (with propane used 
               
               
                 as first refrigerant) 
               
            
           
           
               
               
               
               
               
               
            
               
                 “Wet” air fin outlet temperature 
                 — 
                 41.5° 
                 C. 
                 32.4° 
                 C. 
               
               
                 (stream 105) 
               
            
           
           
               
               
               
               
               
               
               
            
               
                 Refrigeration Duty of Chiller (53) 
                 18,000 
                 kW 
                 19,450 
                 kW 
                 21,400 
                 kW 
               
               
                 Temperature of inlet air 70, 71 
                 16.1° 
                 C. 
                 14.9° 
                 C. 
                 13.2° 
                 C. 
               
               
                 Moisture condensed in 101 or 102 
                 11.1 
                 tons/hr 
                 12.4 
                 tons/hr 
                 14.1 
                 tons/hr 
               
            
           
           
               
               
               
               
            
               
                 Power increase (per Gas 
                 20.8% 
                 22.0% 
                 23.5% 
               
               
                 Processors Suppliers Association) 
               
               
                 from ambient 
               
               
                 Heat rate decrease per GPSA 
                 7.9% 
                 8.2% 
                 8.5% 
               
               
                 from ambient 
               
               
                   
               
            
           
         
       
     
     As an example of the effectiveness to control the air flow rate of the wet air fin cooler, for the same example above, a wet air fin cooler with a fixed UA (surface area combined with heat transfer coefficients) is used. For this example, the same 40° C. dry bulb, 24° C. wet bulb ambient air is assumed to provide the cooling air for this wet air fin cooler. As a base, the air flow is set to 1,000,000 kg/hr and all of the water condensed from the gas turbine inlet air is used for psychometric cooling of the wet air fin cooler  104 . As the water is sprayed onto the air fin tubes or into the air flow stream (or a combination of both), part of the water vaporizes to cool the tubes or the air flow and approaches the wet bulb temperature of the air stream. However, as this water is vaporized, the water content of this wet air stream also increases and so also increases the wet bulb temperature of this wet air stream above the ambient wet bulb temperature. As such, it is not possible to vaporize the water to reach a wet air stream temperature that approaches the ambient wet bulb temperature; the water can only approach the “wet-wet bulb temperature” (WWBT), which is the wet bulb temperature of the ambient air with the moisture added to the gas composition at the local conditions. 
       FIG. 3  illustrates another aspect of the present disclosure that adds a dedicated supplemental compressor  114  to compress the vapor leaving heat exchanger  53  to the pressure similar to the outlet pressure of first refrigerant compressor  37 . This may provide an improvement to the system of  FIG. 2  to provide control of the inlet air chilling system that is independent of the control of the first refrigerant circuit required to manage the LNG liquefaction system. To ensure no icing of the inlet air chillers or inlet air that enters the gas turbine inlet, it may be advantageous to adjust the temperature of the intermediate fluid to ensure that the inlet air temperature can be managed to avoid icing. To control the intermediate fluid temperature, the pressure of the first refrigerant slip-stream leaving heat exchanger  53  may need to be adjusted such that the temperature of the slip-stream is between −5° C. and 20° C. This may be done by use of a control valve at the exit of heat exchanger  53  as shown in  FIG. 3 . However, it may be more efficient and provide more precise control to adjust the performance of the supplemental compressor  114 . The aspect depicted in  FIG. 3  may also be an especially good solution if the inlet air chilling system is retrofitted to an existing LNG liquefaction system. 
       FIG. 4  is a chart  400  showing the effect of air flow rate on the effectiveness of the cooling as the wet air fin ambient air flow rate is varied from 80% to 120% of the base value. In this case, any excess moisture not required to reach the WWBT of the air upstream of the wet air fin cooler  104  is neglected or in essence is allowed to drip away.  FIG. 4  demonstrates that the maximum refrigeration duty of the chiller  402  is reached at an air flow (about 101% in this example) that corresponds roughly with the full vaporization of the available water supply. This is the optimum air flow required to maximize the refrigeration duty with the restriction that excess moisture is separated upstream of the wet air fin cooler  104 . This optimum air flow may be determined by several means, including but not limited to 1) measuring the relative humidity of the air stream after the water spray and targeting about 100% relative humidity; 2) measuring the gas turbine inlet air temperature  404  and performing a real time optimization to minimize the gas turbine inlet temperature by air fin air flow adjustments; 3) measuring the refrigerant outlet temperature from the wet air fin cooler  104  and performing a similar real time optimization; 4) constructing a physics based or empirical model of the system to optimize the air flow across the wet air fin cooler  104 ; 5) another optimization technique generally known to those skilled in the art or 6) a combination of (1) to (5). Those skilled in the art will understand that a physics based model may be as simple as one that incorporates psychometric air data and at least one of ambient temperature, relative humidity, air fin air flow temperature, barometric pressure, spray water flow rate and spray water temperature to estimate or determine the amount of moisture that can be vaporized into the air fin air flow to reach saturation. 
     The example in  FIG. 4  was restricted to psychometric cooling of the air fin air stream prior to any heating of this air stream by transfer of any heat from stream  51 . With an adequate mixing area ahead of the air fin tube bundle, this air stream would be dry but saturated with moisture at the local conditions with any excess moisture separated. However, if the air flow is reduced below the optimum of  FIG. 4  and it is assumed that any excess moisture is not separated but rather travels with this air stream, then a new optimum air flow can be determined that is characterized by full vaporization of the available moisture at the local air stream conditions downstream of the air fin bundle. Similar to the original example, this new optimum air flow may be determined by similar techniques as described in (1) to (6) above except that any humidity measurement is preferably performed on the air stream downstream of the wet air fin cooler. 
       FIG. 5  schematically depicts a cooling system  500  according to aspects disclosed herein. System  500  includes a turbine  502  operatively connected to a load  504 , which may be a compressor, a generator, or the like. Air  506  entering the turbine may be filtered by one or more filters  508  and cooled using chillers or coolers  510 , which in an aspect a refrigerant (not shown) is run through. One or more separators  512  may remove condensed water in the cooled air as previously described. The water may be directed through a conduit  514  to a storage tank  516 , and may then be pumped using one or more pumps  518 , through a conduit  520 , to a wet air fin cooler  522 . The water may then be directed to a spray header  524  and sprayed through nozzles  526  into ambient air  528  that is being directed into the wet air fin cooler  522  using a fan  530 . The combined water spray and ambient air are directed over or around finned tubes  532 . The finned tubes  532  are configured to permit a process fluid  534  to pass therethrough. As explained previously with respect to  FIGS. 1 and 2 , the wet air fin cooler  522  cools the process fluid, which exits the wet air fin cooler at  536 . The process fluid may be any fluid to be cooled, which in the oil and gas industry may include refrigerants, solvents, natural gas liquids, natural gas, or other fluids. The water spray in the ambient air may be recovered by collecting condensed water on the finned tubes  532  or other means, and may be disposed of or used in another process. In the aspect shown in  FIG. 5 , the open-loop circuit of water may be depicted by the path of the water from the separator  512  through the wet air fin cooler  522 . 
     It can be seen that using condensed water collected in an inlet air cooler (IAC), and transferring the water to a wet air fin cooler in an open-loop circuit, increases the effective heat transfer relative to a traditional fin fan cooler with no water spray. The water condensed downstream of at least one filter element in an IAC is expected to be chilled and generally clean, but additional water treatment may be required in the water spray system to reduce corrosion, biological growth, and the like. 
     The disclosed aspects have particular applicability to the to the oil and gas industry or other industries where water usage is often less critical than with large power plants having high capacity steam systems. For example, the disclosed aspects may be installed in any heat transfer service requiring additional capacity or process debottlenecking, such as process compressor discharge temperature control. The disclosed aspects increase the effective heat transfer of any air fin cooler in any service. The disclosed aspects may be used in the discharge of a process compressor to reduce the load of the driver, i.e. reduce firing temperature, as a means to extend maintenance intervals. The disclosed aspects may also be used to improve natural gas liquids processes whereby auxilliary refrigerant systems are used to reduce the mole weight of the gas. The capacity of such auxiliary refrigerant systems is often the limiting factor in process capacity. Using the disclosed wet air fin cooler, the capacity of these auxiliary refrigerant systems is greatly increased, leading to additional available capacity in the primary compression process. The disclosed aspects may also be used to improve efficiency of a turbine/generator emissions system, where condensed water from an exhaust gas recirculation cooler is used as a wet spray onto associated steam system condensers and/or the process stream coolers. 
     The scope of the disclosed aspects is not limited to use in the oil and gas industry. The disclosed aspects may be advantageously applied in other industrial processes that may include but are not limited to air separation, integrated gasification combined cycle (IGCC) power plants, other power generation processes, pharmaceutical manufacturing, organic and non-organic chemical manufacturing, and the like. Furthermore, the scope of the disclosed aspects is not limited to processes in which a gas turbine is used. For example, the inlet air stream to an air separation unit (ASU) compressor may be cooled to below the dew point, and the water condensed thereby may be used to cool another process fluid in a wet air fin cooler as described herein. While cooling the inlet air of the compressor reduces the required compression energy and enables improved process efficiency, using the condensed water in a wet air fin cooler as described herein will further improve the process efficiency. In another example, gas turbines may be integrated with with an ASU for for IGCC and gas-to-liquids plants by extracting part of the compressed air from the gas turbine as an input stream to the ASU. In this case, the input stream could be cooled to below the dew point using the aspects described herein. 
       FIG. 6  is a flowchart of a method  600  for cooling a process fluid according to disclosed aspects. At block  602  an inlet air stream of a process component, such as a turbine, is cooled with an inlet air cooling system. At block  604  moisture contained in the cooled inlet air stream is condensed. At block  606  the moisture is separated from the cooled inlet air stream to produce a water stream in an open-loop circuit. At block  608  the water stream is sprayed into an air cooler air stream. At block  610  the combined air cooler air stream and sprayed water stream is directed through an air cooler. At block  612  heat is exchanged between the process fluid and the combined air cooler air stream and sprayed water stream to thereby condense, chill, or sub-cool the process fluid. 
     Disclosed aspects may include any combinations of the methods and systems shown in the following numbered paragraphs. This is not to be considered a complete listing of all possible aspects, as any number of variations can be envisioned from the description above. 
     1. A method for cooling a process fluid, comprising: 
     cooling an inlet air stream of a turbine with an inlet air cooling system; 
     condensing moisture contained in the cooled inlet air stream; 
     separating the moisture from the cooled inlet air stream to produce a water stream in an open-loop circuit; 
     spraying the water stream into an air cooler air stream; 
     directing the combined air cooler air stream and sprayed water stream through an air cooler; and 
     exchanging heat between the process fluid and the combined air cooler air stream and sprayed water stream to thereby condense, chill, or sub-cool the process fluid. 
     2. The method of paragraph 1, wherein the air cooler includes a tube bundle, and wherein the step of exchanging heat comprises: 
     passing the process fluid through the tube bundle; and 
     directing the combined air cooler air stream and sprayed water stream over or across the tube bundle. 
     3. The method of paragraph 1 or paragraph 2, wherein directing the combined air cooler air stream and the sprayed water stream is accomplished using a fan.
 
4. The method of paragraph 3, wherein a flow rate or velocity of the air cooler air stream is adjusted using one or more of a fan speed control, a fan blade pitch control, and a damper adjustment.
 
5. The method of paragraph 4, wherein the air cooler air stream flow rate or velocity is adjusted based on at least one of: relative humidity of the air cooler air stream, flow rate of the sprayed water stream, ambient temperature, barometric pressure, psychometric air data, ambient relative humidity, air stream temperature, and temperature of the sprayed water stream.
 
6. The method of any of paragraphs 1-5, wherein separating the moisture is accomplished by a separating device selected from an inertial separator, a vane separator, a plenum, and a coalescer.
 
7. The method of any of paragraphs 1-6, further comprising at least partially filtering the inlet air stream before cooling the inlet air stream.
 
8. The method of any of paragraphs 1-7, wherein the process stream is a hydrocarbon process stream requiring heat rejection.
 
9. The method of any of paragraphs 1-7, wherein the process stream is a process stream in one of a pharmaceutical manufacturing process, a power generation process, and a chemical manufacturing process.
 
10. The method of any of paragraphs 1-9, wherein the inlet air stream, the turbine, and the inlet air cooling system are a first inlet air stream, a first turbine, and a first inlet air cooling system, respectively, the method further comprising:
 
     cooling a second inlet air stream of a second turbine with a second inlet air cooling system; 
     condensing moisture contained in the second cooled inlet air stream; 
     separating the moisture from the second cooled inlet air stream; and 
     directing the water into the water stream. 
     11. The method of any of paragraphs 1-10, wherein cooling the inlet air stream of the turbine with the inlet air cooling system comprises chilling the inlet air stream from about a dry bulb temperature of the inlet air stream to a temperature below a wet bulb temperature of the inlet air stream.
 
12. A system for cooling a process fluid in a hydrocarbon process processing natural gas to produce liquefied natural gas, the system comprising:
 
     a gas turbine; 
     a chiller located at an inlet of the gas turbine, the chiller configured to chill an inlet air stream from about its dry bulb temperature to a temperature below its wet bulb temperature; 
     a separator located downstream of the chiller and configured to separate water in the chilled inlet air stream and produce a water stream in an open-loop circuit; and 
     a wet air fin cooler that combines the water stream with an air cooler air stream to condense, chill, or sub-cool the process fluid passing through the wet air fin cooler. 
     13. The system of paragraph 12, wherein the wet air fin cooler comprises: 
     a tube bundle through which the process fluid passes; 
     a spray header configured to spray the water stream into the air cooler air stream; and 
     a fan that forces the air stream and sprayed water stream over or across the tube bundle. 
     14. The system of paragraph 13, further comprising a fan controller that controls at least one of a speed of the fan, a pitch of a blade of the fan, and a damper associated with the fan.
 
15. The system of any of paragraphs 12-14, wherein the separator is one of an inertial separator, a vane separator, a plenum, and a coalescer.
 
16. The system of any of paragraphs 12-15, further comprising a filter arranged to at least partially filter the inlet air stream before the inlet air stream is chilled by the chiller.
 
17. The system of paragraph 16, wherein the filter comprises a moisture barrier.
 
18. The system of any of paragraphs 12-17, wherein the gas turbine, the chiller, the inlet air stream, and the separator are a first gas turbine, a first chiller, a first inlet air stream, and a first separator, and further comprising:
 
     a second gas turbine; 
     a second chiller located at an inlet of the second gas turbine, the second cooler configured to chill a second inlet air stream from about its dry bulb temperature to a temperature below its wet bulb temperature; and 
     a second separator located downstream of the second chiller and configured to separate water in the chilled second inlet air stream and deliver the separated water into the water stream. 
     19. A method for cooling a process fluid, comprising: 
     cooling an inlet air stream of a process component with an inlet air cooling system; 
     condensing moisture contained in the cooled inlet air stream; 
     separating the moisture from the cooled inlet air stream to produce a water stream in an open loop circuit; 
     spraying the water stream into an air cooler air stream; 
     directing the combined air cooler air stream and sprayed water stream through an air cooler; and 
     exchanging heat between the process fluid and the combined air cooler air stream and sprayed water stream to thereby condense, chill, or sub-cool the process fluid. 
     20. The method of paragraph 19, wherein the air cooler includes a tube bundle, and wherein the step of exchanging heat comprises: 
     passing the process fluid through the tube bundle; and 
     directing the combined air cooler air stream and sprayed water stream over or across the tube bundle. 
     21. The method of paragraph 19 or paragraph 20, wherein directing the combined air cooler air stream and the sprayed water stream is accomplished using a fan.
 
22. The method of paragraph 21, wherein a flow rate or velocity of the air cooler air stream is adjusted using one or more of a fan speed control, a fan blade pitch control, and a damper adjustment.
 
23. The method of paragraph 22, wherein the air cooler air stream flow rate or velocity is adjusted based on at least one of: relative humidity of the air cooler air stream, flow rate of the sprayed water stream, ambient temperature, barometric pressure, psychometric air data, ambient relative humidity, air stream temperature, and temperature of the sprayed water stream.
 
24. The method of any of paragraphs 19-23, wherein separating the moisture is accomplished by a separating device selected from an inertial separator, a vane separator, a plenum, and a coalescer.
 
25. The method of any of paragraphs 19-24, further comprising at least partially filtering the inlet air stream before cooling the inlet air stream.
 
26. The method of any of paragraphs 19-25, wherein cooling the inlet air stream of the process component with the inlet air cooling system comprises chilling the inlet air stream from about a dry bulb temperature of the inlet air stream to a temperature below a wet bulb temperature of the inlet air stream.
 
     It should be understood that the numerous changes, modifications, and alternatives to the preceding disclosure can be made without departing from the scope of the disclosure. The preceding description, therefore, is not meant to limit the scope of the disclosure. Rather, the scope of the disclosure is to be determined only by the appended claims and their equivalents. It is also contemplated that structures and features in the present examples can be altered, rearranged, substituted, deleted, duplicated, combined, or added to each other.