Abstract:
A stack system and method for in-line geothermal and hydroelectric generation from recovered natural gas-fired water/steam process waste heat. The stack system and method is a new way of reusing natural gas fired water/steam process waste heat to make more electricity from the same Btu inputs. The stack system and method uses warm industrial demineralized water from various sources, a micro-managed combined stack flue system and specific terrain to ring out every bit of energy possible from traditional, heretofore, acceptable wastes. The stack uses two marginal waste heat sources to make one significant heat source for additional fossil fuel-free generation. This stack is unique in that it incorporates tandem, geothermal and hydroelectric generators. The stack can be applied to closed-loop (Power Stack) and open-loop (Desalination Stack) processes.

Description:
CROSS REFERENCE TO RELATED APPLICATIONS 
   This application claims the benefits of U.S. Provisional Application Ser. No. 60/637,838, filed Dec. 22, 2004 and to U.S. Provisional Application Ser. No. 60/666,604, filed Mar. 31, 2005. 

   BACKGROUND 
   Field of the Invention 
   The present invention relates to geothermal and hydroelectric generation. More particularly, the present invention relates to in-line geothermal and hydroelectric generation from recovered natural gas-fired industrial water/steam process waste heat. 
   SUMMARY OF THE INVENTION 
   This patent discloses and claims a useful, novel, and unobvious stack system and method for in-line geothermal and hydroelectric generation from recovered natural gas-fired water/steam process waste heat. 
   The stack system and method of the present invention is a new way of reusing natural gas fired water/steam process waste heat to make more electricity from the same Btu inputs. The stack system and method uses warm industrial demineralized water from various sources, a micro-managed combined stack flue system and specific terrain to ring out every bit of energy possible from traditional, heretofore, acceptable wastes. The stack system and method uses two marginal waste heat sources to make one significant heat source for additional fossil fuel-free generation. This stack is unique in that it incorporates tandem, geothermal and hydroelectric generators. This stack system and method can be applied to closed-loop (Power Stack) and open-loop (Desalination Stack) processes. 
   Power Stack 
   A principal object of the present invention is to provide a power plant waste heat conversion process and apparatus called Power Stack that will overcome the deficiencies of the prior art devices. 
   An object of the present invention is to provide a natural gas depressurized cooling heat exchanger device that will properly control Demineralized Circulating Water (DCW) to an 80° F. constant temperature. Natural gas depressurization will cool post-turbine steam in the steam cycle during the hottest summer months and reduction of natural gas depressurization cooling will advantageously heat post-turbine steam in the steam cycle during the coldest winter months. 
   Another object of the present invention is to provide a natural gas depressurized cooling of DCW that will eliminate any type of internal and/or external cooling towers and thus eliminate any and all cooling tower evaporation. 
   Another object of the present invention is to provide the only generation by two renewable generators (geothermal and hydroelectric) in a continuous DCW closed loop in tandem with traditional steam plants that are both free from additional fossil fuel input. 
   Another object of the present invention is to provide a greatly improved topographical elevation change of water state process that significantly supersedes any traditional uphill off-peak pumping costs. A cheaper, non-terrain utilization version can include placing Power Stack atop an existing steam unit or aside an existing unit&#39;s stack. 
   Another object of the present invention is to provide a Power Stack apparatus having an infrastructure that does not contain any pumps or fans greater than 480 volts. 
   Another object of the present invention is to provide a Power Stack process and apparatus that routinely allows flexible generation from geothermal units. These normally static ‘green’ generators can easily produce peak load with duct burner input. 
   Another object of the present invention is to provide a Power Stack process that eliminates station service losses from traditional winter cooling tower maintenance against icing by running a second DCW pump and/or reversing fans. Furthermore, Power Stack eliminates traditional over-generation during winter to keep DCW warm enough not to sub-cool the condenser, which endangers turbine back-end blading. 
   Another object of the present invention is to provide a Power Stack process that extends single DCW pump use by high-head feeding siphon effect and from cooler DCW-in temperatures for better backpressure. It also reduces induction fan use due to negative pressure generated at the bottom intake of the tall Power Stack flue. 
   Another object of the present invention is to provide a method for nuclear energy to be generated in rural areas if supported by enough depressurized natural gas flow for DCW cooling, steep terrain and a few good wells. It is a drought-resistant and timely process. 
   Desalination Stack 
   A principal object of the present invention is to provide a more reliable, more efficient, less costly saltwater to potable water distillation process and post-process electric generation by apparatus called Desalination Stack that will overcome the deficiencies of the prior art devices. 
   Another object of the present invention is to provide a natural gas depressurized cooling heat exchanger device that will better control the distillation temperature environment within a desalination chamber for better vapor condensation rates. This heat exchanger with natural gas internal flow is called the step-down condenser. It replaces seawater-in on most traditional MED and MSF schemes. 
   Another object of the present invention is to provide a natural gas depressurized cooling heat exchanger device that will better develop vacuum within desalination chamber for lower brine evaporation temperatures. This heat exchanger with natural gas internal flow is called the step-down condenser. It replaces seawater-in and non-condensable ejectors on most traditional MED and MSF schemes. 
   Another object of the present invention is to provide natural gas fired exhaust heating that creates an externally heated seawater/brine heater, replacing traditional steam-in seawater/brine heaters. This flue gas brine heater eliminates traditional internal routing of seawater in through stages or effects. This reduces construction costs, removes seawater-in corrosion, aggressive cathodic protection problems, and increases reliability with fewer outages. Nothing hinders brine vapor access to the icy step-down condenser. 
   Another object of the present invention is to provide natural gas fired exhaust gasses to reboil freshwater-out for the production of electricity: 1) as it condenses back to water through the geothermal generator, and 2) after it condenses back to water through the hydroelectric generator. 
   Another object of the present invention is to provide optional steamless construction allowing simpler mechanical vacuum and non-condensable removal. As with steam style process, optional individual maximum brine heating coupled with maximum individual cooling/vacuum uses fewer chambers for full desalination. 
   Another object of the present invention is to provide double boiling of freshwater-out/DCW for ultimately pure potable water. Though unnecessary for drinking water, it is good for equipment anti-scale chemistry. 
   Another object of the present invention is to provide stand-alone full DCW capability. Desalination Stack can function without any combustion turbines on-line solely using individual auxiliary chamber burners and duct burners. More gas is routed through chambers than can be fired by individual auxiliary burners. This surplus is valved to the duct burner, contributing to overall flue heat. While uneconomical, the added step-down depressurized natural gas will condense even more brine vapor. Full capacity water production is therefore possible. 

   
     BRIEF DESCRIPTION OF THE DRAWINGS 
       FIG. 1  is an exemplary embodiment of a hydrologic cycle; 
       FIG. 2  is an exemplary embodiment of the general Power Stack process of the present invention; 
       FIG. 3  is an exemplary embodiment of the general Desalination Stack process of the present invention; 
       FIG. 4A  is an exemplary embodiment of a normal manometer; 
       FIG. 4B  is an exemplary embodiment of a manometer associated with the power stack and the Desalination Stack of the present invention; 
       FIG. 5  is an exemplary embodiment of a power stack system according to the present invention; 
       FIG. 6  is an exemplary embodiment of a Desalination Stack system according to the present invention; 
       FIG. 7  is an alternative exemplary embodiment of a Desalination Stack system according to the present invention; 
       FIG. 8  is an exemplary embodiment of a Power Stack closed loop according to the present invention; and 
       FIG. 9  is an exemplary embodiment of a Desalination Stack open loop of the present invention. 
   

   DETAILED DESCRIPTION 
   Persons of ordinary skill in the art will realize that the following disclosure is illustrative only and not in any way limiting. Other embodiments of the invention will readily suggest themselves to such skilled persons having the benefit of this disclosure. 
   The stack systems and methods of the present invention harness natural gas-fired industrial water/steam process waste heat. This heat is comprised of flue gas waste heat that boils previously waste heated pristine demineralized water from various sources. The resulting saturated steam is sent to a geothermal generator. It is then sent as water to a hydroelectric unit, and eventually cooled en route to its final destination. 
     FIG. 1  illustrates a hydrologic cycle  2 . Hydrologic cycle  2  starts at lower left where a body of water  4  is heated up and evaporated  6  as moisture up into clouds. Clouds move horizontally clockwise, by advection  8 , to the place where condensation  10  in the form of precipitation falls on headwaters  12 . Runoff water  14  then flows back to the body of water  4 . 
     FIG. 2  illustrates the general Power Stack process  20  of the present invention. The Power Stack system and method rotates the hydrologic cycle  2  ninety degrees counter-clockwise. Therefore, the Power Stack system and method evaporative process  22  rotates to the bottom left. Next, the Power Stack&#39;s left-hand side ascending vertical is distilled water advection  24  in saturated steam form. The top sector flow is condensation  26 , due to taking heat out of the saturated steam by a geothermal generator, as will be discussed below. The right-hand side descending vertical is high-head hydroelectric generation runoff  28 . The water goes through a cooling process  30 , and then flows though a power plant  32  back to evaporation point  22 . 
   As seen in  FIG. 2 , the general Power Stack process  20  is a closed loop process. This closed loop begins by modifying steam cycle main condenser cooling water. Normally, raw cooling water (from a river or body of water) picks up Btus from post-turbine boiler steam in a condenser. Raw water then flows to a cooling tower where evaporation gives up the Btus and thousands of gallons of water per minute. Cooled raw water is pumped back to the condenser. Instead, the Power Stack of the present invention uses pristine demineralized water for steam cycle cooling. The Power Stack&#39;s heat exchanger boils the very warm demineralized water leaving the condenser with steamer and combustion turbine flue gas waste heat. Vaporous saturated steam fills a vertical pipe which leads to an elevated geothermal generator. Elevated locations can include a dozed hill, nearby natural terrain or the top of the steamer itself. Saturated steam superheats geothermal generator Freon to produce electricity, and in the process, turns into about 120° F. DCW. 
   These one-to-one water to steam to water phase changes are the first factor for lifting saturated steam uphill. The warm water then flows down to a hydroelectric unit back at base level. The siphon effect is the second factor for lifting saturated steam uphill. Siphon also pulls a negative on the entire evaporation process to lower the boiling point. The third factor is temperature gradient itself. 
   About 30-40° F. is preferably removed before closed-loop, pristine DCW reaches the power plant condenser. 
     FIG. 3  illustrates the general Desalination Stack process  40  of the present invention. Just like the general Power Stack process  20  of the present invention, the general Desalination Stack&#39;s system and method rotates the hydrologic cycle  2  ninety degrees counter-clockwise. Water is introduced into the process at step  42 . The water is evaporated, as the desalination stack&#39;s evaporative process  44  has been rotated to the bottom left. Next, the Desalination Stack&#39;s left-hand side ascending vertical is distilled water advection  46  in saturated steam form. The top sector flow is condensation  48 , due to taking heat out of the saturated steam by a geothermal generator, as will be discussed below. The right-hand side descending vertical is high-head hydroelectric generation runoff  50 . Desalination stack process  40  is different from Power Stack process  20  in that it is an open loop process. This open loop distinction is different from Power Stack&#39;s closed loop in that runoff  50  flows away from its evaporative starting point  44  and toward municipal consumption  52 . 
   Open loop thermal desalination conveniently produces its own pristine demineralized water. Seawater-in is heated to the point of vaporization, which is customarily about 230° F. Natural gas cooling produces more condensate from vapor and the net lower vacuum attained reduces boiling temperatures. Yet, this anti-scale perk still yields very warm freshwater-out. Instead of traditionally cooling the demineralized freshwater and sending it directly to the public, the Desalination Stack of the present invention makes that hot water perform more work. It is re-boiled by associated combustion turbine flue gas waste heat, sent up to the geothermal generator, drawn down to the hydroelectric unit, and cooled by thermal oriented businesses. Only then is it remineralized, traditionally cooled and pumped to municipal distributions. In the long term, this desalination stack may become cheaper than reverse osmosis. 
   The Power Stack and Desalination Stack of the present invention provide free, low tech geothermal and hydroelectric green generation without additional fans or pumps, assures year round 80° F. condenser cooling water (important to power plant operation) and, as a benefit to local communities with thirsty people, there is no water lost to evaporation. 
   The Power Stack and Desalination Stack DCW system is like an upside-down manometer. As seen in  FIG. 4A , a normal manometer  60  includes a positive pressure  62  exerted on one leg  64 , pushing down on the integral column of water leg  66  and resisting against the pull of gravity. Where the line of liquid stops is where the pressure is measured. 
   The manometer  70  associated with the Power Stack and the Desalination Stack of the present invention is an upside-down manometer. It includes thermal gradient and pressure gradient  72  exerted on one leg pulled up on by the interconnected downward column of water leg  76 , assisted with the pull of gravity. Where the line of liquid starts at  74  is the siphon pressure of water itself, continually condensed at or near the zenith of potential energy. The Stacks&#39; second leg  76 , the downward water column, possesses enough kinetic energy to siphon a full wet column of water upwards by itself, yet has only vapor to pull. The Stacks&#39; inverted manometer  70  sufficiently lifts the positive moment of saturated steam input energy by its prevailing negative moment of draining condensation output energy. 
     FIG. 5  is an exemplary embodiment of a Power Stack system  80  according to the present invention. System  80  comprises DCW pump  82 , which supplies DCW throughout the system. DCW pump  82  is coupled with natural gas heat exchanger  84 , which cools DCW. Heat exchanger  84  is coupled to DCW-in header  86 , which routes DCW through DCW steam cycle heat exchangers  88 , to DCW-out header  90 . DCW-out header  90  is coupled to stack heat exchanger  94  through DCW-out valve  92 . Valve  92  is normally open to heat exchanger  94 , allowing DCW to be vaporized by cumulative flue gas heat from thermal flue source or sources  96 . The flue gas temperature may be increased by duct burner  98 . DCW from DCW-out header  90  is heated by flue gas heat from sources  96  and/or duct burner  98 . Excess flue gas volume may bypass heat exchanger  94  through bypass  102 . Natural gas supply  85  provides cooling in heat exchanger  84  and combustion Btus for thermal processes  96  and  98 . 
   DCW-out will become saturated steam by the time it reaches drum  100 . Water solids from drum  100  are removed by blowdown pump  104 . Saturated DCW proceeds upwards through de-aerator  106 , where non-condensables are removed by eductor  108 . Flue gas flows to and through upper flue gas discharge  112 . Liquified gas particulates are collected in waste drain  114 . DCW saturated steam from deaerator  106  flows to Rankine cycle heat exchanger  110 , where Freon picks up DCW-out steam Btus. Condensed DCW flows from latter stages of heat exchanger  110  to and through routing valve  116 . A minor portion of DCW flows to and through line  118  to hotwell makeup header  120 . The larger portion of DCW flows through larger thermal business heat exchanger  122 , benefitting to thermal business site  124 . Cooler DCW flows to optional ground loop cooling  126  to routing valve  128 . 
   Heated by heat exchanger  110 , superheated Freon flows through and turns geothermal turbine(s)  130 . Spent Freon gas from geothermal turbine(s)  130  flows to and through smaller thermal business heat exchanger  132  and potable water heat exchanger  134 . Potable water heat exchanger  134  component  136  flows to thermal business site  124 . Liquefied Freon is returned to heat exchanger  110 . 
   DCW from valve  128  becomes high head hydroelectric source  138 . Routing valve  128  can also send DCW to dark start reserve tank  140 . From hydroelectric source  138 , DCW drops vertically to hydroelectric units  144 . Hydroelectric throttle valve  142  enables additional flow from reserve tank  140  to and through hydroelectric units  144 . Plume surge piping  146  from hydroelectric units  144  flows to plume surge tank  148 . DCW non-condensables from deaerator  106  flow through eductor line  108  to plume surge piping  146 . DCW may flow through DCW bypass  150  from routing valve  92 , and through natural gas heat exchanger  84  to plume surge piping  146 . DCW supply pump  82  takes suction from plume surge tank  148 . 
   Geothermal turbine(s)  130  and hydroelectric units  144  each generate electricity from reheated DCW without additional Btus. The electricity is generated solely from power plant discharges from DCW-out header (thermal water source)  90  and thermal flue source(s)  96  that would normally be wasted to atmosphere. 
     FIG. 6  illustrates an exemplary embodiment of a Desalination Stack steam system  180  according to the present invention. Steam system  180  comprises seawater-in pump  182 , which supplies seawater from saline water sources, such as the ocean, aquifers, and lakes, to freshwater-out/DCW header pumps: low-pressure pump  184  and high-pressure variable-speed pump  186 . It is contemplated that seawater refers to saline water from any source. 
   Seawater-in is pumped through seawater/freshwater heat exchanger  188 , where seawater-in cools freshwater that is directed to city/municipal water system  190 . Seawater proceeds to final condenser (heat exchanger)  192 , en route to seawater/brine heater  194 . Seawater is injected from seawater/brine heater  194  into individual desalination process chamber(s)  198  through injection port  196 . This hot seawater-in is further heated by auxiliary heater(s)  200 . Brine vapor, represented by the arrows, escape from brine  202  into condensation, represented by the dots. This condensation is precipitated out by depressurized natural gas step-down condenser/heat exchanger(s)  204 . This resultant condensation gravitates to V-shaped condensation collector(s)  206 . Condensation collector(s)  206  cumulatively produce freshwater for freshwater-out/DCW header  208 . 
   Pumps  184  and  186  take suction from header  208 . High-pressure pump  186  supplies pressure to start up heat exchanger  210 , which creates pressure that routing valve  212  controls. This pressure is created by DCW being boiled by flue gas Btus from combustion turbine(s)  214  and/or duct burner  216 . Flue gas bypass  218  prevents overheating of heat exchanger  210  and desalination stack heat exchanger  220 . High-pressure pump  186  can also send DCW to routing valve  224 . Valve  212  sends DCW to heat exchanger  220  or to steam air ejector(s)  222 . Steam from steam air ejector(s)  222  proceeds to the final condenser/heat exchanger  192 , and is sent to final condenser waste. 
   Natural gas supply header  230  sends high-pressure natural gas to combustion turbine(s)  214  and to duct burner  216 . Natural gas is sent through pressure reducing valve  232  into individual chambers  198 . Within chambers  198 , step-down heat exchanger  204  creates condensation (represented by dots), supplies natural gas to auxiliary heater(s)  200 , and supplies stand-alone natural gas to duct burner  216  through stand-alone line  234 . 
   Low-pressure pump  184  sends pressure to routing valve  224 . Routing valve  224  sends low-pressure DCW to heat exchanger  220 . Routing valve  224  can also send DCW to DCW bypass line  226 . 
   DCW-out will become saturated steam by the time it reaches drum  228  from heat exchanger  220 . Water solids from drum  228  are removed by blowdown pump  236 . Flue gas flows to and through upper flue gas discharge  238 . Liquified gas particulates are collected in waste drain  240 . DCW saturated steam from drum  228  flows to Rankine cycle heat exchanger  242 , where Freon picks up DCW-out steam Btus. Condensed DCW flows from latter stages of heat exchanger  242  to and through routing valve  244 . A minor portion of DCW can flow through line  246  to an optional specialty business. The larger portion of DCW flows through larger thermal business heat exchanger  248 , benefiting thermal business site  258 . The resultant cooler DCW continues to flow through DCW heat exchanger  250  en route to high head hydroelectric supply tank  252 . 
   Heated by heat exchanger  242 , superheated Freon flows through and turns geothermal turbine(s)  254 . Spent Freon gas from geothermal turbine(s)  254  flows to and through smaller thermal business heat exchanger  256 , benefiting thermal business site  258 , and continues to and through DCW heat exchanger  250 . Resultant liquefied Freon is returned to heat exchanger  242 . 
   From hydroelectric source tank  252 , DCW drops vertically to hydroelectric units  260 . Hydroelectric throttle valve  262  enables additional flow from tank  252  reserve to and through hydroelectric units  260 . Plume surge piping  264  from hydroelectric units  260  flows to plume surge tank  266 . Atmospheric aeration  268  is educted by and entrained in plume surge piping  264  through valves  270 . Freshwater from plume surge tank  266  is forwarded through seawater-in/freshwater heat exchanger  188  via piping  272  to city/municipal water system  190 . DCW bypass line  226  connects to piping  272  upstream of seawater-in/freshwater heat exchanger  188 . 
   Geothermal turbine(s)  254  and hydroelectric units  260  each generate electricity from reheated DCW without additional Btu&#39;s. The electricity is generated solely from power plant discharges from DCW-out header (thermal water source)  208  and thermal flue source(s)  216  and  214  that would normally be wasted to atmosphere. 
     FIG. 7  illustrates an alternative exemplary embodiment of a Desalination Stack steamless system  280  according to the present invention. System  280  is similar to system  180 , with like elements numbered alike. 
   Steamless system  280  comprises seawater-in pump  182 , which supplies seawater from saline water sources, such as the ocean, aquifers, and lakes, to freshwater-out/DCW header low-pressure pump  184 . It is contemplated that seawater refers to saline water from any source. 
   Seawater-in is pumped through seawater/freshwater heat exchanger  188 , where seawater-in cools freshwater that is directed to city/municipal water system  190 . Seawater is injected into individual desalination process chamber(s)  198  through injection port  196 . This hot seawater-in is further heated by auxiliary heater(s)  200 . Brine vapor, represented by the arrows, escape from brine  202  into condensation, represented by the dots. This condensation is precipitated out by depressurized natural gas step-down condenser/heat exchanger(s)  204 . This resultant condensation gravitates to V-shaped condensation collector(s)  206 . Condensation collector(s)  206  cumulatively produce freshwater for freshwater-out/DCW header  208 . 
   Mechanical air ejectors  282  remove non-condensables from each individual chambers  198 . 
   Natural gas supply header  230  sends high-pressure natural gas to combustion turbine(s)  214  and to duct burner  216 . Natural gas is sent through pressure reducing valve  232  into individual chambers  198 . Within chambers  198 , step-down heat exchanger  204  creates condensation (represented by dots), supplies natural gas to auxiliary heater(s)  200 , and supplies stand-alone natural gas to duct burner  216  through stand-alone line  234 . 
   Pump  184  takes suction from header  208 . Pump  184  supplies DCW to routing valve  224 . Low-pressure pump  184  sends pressure to routing valve  224 . Routing valve  224  sends low-pressure DCW to heat exchanger  220 . Routing valve  224  can also send DCW to DCW bypass line  226 . 
   DCW-out will become saturated steam by the time it reaches drum  228  from heat exchanger  220 . Water solids from drum  228  are removed by blowdown pump  236 . Flue gas flows to and through upper flue gas discharge  238 . Liquefied gas particulates are collected in waste drain  240 . DCW saturated steam from drum  228  flows to Rankine cycle heat exchanger  242 , where Freon picks up DCW-out steam Btu&#39;s. Condensed DCW flows from latter stages of heat exchanger  242  to and through routing valve  244 . A minor portion of DCW can flow through line  246  to an optional specialty business. The larger portion of DCW flows through larger thermal business heat exchanger  248 , benefiting thermal business site  258 . The resultant cooler DCW continues to flow through DCW heat exchanger  250  en route to high head hydroelectric supply tank  252 . 
   Heated by heat exchanger  242 , superheated Freon flows through and turns geothermal turbine(s)  254 . Spent Freon gas from geothermal turbine(s)  254  flows to and through smaller thermal business heat exchanger  256 , benefiting thermal business site  258 , and continues to and through DCW heat exchanger  250 . Resultant liquefied Freon is returned to heat exchanger  242 . 
   From hydroelectric source tank  252 , DCW drops vertically to hydroelectric units  260 . Hydroelectric throttle valve  262  enables additional flow from tank  252  reserve to and through hydroelectric units  260 . Plume surge piping  264  from hydroelectric units  260  flows to plume surge tank  266 . Atmospheric aeration  268  is educted by and entrained in plume surge piping  264  through valves  270 . Freshwater from plume surge tank  266  is forwarded through seawater-in/freshwater heat exchanger  188  via piping  272  to city/municipal water system  190 . DCW bypass line  226  connects to piping  272  upstream of seawater-in/freshwater heat exchanger  188 . 
   Geothermal turbine(s)  254  and hydroelectric units  260  each generate electricity from reheated DCW without additional Btu&#39;s. The electricity is generated solely from power plant discharges from DCW-out header (thermal water source)  208  and thermal flue source(s)  216  and  214  that would normally be wasted to atmosphere. 
     FIG. 8  illustrates an exemplary embodiment of a Power Stack closed loop  300  according to the present invention. At  302 , the cycle begins with the DCW pump sending DCW to a natural gas heat exchanger, where warm DCW is cooled. Natural gas is directed to natural gas steam electric generation at  306 , where it is combusted to create the steam electric generation, and the cooled DCW is sent to the main condenser at  304 , where it picks up the natural gas Btu&#39;s from  306  after steam turbine utilization. Flue gas waste heat and DCW waste heat combine at flue gas heat exchanger at  308  and heat DCW into DCW saturated steam at  310 . DCW saturated steam proceeds upwards, following diminished pressure to Rankine geothermal generator heat exchanger at  312 . That heat exchange produces electrical energy and sends resultant hot DCW at  314  to the thermal business heat exchanger at  316 . Thermal business heat exchanger  316  utilizes hot DCW from  314  for the advantage of thermal oriented businesses. Warm DCW is then gravitationally pulled at  318  to hydroelectric units at  320 , where the second generation of electricity occurs without the necessity of additional Btu&#39;s. Hydroelectric plume flow is directed back to starting point of  302 . 
     FIG. 9  illustrates an exemplary embodiment of a Desalination Stack open loop  330  of the present invention. At  332 , the open loop begins with saline water being pumped at  332  through the seawater and freshwater heat exchanger at  334 , Here, it picks up Btu&#39;s from freshwater coming into heat exchanger at  334  and contributes those Btu&#39;s to natural gas thermal desalination and thermal combustion turbine generation process at  336 . Step  336  creates by-product waste heat in the form of flue gas and hot DCW, which are combined at heat exchanger  338 . DCW saturated steam proceeds upwards at  340 , following diminished pressure to Rankine geothermal generator heat exchanger at  342 . That heat exchange produces electrical energy and sends resultant hot DCW at  344  to the thermal business heat exchanger at  346 . Thermal business heat exchanger  346  utilizes hot DCW from  344  for the advantage of thermal oriented businesses. Warm DCW is then gravitationally pulled at  348  to hydroelectric units at  350 , where the second generation of electricity occurs without the necessity of additional Btu&#39;s. Hydroelectric plume flow is directed through the seawater and freshwater heat exchanger at  334 . Btu&#39;s are given up to the saline water  332  entering heat exchanger  334  en route to step  336 . Cooler potable water is directed to public potable water systems at  352 . 
   While the invention has been described with reference to exemplary embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiments disclosed as the best mode contemplated for carrying out this invention.