Abstract:
A power cogeneration system employing a partially-open gaseous fluid cycle method and apparatus devices for oxy-fuel combustion conversion of a given hydrocarbon composition fuel&#39;s heat-value energy into mechanical or electrical power energy, and transferred useful heat energy, with accompanying large reductions of consumed fuel and undesirable exhaust emissions.

Description:
BACKGROUND OF THE INVENTION  
       [0001]     To achieve a goal of significantly reducing a power cogeneration system&#39;s emission mass flow rate of the “greenhouse gas” (carbon dioxide) by a given percentage amount, it is necessary to proportionally increase the thermal efficiency of a power unit apparatus&#39; conversion of fuel energy to developed mechanical power and useful applied residual thermal energy which therein proportionally reduces the amount of combusted hydrocarbon fuel required to provide the described energy conversion.  
         [0002]     It has been well known and practiced for decades that higher humidity air and injected water or steam commingled with conventional air combustion gases increases combustion flame speeds and fuel combustion thermal efficiencies within gas turbine type engines, reciprocating type engines, and other fuel combustion burner apparatus using air/fuel combustion. It has also been well known and practiced that partially re-circulating combustion flue stack gases containing carbon dioxide (CO.sub.2) back into a combustion chamber results in a reduced level of nitrogen oxides (NO.sub.x) within the fuel combustion exhaust gases. Due to the high temperatures and speed of completed fuel combustion, the scientific community has been unable to reach a consensus as to precisely what series of altered chemical reactions occur when water vapor and/or carbon dioxide is introduced into an engine&#39;s fuel combustion chamber assembly or subassembly device.  
         [0003]     Oxy-fuel combustion burners have been employed for many years in the steel and glass making industries to furnish desired 3000+ degree Fahrenheit combustion gas temperatures into furnaces to avoid the production of high (NO.sub.x) emissions, but at the expense of high carbon monoxide (CO) emissions. Both the present air separation art methods&#39; high production energy costs of producing acceptable combustion grade oxygen, and the lack of devised combustion system methods to control preset desired oxy-fuel combustion burner or combustion chamber assembly or subassembly uniform maximum temperatures, have collectively curtailed oxy-fuel combustion applications within present fuel thermal energy to power energy conversion facilities.  
         [0004]     Conventional gas turbine engines or reciprocating engines must be de-rated from their standard ISO horsepower or kW ratings at ambient temperatures exceeding 59° F., and/or at operating site altitudes above sea level. Thus, during summer&#39;s peak power demand periods, when the ambient temperature can increase to 95° F. or greater, up to 20% to 25% horsepower derations of a conventional gas turbine&#39;s ISO engine rating can occur. It is obviously desirable that a power turbine engine/generator unit apparatus within a cogeneration system not be susceptible to such combined on-site ambient temperature and altitude derations when peak power demands occur, or at any other time or site location.  
         [0005]     The current and future projected increasing costs of purchased utility electric power and natural gas (or liquid hydrocarbon fuel) and the accepted projected future trend in the future of “distributed power” and/or power cogeneration facilities, coupled with present and future environmental constraints on fuel combustion exhaust emissions, will make it commercially mandatory that such “distributed power” and/or power cogeneration facilities have the combined attributes (at the minimum) of combined ultra-low NO.sub.x and CO exhaust emissions and substantially higher thermal efficiencies than offered by current art power cogeneration methods. It can be expected that the number of new turbine engine powered ‘cogeneration facilities in the world will be significantly greater than the number of turbine engine powered ‘combined-cycle’ facilities that are devoted purely to the production of electric power. The referenced ‘cogeneration facilities’ are not new in concept. Such energy saving facilities became highly popular in the 1970&#39;s (then referred to as ‘Total Energy Plants’) and were aggressively promoted by many natural gas utilities. Reciprocating gas engine-driven generator sets were the predominant producers of prime power and utilized waste heat. These ‘Total Energy Plant’ facilities efficiently provided electricity, hot water or steam for domestic hot water and building heating requirements, and chilled water for air conditioning. ‘Total Energy Plants’ were widely applied to serve hospitals, universities, large office buildings or building complexes, shopping centers, hotels, food processing plants, and multi-shift manufacturing and industrial facilities, etc. The 50 plus years old predecessor to the ‘Total Energy Plant’ concept was the central electric power and steam plants that continue to currently serve some large eastern US cities, and more predominantly European cities and metropolitan areas. Predominantly, ‘Total Energy Plants’ and current cogeneration facilities have predominantly had less than 100 psig utility supplies of natural gas available to their facilities.  
         [0006]     It is not unusual that present art cogeneration facilities can require fuel gas compression apparatus assemblies to supply adequate fuel pressure to the employed cogeneration method&#39;s selected power engine units, with the said fuel gas compression consuming approximately 5% of the gross electric power produced by the current art power cogeneration facility. It is therefore desirable that power cogeneration facilities incorporate a fuel energy to power and useful heat energy conversion method that requires low gas supply pressures.  
         [0007]     When Brayton Cycle gas turbine engines operate within current art cogeneration facilities as mechanical power drive sources to electric generators and other mechanically driven devices, atmospheric air is compressed and mixed with hydrocarbon gases or atomized hydrocarbon liquids for the resulting mixture&#39;s ignition and combustion at approximately constant pressure. To produce power, the hot combustion and working motive fluid gases are expanded to near atmospheric pressure across one or more power extraction turbine wheels, positioned in series.  
         [0008]     The majority of Brayton simple open-cycle aero-derivative-style Low-NO.sub.x art gas turbine engines are predominantly presently limited in achieving shaft output horsepower rating with 26% to 39% thermal efficiencies, whereas most simple cycle industrial-style Low-NO.sub.x art gas turbine engines are predominantly presently limited in achieving shaft output horsepower rating with 27% to 34% engine thermal efficiencies. The aero-derivative turbine engine&#39;s higher efficiencies are achieved when the gas turbine engines operate with compressor ratios ranging from 14 to 35 and predominant first stage turbine inlet temperatures ranging from 2000° to 2300° F. Typical turbocharged reciprocating-type power engine units generally have 3% to 5% higher output shaft thermal efficiencies than comparable power rated gas turbine power units having lesser overall life cycle operating costs.  
         [0009]     Existing conventional applied art gas turbine and reciprocating-type engines employ combustion chamber air/fuel combustion chemical reactions, wherein the elements of time and high peak flame temperatures increase the presence of disassociation chemical reactions that produce the fugitive emissions of carbon monoxide (CO) and other chemical reactions that produce nitrogen oxides (NO.sub.x).  
         [0010]     The best available applied turbine engine and reciprocating-type engine low NO.sub.x combustion technology for limiting NO.sub.x emissions, using near-stiochiometric air/fuel primary combustion reaction chemistry means, still results in the production of NO.sub.x and CO that are no longer acceptable for new power or energy conversion facilities in numerous states and metropolitan environmental compliance jurisdictions. With the conventional gas turbine engine or reciprocating-type engine employment of compressed atmospheric air as a source of oxygen (O.sub.2) which acts as a fuel combustion oxidizing reactant, the air&#39;s nitrogen (N.sub.2) content is the approximate 78% predominant mass component within the cycle&#39;s working motive fluid. Due to its diatomic molecular structure, the nitrogen molecules are capable of absorbing combustion heat only through convective heat transfer means predominantly resulting from their collisions with higher temperature combustion gas molecules.  
         [0011]     Despite the very brief time it takes for conventional power engines to reach a average molecular primary flame combustion zone gas equilibrium temperature of less than 2600° F. within its combustion chamber assembly or subassembly, there are sufficient portions of the combustion zone gases that experience temperatures in excess of 2600° F. to 2900° F. for an ample period of time for the highly predominate nitrogen gas to enter into chemical reactions with oxygen that produce nitrogen oxides. The same combined elements of time and sufficiently excessive high flame temperature permit carbon dioxide to enter into dissociation chemical reactions that produce carbon monoxide gas.  
         [0012]     To achieve a goal of greatly reducing a power engine unit&#39;s NO.sub.x and CO fugitive emissions, it is necessary to alter both the fuel combustion chemical reaction formula and the means by which acceptable combustion flame temperatures can be closely controlled and maintained within a power engine unit&#39;s fuel combustion assembly. Maintenance of an acceptably low selected fuel combustion peak gas temperature at all times and throughout all portions of within the combustion assembly, requires a change in the means by which the heat of combustion can be better controlled and more rapidly distributed uniformly throughout the gases contained within the fuel combustion assembly.  
       SUMMARY OF THE INVENTION  
       [0013]     To achieve both power turbine engine ultra-low NO.sub.x and CO exhaust emissions (as well as reduced “greenhouse gas” carbon dioxide (CO.sub.2) emissions and enhanced simple-cycle operating thermal efficiencies, the inventor&#39;s AES gas turbine power cycle system and apparatus is described in U.S. Pat. No. 6,532,745 dated Mar. 18, 2003. The cited invention&#39;s further described partially-open gas turbine cycle contains multiple heat recovery devices for transferring waste heat to varied process gases and steam resulting in a cogeneration facility overall maximum thermal efficiency that “may approach 100%”.  
         [0014]     The present invention describes selected process elements from the cited partially-open AES turbine power cycle and apparatus devices that can be incorporated within a simplified and improved power cogeneration system method having simplified apparatus means that can further achieve increased power cogeneration method system and apparatus thermal efficiencies which may exceed 115%.  
         [0015]     The addition of these selected apparatus assembly device alternatives to the presented power cogeneration method employing a power engine unit of the example gas turbine engine type, as later further described and shown in  FIG. 2 , may increase the presented power cogeneration system&#39;s method overall thermal efficiency to greater than 115%.  
         [0016]     To achieve the power cogeneration method system&#39;s ultra-low fugitive exhaust emissions, the presented power cogeneration system method employs a partially-open gaseous thermal fluid energy cycle and apparatus assembly devices that provides a continuous controllable mass flow rate of described recycled or “recirculated” superheated vapor-state predominant mixture of carbon dioxide (CO.sub.2) and water vapor (H.sub.2 O), the said mixture being in identical mixture Mol percent proportions as each said molecular gas component occurs as products of chemical oxy-fuel combustion reactions from the gaseous or liquid hydrocarbon fuel employed.  
         [0017]     To achieve the power cogeneration method&#39;s ability to employ gaseous hydrocarbon fuels, other than gas utility distribution quality natural gas, the cited gaseous fuels (alternately containing toxic and/or difficult to combust hydrocarbon molecular gases) can be rapidly carried through useful fuel energy to useful heat conversion and/or completed incineration with the inventions provided system method and apparatus assembly devices that control the primary and secondary combustion zones temperature. Whereas the invention example system method presented recycle exhaust gas (or alternately referred to as “recirculated cycle gas”) flow rates and temperatures are capable of producing 1800° F. tertiary zone working motive fluid gas temperatures to the example gas turbine engine&#39;s power turbine wheel sub-assembly (while maintaining herein described high thermal efficiencies and ultra-low emissions), the preferred example 2400° F. primary and outer secondary zone combustion temperature provides a desired 7.585 greater chemical reaction speed rate between a fuel and oxygen than that occurring at 1800° F. As repeatedly verified by John Zink Research in applied research, the reaction rate formula is:  
         Reaction  Rate  Increase     =       (   N   )     =         [       (     2400   ⁢   °   ⁢           ⁢     F   .     +   460         )     +     (     1800   ⁢   °   ⁢           ⁢     F   .     +   460         )       ]     -   1     .035           
 
         [0018]     Provided herein is a power cogeneration system method with apparatus assembly devices employing a partially-open gaseous thermal fluid energy cycle for use therein of either the provided example modified conventional gas turbine power engine unit configurations, or use therein of the alternative unconventional turbine power engine assembly unit apparatus configurations that can utilize separate existing low cost mechanical equipment apparatus assembly components and combustion chamber assembly or subassembly devices. The said assembly components need not to be designed for, nor applied to, either the manufacture of conventional engine power unit assemblies nor the said apparatus devices and combustion chamber assemblies or subassemblies incorporation into facility designs of current technology engine powered cogeneration facilities (or combined-cycle facilities). The cited combustion chamber assemblies or subassemblies devices are those wherein fuel combustion occurs at pressures greater than 1.5 bar absolute.  
         [0019]     The invention&#39;s combined employed cited power cogeneration method and apparatus, a partially-open gaseous thermal fluid energy cycle, and the alternative added incorporation of an oxy-fuel burner apparatus (having a fuel combustion pressure of less than 1.5 bar absolute) into the present invention therein provides for a commonly ‘shared non-air’ working motive fluid means that is essential to the 95% to 100% reduction of NO.sub.x, and CO mass flow emissions from those of conventional Low-NO.sub.x designed gas turbine and reciprocating engines and/or other conventional fuel combustion apparatus devices that can be applied within existing art power cogeneration methods and employed apparatus devices.  
         [0020]     It is an objective of the present invention&#39;s improved power cogeneration method system and apparatus means to provide a new benchmark standard for Best Available Technology (B.A.T.) in achieving combined highest thermal efficiencies, lowest emissions, and lowest auxiliary facility operating power consumptions within a overall operating power cogeneration facility.  
         [0021]     It is a further objective of this invention to provide the means by which the power cogeneration method system&#39;s production of steam or hot water, and/or the heating of process fluids, is not limited by the amount of a power engine unit/generator or power engine unit/mechanical drive train&#39;s availability of waste heat that can be derived from a given production level of electric power or mechanical horsepower.  
         [0022]     It is a further objective of this invention to provide the means by which the power cogeneration method system&#39;s presented alternative apparatus devices can comprise unconventional individual power train unit components that can be adapted to individual unit power generator ratings of 200 kW to  30  MW+ to satisfy most cogeneration facilities&#39; installed individual unit power rating requirements.  
         [0023]     It is a further objective of this invention to provide the collective means by which deviations from the presented invention&#39;s example operating conditions can be made to best accommodate a facility designer&#39;s incorporation of existing models of other facility auxiliary equipment that can be further incorporated into a specific design of cogeneration facility, said other auxiliary equipment comprising such as currently manufactured absorption chillers or mechanically-driven refrigeration chillers that have been conventionally or similarly applied in related waste heat recovery power facilities for over 30 years.  
         [0024]     It is a further objective of the present invention&#39;s cogeneration method system and apparatus devices to accomplish both a highly accelerated oxy-fuel combustion process and the added capabilities to separately control both a preset maximum primary combustion zone temperature and the tertiary zone exhaust gases temperature supplied to the example gas turbine engine unit&#39;s hot gas expansion turbine assembly. This satisfied objective eliminates the elements of time and high degree of temperature that is required for endothermic dissociation chemical reactions to occur that produces both NO.sub.x and CO within the conventional air-fuel combustion product gases.  
         [0025]     It is a further objective of the present invention of improved system method and apparatus devices that the example modified conventional gas turbine power engine unit assembly or alternative unconventional re-configured turbine engine train apparatus assembly can be capable of achieving an additional 35% to 40% in method thermal efficiencies than are available in current art B.A.T. gas turbine engine-powered cogeneration facilities.  
         [0026]     It is a further objective of the present invention of improved power cogeneration method and apparatus assembly devices, that the cited example gas turbine power engine unit and apparatus assemblies of preferred high efficiencies can employ (but not limited to) gas compression ratios of 2.4 to 6.4 (2.1 to 6.5 Bar operating pressure). These said gas compression ratios can be compared to conventional gas turbine engines having varied employed compression ratios of approximately 9 to 35.  
         [0027]     It is a further objective of the present invention of improved power cogeneration method system and apparatus assemblies that the cited combined gaseous thermal fluid energy cycle, apparatus assemblies, and example gas turbine power engine unit can provide the maximum cogeneration thermal efficiencies with facility fuel gas supply pressures of less 100 psig (6.9 bar).  
         [0028]     It is a further objective of this invention to provide the means wherein, during a steady-state power cogeneration operation, that the ‘open portion’ of the cited ‘partially-open’ gaseous thermal fluid energy cycle therein provide an approximate atmospheric-vented gas mass flow that can be approximately 5 to 8% of the total working motive fluid mass flow rate as contained within the ‘closed portion’ of the cited gaseous thermal fluid energy cycle.  
         [0029]     It is a further objective of this invention to provide the method means whereby all apparatus assemblies and devices can collectively include appropriate safety sensor/transmitter and gaseous thermal fluid flow control devices. The presented invention&#39;s power cogeneration system thermal fluid cycle streams, streams of supplied fuel and predominant oxygen, and contained apparatus assembly devices can be monitored and controlled for safe operation during all cogeneration facility operations encompassing variations in electric power generation demands and thermal fluid heat energy extraction demands from remote supplied steams of steam or hot water, or process fluids.  
         [0030]     It is a further objective of this invention to provide the combination of power cogeneration method, apparatus assembly and control devices by which a non-distribution quality of gaseous hydrocarbon fuel (containing toxic and/or difficult to combust hydrocarbon molecular gases) can be rapidly carried-forth through oxy-fuel combustion to a useful heat energy conversion and/or completed incineration without emitted toxic gas emissions to atmosphere.  
         [0031]     The following nine embodiments comprise the subject matter of this invention:  
       First Embodiment  
       [0032]     The working motive fluid of this invention&#39;s power cogeneration method system comprises a continuous superheated vapor mixture of predominant carbon dioxide (CO.sub.2) and water vapor (H.sub.2 O) in identical Mol percent ratio proportions as the molecular combustion product components Mol percent ratio proportions are produced from the combustion of the gaseous or liquid hydrocarbon employed fuel.  
         [0033]     Within the predominately-closed portion of the presented invention&#39;s cited power cogeneration method&#39;s partially-open gaseous thermal fluid energy cycle, the re-circulated power engine unit exhaust gas is routed from an exhaust gas distribution manifold (the exhaust gas having a small degree of superheat temperature and positive gage pressure supply) into the inlet of the recycle gas compressor. The exhaust gas recycle compression function can be performed by a more typical axial compressor section used for air compression within a conventional gas turbine power engine unit, or it may be a separately power driver device-driven compressor of the axial, centrifugal, or rotating positive displacement type. Either described type of compression can incorporate means of flow control available within the compressor or by its driver&#39;s varied speed, with flow changes being initiated by a power cogeneration PLC type control panel containing programmable logic microprocessors.  
         [0034]     The cited type of compressor can increase the example gas turbine power engine unit&#39;s recycled or recirculated exhaust&#39;s absolute pressure by a ratio range of only 2.4 to 6.4 to achieve a relatively high example gas turbine power engine unit “stand-alone” simple-cycle thermal efficiency, but the in the case of the said gas turbine power engine unit&#39;s incorporation into the invention&#39;s cited combined power cogeneration method and apparatus assembly devices, the gas turbine power engine unit is not limited to operations within these said ratios.  
         [0035]     As shown in Table 1, between the example gas turbine engine unit&#39;s fuel combustion pressures of 45 psia and 75 psia, the cited gas turbine power engine unit&#39;s “stand-alone” simple-cycle thermal efficiencies can range between 35.16% and 43.24%. Between 75 psia and 90 psia oxy-fuel combustion burner assembly pressures (with the common individual recycle compressor and hot gas expander power turbine assembly efficiencies of 84%, and a stage 1 turbine inlet temperature of 1800° F.), the cited gas turbine engine power unit “stand-alone” (simple-cycle) efficiencies can begin to decline.  
                                   TABLE 1                       Combustion   Gas Turbine   Gas Turbine   Gas Turbine       Thermal       Operating   Gas Inlet   Exhaust   Net Output   Gas Turbine Fuel   Efficiency       Pressure   Temperature   Temperature   Horsepower   Rate Btu/HP-Hr.   %*                   45 psia   1800° F.   1471° F.   2859   7237   35.16       60 psia   1800° F.   1391° F.   3458   5983   42.54       75 psia   1800° F.   1331° F.   3515   5885   43.24       90 psia   1800° F.   1284° F.   3406   6075   41.89                 *With a 1 Mol/minute methane gas fuel rate             
 
         [0036]     The re-cycled (or recirculated) and re-pressurized turbine exhaust gas (hereafter can be referred to as “either recycle gas, or re-pressurized recycle gas” within the cited power cogeneration method&#39;s partially-open gaseous thermal fluid energy cycle) is discharged from the recycle gas compressor at an increased temperature and pressure through a conduit manifold containing both a side-branch connection and first and second parallel conduit end-branches flow-controlled streams. The conduit manifold side-branch supplied controlled low mass flow stream of recycle gas can be reduced in temperature within an air-cooled exchanger prior to the stream flow&#39;s entry into one or more preferred partial pre-mix subassembly contained within each oxy-fuel combustion chamber assembly or subassembly. Within each referred partial pre-mix assembly, the reduced temperature recycle gas stream can be homogenously pre-mix blended with the supply stream of predominant oxygen that is also is also supplied to the preferred partial pre-mix subassembly and/or pre-mix blended with the supply stream of fuel.  
         [0037]     The fore-cited first and second parallel conduit end-branches flow-controlled streams having end-connectivity respectively to the inlets of first and second headers of the power turbine exhaust gas waste heat recovery unit (WHRU) exchanger of counter-current flow gas to gas heat exchange design. A predominate flow-controlled portion of the example gas turbine power engine unit developed high temperature exhaust is flow-directed through the cited WHRU exchanger for its heat transfer into the recycle gas stream that thereafter is downstream re-admitted into the oxy-fuel fired combustion chamber assembly.  
         [0038]     This example gas turbine power engine unit exhaust gas WHRU exchanger can be capable, with the particular example of a methane fuel combustion chamber pressure of 60 psi absolute and 1800° F. first stage hot gas expansion power turbine inlet temperature, of raising the temperature of the re-pressurized recycle gas within the turbine exhaust gas WHRU exchanger to an approximate maximum 1350° F. temperature. With these operating conditions and assumed individual compressor and hot gas expansion turbine efficiencies of 84%, the example gas turbine engine unit “stand-alone” simple-cycle thermal efficiency of 42.5% can be achieved.  
         [0039]     Thereafter, the 1350° F. highly superheated and re-pressurized recycle gas individual streams (and/or higher temperature method cycle fluid streams) can hereafter be referred to as “working motive fluid” gas streams. The first controlled stream of working motive fluid can be routed and separately flow-divided as required to the internal tertiary blending zone contained within each of one or more oxy-fuel combustion chamber assembly or subassembly that can be conventionally positioned radially about the centerline axis of the example gas turbine power engine unit. The second controlled stream can be separately flow-divided as required for passage into one or more preferred partial premix sub-assemblies contained within one or more oxy-fuel combustion chamber assembly.  
         [0040]     Within the presented power cogeneration system method, a lesser flow controlled portion of the total example gas turbine power engine unit&#39;s discharged exhaust flows through the waste heat recovery steam generator (WHRSG) exchanger or waste heat recovery process fluid (WHRPF) exchanger.  
       Second Embodiment  
       [0041]     From the First Embodiment&#39;s “the re-circulated power engine unit exhaust gas is routed from a exhaust gas distribution manifold (the exhaust gas having a small degree of superheat temperature and positive gage pressure supply) into the inlet of the recycle gas compressor”, the said re-circulated power engine unit exhaust gas within the exhaust distribution manifold comprises the discharge exhaust gas from a second WHRSG or WHRPF exchanger upstream that is inlet-connected to a re-circulated exhaust gas manifold that conveys the combined example gas turbine power engine unit&#39;s reduced temperature exhaust gases originating from both the WHRU exchanger and the first parallel-positioned WHRSG or WHRPF exchanger into which the total example gas turbine power engine unit&#39;s high temperature exhaust is first inlet-connected.  
         [0042]     Either the second WHRSG or second WHRPF exchanger can perform the initial heating of supplied streams from either a facility&#39;s steam or hot water feed circuit or a process fluid stream prior to either of these streams being further downstream flow-connected to the fore-described high temperature example gas turbine power engine unit exhaust gases first WHRSG exchanger or WHRPF exchanger.  
       Third Embodiment  
       [0043]     From the First Embodiment cited re-circulated example turbine power engine unit exhaust from the exhaust gas distribution manifold supplied to the inlet of the primary recycle gas compressor, the exhaust gas distribution manifold has a end manifold alternative system connection point and two side-branch flow delivery connections. The first side-branch conduit provides the greatly predominant flow of re-circulated exhaust gas into the inlet of the recycle gas compressor, and the second side-branch conduit directs the controlled flow of excess of re-circulated turbine exhaust gases to atmosphere during steady-state operation of the presented system. This flow of excess cited re-circulated turbine exhaust gases to atmosphere constitutes the “Open Portion” of the presented partial-open power cogeneration method system. The system steady-state condition&#39;s controlled mass flow rate, in which the re-circulated turbine exhaust is vented to atmosphere, is equivalent to the combined mass rates at which the fuel and the predominant oxygen gas streams enter the invention&#39;s provided oxy-fuel combustion system method&#39;s partially-open cycle and apparatus devices.  
       Fourth Embodiment  
       [0044]     From the First Embodiment cited “The second controlled stream can be separately flow-divided as required for passage into one or more preferred partial pre-mix sub-assemblies contained within one or more oxy-fuel combustion chamber assembly.”, each partial pre-mix sub-assembly having the following introduced controlled streams: fuel; a predominant oxygen stream which originates from an adjacent facility area containing a preferred highly electric energy efficient modular air separation system; First Embodiment described air-cooled recycle gas; and second stream of working motive fluid. These individual flow controlled conduit streams are collectively admitted through their respective pre-mixer inlet conduit means for preferred selective pre-mixing and homogeneous blending at points of admittance into the primary combustion flame zone and outer secondary zone within each oxy-fuel combustion chamber assembly.  
         [0045]     To establish primary combustion temperatures that do not exceed the example preferred maximum 2400 F, one of several possible acceptable designs of pre-mix sub-assembly can be one of wherein the oxy-fuel combustion chamber assembly (a specific method or design of which is not within the scope of the presented invention) can incorporate both a primary oxy-fuel combustion flame zone and a secondary outer zone wherein a predominant portion of the fore-described second stream of working motive fluid is introduced into a outermost flow annulus area surrounding the homogeneous mixture admitted from each pre-mix sub-assembly into the said primary combustion flame zone for ignition. The secondary outer zone introduced working motive fluid can thereby provide a closely positioned rapid heat-absorbing greater mass shrouding means around each primary combustion flame zone developed within the oxy-fuel combustion chamber assembly. This flame shrouding means can enable the radiant heat energy emanating from the lesser mass binary gas molecules within the combustion flame to be rapidly distributed to and absorbed uniformly by the described shroud&#39;s contained greater mass of identical binary gaseous molecules at the speed of light rate of 186,000 miles per second. The resulting equilibrium temperature within each oxy-fuel combustion chamber assembly&#39;s primary combustion flame zone and secondary zone, based on the controlled flow rate of the second stream of working motive fluid into the oxy-fuel combustion chamber assembly, can be established as being equal to a preset desired example of a maximum 2400° F. or other desired preset temperature that is substantially less than the temperature at which NO,sub.x and CO can be formed during endothermic disassociation chemical reactions. The example maximum 2400° F. merely represents a conservative maximum temperature to totally avoid the slightest potential of any combined production of extremely small trace amounts of NO.sub.x and companion larger amounts of CO.  
       Fifth Embodiment  
       [0046]     From the First Embodiment cited “The first controlled stream of working motive fluid can be routed and separately flow-divided as required to the internal tertiary blending zone contained within each of one or more oxy-fuel combustion chamber assembly or subassembly that can be conventionally positioned radially about the centerline axis of the example gas turbine power engine unit”, the first controlled stream of working motive fluid to the tertiary blending zone flow can be introduced into an oxy-fuel combustion chamber assembly&#39;s inner annulus area between the chamber assembly&#39;s outer casing and an inner liner surrounding each primary oxy-fuel combustion flame zone and outer secondary zone, followed by its flow emanation into the chamber assembly&#39;s downstream-positioned tertiary blending zone chamber area through openings in the said inner liner. This tertiary zone introduced mass flow of superheated working motive fluid (of example 1350° F. temperature) blends with the example maximum 2400° F. equilibrium temperature combined gases emanating from the chamber assembly&#39;s primary oxy-fuel combustion flame zone and its outer secondary zone to thereby produce a resultant example 1800° F. final oxy-fuel combustion chamber assembly exhaust equilibrium temperature to the hot gas expansion turbine assembly. The equilibrium temperature of the final oxy-fuel combustion chamber assembly exhaust gases is not limited to 1800° F., and can be controlled by the introduced tertiary working motive fluid mass flow rate and/or fuel mass flow rate to establish any other higher or lower selected operating temperature. The example 1800° F. temperature can be chosen to coincide with 10 year old proven power turbine blade metallurgy technology for continuous operation.  
         [0047]     Within the one or more hot gas expansion turbine stages, the oxy-fuel combustion chamber assembly&#39;s pressurized and highly superheated gases are expanded to create useful work in the conventional form of both turbine power engine unit output shaft horsepower and (in the case of a conventional modified gas turbine power engine unit configuration) internal horsepower to additionally direct-drive the recycle gas compressor. In a conventional 2-shaft style of gas turbine engine configuration, the recycle gas compressor can be shaft-connected to the high-pressure stage section of the power turbine assembly, and the low pressure section of the power turbine engine assembly with connected output shaft therein provides the turbine power assembly output power to driven equipment. The expanded exhaust gases exit the power turbine assembly at a low positive gage pressure and are further conveyed through conduit means to the fore-described WHRU exchanger and adjacent parallel-position WHRSG or WHRPF exchanger as further described later and shown in  FIG. 1 .  
       Sixth Embodiment  
       [0048]     In the Fifth Embodiment description “In a conventional 2-shaft style of gas turbine engine configuration, the recycle gas compressor can be shaft-connected to the high-pressure stage section of the power turbine assembly, and the low pressure section of the power turbine engine assembly with connected output shaft therein provides the turbine power assembly output power to driven equipment.”, the presented invention provides an alternative system method and apparatus devices by which an unconventional turbine power engine unit train (comprising individual separate compressor unit assembly, oxy-fuel combustion chamber assembly, and hot gas expansion turbine assembly unit with mechanical shaft output) can be configured to produce mechanical or electrical power within a cogeneration method system as described later and shown in  FIG. 2 .  
         [0049]     The invention&#39;s alternative recycle gas compressor can be a separately motor-driven or stream turbine-driven compressor of centrifugal or axial type therein comprising one or more stages of compression as required, or single rotating positive displacement type compressor for the system applied operating conditions. The re-circulated and slightly superheated turbine exhaust gas stream is re-introduced into the recycle gas compressor and increased in pressure and temperature as described for the conventional gas turbine power system. This presented style of recycle gas compression drive train generally offers greatly improved capacity control and/or turn-down capabilities, but can be overall less efficient than the conventional type gas turbine assembly&#39;s direct-driven axial compressor section.  
         [0050]     As described in the Fourth and Fifth Embodiment, the oxy-fuel combustion chamber assembly configuration and functional operation remains unchanged. Rather than the Fifth Embodiment described one or more oxy-fuel combustion chamber assembly being conventionally positioned radially about the centerline axis of the example gas turbine engine unit, the presented invention&#39;s alternative system and apparatus means can further have a single oxy-fuel combustion chamber assembly that is axially centerline-positioned and can be directed-connected to the hot gas expander power turbine as shown later in  FIG. 2 .  
       Seventh Embodiment  
       [0051]     From the Second Embodiment&#39;s cited “the said re-circulated power engine unit exhaust gas within the exhaust distribution manifold comprises the discharge exhaust gas from a second WHRSG or WHRPF exchanger upstream that is inlet-connected to a re-circulated exhaust gas manifold that conveys the combined example gas turbine power engine unit&#39;s reduced temperature exhaust gases originating from both the WHRU exchanger and the first parallel-positioned WHRSG or WHRPF exchanger into which the total example gas turbine power engine unit&#39;s high temperature exhaust is first connected.”, the total amount of exhaust waste heat that can usefully be transferred into the said heat exchanger&#39;s supplied fluids is limited to (or in proportion to) the amount of mechanical output power that is developed by the invention&#39;s power cogeneration system method employed power engine unit.  
         [0052]     The presented invention provides an alternative method system and apparatus devices by which the presented power cogeneration method&#39;s production of steam or hot water (or heating of process fluids) is independent of the amount of power engine unit developed mechanical power. This presented invention, with its described alternative method system and apparatus devices, provides this power cogeneration method with added operational flexibility while further increasing the thermal efficiency of the presented invention&#39;s cogeneration method and maintaining the same ultra-low exhaust emissions. Wherein an example presented given power cogeneration system facility of a given mechanical power output rating could fully utilize at all times a 100% or greater steam production or process fluid heating than would be associated with the cogeneration method system and apparatus devices shown in  FIG. 1 , the  FIG. 2  presented alternative cogeneration system and apparatus devices can include the presented supplementary oxy-fuel fired heating of a selected portion of combined apparatus generated recirculated system exhaust gases to achieve both the generated power and the additional production of steam or process fluid heating. The  FIG. 2  described alternative method system and apparatus provides the device means of achieving the presented overall cogeneration system thermal efficiencies that can significantly exceed 115% as shown later in Table 5 for an example 100% increase in steam or process heating beyond the  FIG. 1  system capabilities.  
         [0053]     The presented invention&#39;s alternative method system and apparatus assembly devices includes the added conduit means for withdrawal of a portion of cited combined re-circulated exhaust gases from the Third Embodiment described exhaust gas distribution manifold. The cited conduit means provides a routed supply of the re-circulated exhaust gases to the example  FIG. 2  preferred two parallel auxiliary primary recycle blowers that are separately capacity controlled to produce slightly re-pressurized first and second conduit stream flows of exhaust recycled gas that are connected to the alternative cogeneration system&#39;s auxiliary oxy-fuel fired combustion burner assembly unit.  
         [0054]     The cited oxy-fuel fired combustion burner assembly employs additional individual connected flow controlled streams of fuel and predominant oxygen to produce an identical composition of additional combustion exhaust gases as existing within the example gas turbine power engine unit&#39;s exhaust gases, whereby the said additional oxy-fuel fired combustion burner assembly&#39;s exhaust gases are conduit routed into the turbine exhaust conduit branch connecting to the WHRSG exchanger or WHRPG exchanger described above in the above cited Second Embodiment.  
         [0055]     In the case of the  FIG. 1  configuration of the presented invention&#39;s power cogeneration method system and apparatus assembly devices, any increase in power generation (beyond the then existing cogeneration system&#39;s ‘steady-state’ production condition, but not exceeding the example presented gas turbine&#39;s power engine unit output continuous rating), can be accomplished by terminating the controlled flow of vented excess turbine re-circulated exhaust flow to atmosphere and increasing the fuel flow and predominant oxygen gas flow. Only upon reaching the required accumulated increased mass flow of preset high temperature exhaust gases within the closed system, shall the presented invention&#39;s power cogeneration method system then be returned to its normal ‘steady-state’ and ‘partially-open system status’ with controlled excess re-circulated exhaust gas vented to atmosphere.  
       Eighth Embodiment  
       [0056]     From the First Embodiment cited “As shown in Table 1, between the example gas turbine power engine unit&#39;s fuel combustion pressures of 45 psia and 75 psia, the cited gas turbine power engine unit&#39;s “stand-alone” simple-cycle thermal efficiencies can range between 35.16% and 43.24%.” The invention&#39;s improved high thermal efficient power cogeneration method&#39;s presented example 60 psia oxy-fuel combustion chamber assembly therein enables a low fuel supply pressure of less than 65 psi gage (5.5 Bar) to be employed.  
       Ninth Embodiment  
       [0057]     From the preceding collective Embodiments&#39; cited control of fluid stream flows, temperatures, pressures, generated power, and apparatus means includes valves, compressors, blowers, motors, etc., the presented invention&#39;s power cogeneration method system and apparatus means can be both performance and safety monitored and controlled by a manufacturer&#39;s PLC based control panel design that meets or exceeds the power cogeneration facility&#39;s applicable industry and governmental standards and codes, and as is applicable to the power cogeneration method&#39;s specifically employed apparatus assembly devices. The operating power cogeneration method system&#39;s operating data signals can comprise, but not limited to: 
    (a) the power cogeneration method system&#39;s apparatus connecting conduits containing individual valve controlled gas stream&#39;s mass flows with temperatures and pressures for a given operating hydrocarbon fuel composition and horsepower or kilowatt output, and effective waste heat transfer duty;     (b) the power cogeneration method system&#39;s power engine unit exhaust and waste heat recovery unit&#39;s fluid conditioning status and power engine unit exhaust excess oxygen content for a given operating hydrocarbon fuel composition;     (c) the power cogeneration method system&#39;s power engine unit exhaust and recycle gas compressor discharge mass flow rates through their respective downstream waste heat recovery exchangers;     (d) the power cogeneration method facility&#39;s auxiliary rotating equipment&#39;s operating mass flow rates with temperatures and pressures combined with the positioning-state of any rotating equipment&#39;s integral capacity control apparatus;     (e) the power cogeneration method facility&#39;s rotating equipment and alternative blower/oxy-fuel fired combustion burner assembly safety monitoring condition point locations as set forth by the prevailing industry or government specifications for each type of equipment, as well as those monitoring points whose operating condition state can impact on the power cogeneration method apparatus assembly device&#39;s operational on-line availability and equipment life cycle costs.    
 
       Overall System Method and Apparatus Means  
       [0063]     Within the presented improved power cogeneration system method and apparatus assembly devices described herein, the provided system employed oxy-fuel combustion generated working motive fluid means can provide a 95 to 100% reduction of nitrogen oxides (NO.sub.x) that occurs within current art Low-NO.sub.x employed type of power engine units. The partially-open gaseous thermal fluid energy cycle contained within the cited power cogeneration method&#39;s provides a temperature controlled oxy-fuel combustion temperature and the speed of combustion flame heat transfer that also similarly suppresses the chemical reaction dissociation formation of the fugitive emission carbon monoxide (CO) from carbon dioxide (CO.sub.2). The means of suppressing the development of fugitive emissions results from the following collective working motive fluid molecular attributes and combustion events: 
        (a) The working motive fluid of this invention&#39;s power cogeneration method system and apparatus devices comprises a continuous superheated mixture of predominant carbon dioxide (CO.sub.2) and water vapor (H.sub.2 O) in identical Mol percent ratio proportions as these molecular components are produced from the combustion of a given fuel. For example, in the case of landfill gas, the working gas fluid contains a 1:1 ratio of 2 Mol carbon dioxide to 2 Mols water vapor in identical proportion to the products of stoichiometric oxygen combustion. The chemical reaction equation can be described as follows: 
 
Working Motive Fluid+1  Mol  CH. sub. 4+1  Mol  CO. sub. 2+2  Mols  O. sub. 2=2  Mol  CO. sub. 2+2  Mol  H. sub. 2 O+Heat+Working Motive Fluid. 
 
 In the example of methane gas fuels, the working fluid composition contains a ratio of 1 Mol CO.sub.2 to 2 Mols H.sub.2 O in identical proportion to the products of 105% stoichiometric oxygen combustion of methane fuel within the chemical reaction equation of: 
 
Working Motive Fluid+1  Mol  CH. sub. 4+2.1  Mols  O. sub. 2=1  Mol  CO. sub. 2+2  Mols  H. sub. 2 O+0.1  Mol  O. sub. 2+Heat+Working Motive Fluid; 
    (b) The invention&#39;s power cogeneration system&#39;s method&#39;s working fluid provides the replacement mass flow means to conventional open power cycles incorporating the predominant diatomic non-emissive and non-radiant energy absorbing molecular component nitrogen (N.sub.2) within the cited-conventional cycles working motive fluid. The invention&#39;s replacement working motive fluid contains both predominant water vapor (with a binary lack of molecular symmetry) and a mass ratio of atomic weights of (16/2)=8 and carbon dioxide with a mass ratio of atomic weights of (32/12)=2.66, which denotes their susceptibility to high radiant energy emissivity and absorption. This compares to the nitrogen&#39;s mass ratio 14/14=1 which denotes nitrogen&#39;s minimal, if any, emissive and radiant energy absorbing abilities at any temperature;     (c) The presented invention&#39;s power cogeneration method&#39;s cycle system&#39;s controlled flow of working motive fluid into the oxy-fuel combustion chamber assembly therein provides the said assembly&#39;s interior gaseous environment with an approximate 900% increase of binary molecular mass means susceptible to the fuel/oxidation exothermic chemical reactions generated combustion heat transfer being highly accelerated at the speed of light (186,000 miles a second). The cited highly accelerated rate of combustion heat transfer to the highly predominant interior binary gases within the cited combustion apparatus assembly, provides the means by which a controlled highly superheated temperature equilibrium state of accelerated fuel and oxygen reaction rates is maintained without the prospect of developing CO2 disassociation reactions that produces CO in the presence of the highly elevated gas molecular temperatures above 2600° F. to 2900° F.;        
 
         [0067]     The cited binary gases being comprised of individual binary carbon dioxide and binary water vapor molecular gases whose individual molecular mass heat energies are separately emitted or adsorbed in their own individual and specific narrow and unique infrared spectral ranges.  
         [0068]     The radiant heat is transferred from the cited binary carbon dioxide and binary water vapor combustion gaseous products in their specific Mol % proportions as determined by the molecular fuel being combusted, the said gaseous Mol % proportions being sustained throughout the gaseous thermal fluid energy cycle, including the working motive fluid that enters the fuel combustion chamber assembly device along with supplied fuel and oxygen. 
        (d) The First Embodiment recited oxy-fuel combustion chamber assembly pre-mix sub-assemblies provides the means for homogeneous blending, wherein gaseous streams of working motive fluid and an oxygen-rich stream can be further homogeneously blended for downstream mixing and ignition with the gaseous fuel stream. The gaseous fuel stream also comprises binary molecules of high susceptibility to high radiant energy absorption and emissivity, such as methane with a mass ratio of atomic weights of (16/4)=4, ethane with a mass ratio of atomic weights of (24/4)=6, propane with a mass ratio of atomic weights of (36/8)=4.5, etc;     (e) The subsequent tertiary zone admission of a controlled-flow of Table 1 identified 1350° F. superheated working motive fluid into the example 2400° F. combustion chamber assembly&#39;s primary oxy-fuel combined primary combustion flame zone and its outer secondary zone combustion gas stream, results in the rapid creation of the example desired equilibrium temperature of 1800° F. This rapid establishment of the preferred equilibrium temperature is due to the 186,000 miles per second rate of radiant heat transfer between the two streams of common molecular constituents with common means of high radiant energy absorption and emissivity in their respective individual infra-red spectrum ranges.        
 
         [0071]     The presented improved power cogeneration method and apparatus devices employ a partially-open gaseous thermal fluid energy cycle therein incorporating an oxy-fuel fired combustion system&#39;s apparatus assembly generated working motive fluid gases of optimum selected operating pressures and temperatures that can achieve 115% or greater power cogeneration facility thermal efficiencies. The means of achieving these 40% to 50% increased thermal efficiencies than those thermal efficiencies provided by current art conventional cogeneration power facilities (thereby reducing CO.sub.2 “greenhouse mass flow emissions” by 40% to 50%), results from the following improved power generation method and apparatus devices, employed partially-open gaseous thermal fluid energy cycle, and the collective working fluid molecular thermal characteristics or attributes comprising: 
        (a) The oxy-fuel combustion chamber assembly&#39;s low operating pressures reduces the work (per pound of primary recycled gas) that is adsorbed by the employed power engine unit&#39;s compressor apparatus assembly, the said compressor re-pressurizing the recycled power engine unit exhaust gas stream that subsequently becomes the downstream highly superheated working motive fluid that is expanded through the employed power engine unit&#39;s hot gas expansion power output assembly;     (b) The presented improved power cogeneration method system working motive fluid molecular gas composition replaces air content nitrogen that is the predominant mass flow molecular gas component in a conventional internal combustion engine&#39;s working motive fluid. The presented improved power cogeneration method system working motive fluid is unique in that each highly superheated temperature pound of fluid can adsorb or exchange approximately 42% more heat per degree Fahrenheit change in gas temperature than does air or nitrogen.     (c) In the presented example operating conditions, approximately 92% of the high temperature example gas turbine power engine unit exhaust heat energy that is recovered from within the total exhaust flow passing through the WHRU exchanger and first WHRSG exchanger (or WHRPF exchanger) is transferred back into the pressurized working motive fluid that will re-enter the oxy-fuel combustion chamber assembly to further absorb the heat of fuel combustion.     (d) Approximately 92 to 95% of the presented improved power cogeneration method system&#39;s re-circulated exhaust downstream of the waste heat exhaust exchangers (therein still containing a large ‘heat sink’ quantity of energy) can approximately be recycled within the closed portion of the improved power cogeneration method system during steady-state operation. During an increased energy output demand on the presented power cogeneration method system, 100% of the presented improved cogeneration method system&#39;s re-circulated exhaust heat capacity downstream of the waste heat exhaust exchangers can be recycled during its accompanying ‘total-closed’ cycle method system operation.     (e) The presented improved power cogeneration method system employed partially-open gaseous thermal fluid energy cycle, and the described operating characteristics of the continuous and uniform superheated gaseous heat transfer fluid, enables the presented power cogeneration method to annually maintain a continuous facility power output rating without any imposed site ambient temperature derations.        
 
         [0077]     With the presented example turbine power engine unit cogeneration method system and apparatus assembly devices described herein, or including the presented alternative system power cogeneration method and employed apparatus assembly devices, either a modified conventional gas turbine power engine unit apparatus train or an unconventional turbine power engine unit train comprised of two or more apparatus assemblies can be employed. An alternative turbine power engine unit assembly unit apparatus configuration can utilize separate existing low cost mechanical equipment components and combustion chamber and burner assemblies which can be predominantly not designed for, nor applied to, the manufacture of conventional gas turbine power engines, nor the said components&#39; incorporation into facility designs of current technology power cogeneration facilities.  
         [0078]     Within the presented power cogeneration method system and apparatus assembly devices described herein, the presented invention provides an alternative improved power cogeneration method and apparatus assembly devices by which a power cogeneration-method system&#39;s production rate of steam or hot water (or heating of process fluids) can be independent of the actual percentage of full-rated mechanical or electric power load that is being produced from the described power cogeneration method system. The presented example alternative power cogeneration method system and apparatus assembly devices is not limited in its ability to have expanded steam or hot water or process fluid heating capacity capabilities beyond that which is possible solely from a power engine unit&#39;s exhaust gas waste heat utilization.  
         [0079]     Within the presented power cogeneration method system and apparatus assembly devices described herein, the apparatus assembly devices are provided wherein all fluid streams entering the oxy-fuel combustion chamber assembly (and alternative combustion burner assembly) are controlled to maintain preset maximum combined primary combustion flame zone and outer secondary zone temperatures in which a non-distribution quality of gaseous hydrocarbon fuel (containing toxic and/or difficult to combust hydrocarbon molecular gases) can be rapidly carried through the oxy-fuel combustion method to a useful heat conversion and/or completed incineration without significantly altering the method system&#39;s high thermal efficiencies or ultra-low emission levels. 
     
    
     BRIEF DESCRIPTION OF THE DRAWINGS  
       [0080]      FIG. 1  is a schematic flow diagram of the invention&#39;s improved power cogeneration method system and apparatus devices employed within a partially-open gaseous thermal fluid energy cycle therein incorporating an example modified configuration of a conventional gas turbine power engine unit and simplified waste heat transfer apparatus for either steam or hot water generation, or process fluid heating.  
         [0081]      FIG. 2  is a schematic flow diagram of the invention&#39;s improved cogeneration method system that includes the presented partially-open gaseous thermal fluid energy cycle of  FIG. 1 , and additional alternative example comprising a non-conventional turbine power engine unit and apparatus assembly devices including an alternate separate motor or steam turbine driven recycle or recirculated exhaust gas compressor, an oxy-fuel combustion chamber assembly series-connected to a hot gas expander turbine device, and an alternative supplementary blower/oxy-fuel fired combustion burner assembly that can sustain rated steam or hot water production or heating of process fluids irregardless of the said example non-conventional turbine power engine unit&#39;s output of mechanical or electric power. 
     
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT  
       [0082]     Referring now more particularly to  FIG. 1 , an example modified conventional gas turbine engine power unit&#39;s exhaust recycle gas compressor section  1  comprises two or more recycle exhaust gas compression stages, positioned in series, with a final stage of radially directed discharge flow of compressed or re-pressurized recycle exhaust gas. In the case of a two-shaft turbine engine, the power to drive the recycle gas compressor section  1  is transmitted by shaft  2 , on which one or more high-pressure power extraction turbine stages are mounted within the combustion hot gas expansion power turbine assembly  3 . The second shaft, designed for mechanical equipment or generator drive applications, has one or more low-pressure hot gas expansion power stages mounted on power output shaft  4 , with coupling means for power transmission to rotate the driven equipment.  
         [0083]     The invention&#39;s improved power cogeneration method adaptation to modified conventional gas turbine engine driven mechanical equipment may or may not require the addition of a gearbox or variable speed coupling  5  to adapt the speed of the hot gas expansion power turbine assembly  3  to the speed required by a generator or other driven equipment (not shown). The rotating driven equipment may have its required power transmitted through a shaft and coupling device  6 . The shaft and coupling means device  6  can transmit power to a generator  7 , wherein electric power is produced and transmitted through conduit means  8  to a control room module  9 . Control room module  9  therein can contain the turbine power engine unit&#39;s PLC control panel, electrical switchgear, and motor control center, whereby electric power production is controlled and distributed to the power cogeneration facility&#39;s electrical grid and/or connected electric utility electrical grid. The shaft and coupling device  6  may alternately transmit power to other rotating pumps or compressors (not shown) in lieu of generator  7 .  
         [0084]     Within the presented invention&#39;s improved power cogeneration system method, including a partially-open gaseous thermal fluid energy cycle and apparatus devices, the slightly superheated example turbine power engine unit&#39;s re-circulated exhaust gas flows from the exhaust gas distribution manifold  10  (having end-connection  62  that is blind-flanged closed in this  FIG. 1 ) through said manifold side-branch connected exhaust recycle gas conduit means  11  that is end-connected to the inlet of the recycle gas compressor section  1 . The higher-pressure and higher-temperature compressed gas discharged from the recycle gas compressor section  1  (hereafter referred to as “recycle gas, or re-pressurized recycle gas”) is routed through conduit manifold  12  containing two parallel conduit end-branches  13  and  14  respectively, either one or both said conduit branch therein containing a gas mass flow sensor means and a flow control (or flow proportioning) damper valve  15 .  
         [0085]     The twin parallel conduit end-branches  13  and  14  respectively convey first and second primary re-pressurized recycle gas streams with respective end connections to parallel inlet headers  16  and  17  located on the section  18  of the example turbine power engine unit&#39;s exhaust gas waste heat recovery unit (WHRU) exchanger. The said first and second streams of re-pressurized recycle gas is discharged from section  18  of the cited turbine power engine unit&#39;s WHRU exchanger through outlet headers  20  and  19  respectively at highly increased superheated temperatures (with the highly superheated recycle gas hereinafter referred to as a “working motive fluid”) with flows through conduits  21  and  22  respectively.  
         [0086]     The re-pressurized recycle gas additionally can be routed at low gas flow levels from conduit manifold means  12  through a side-branch connected conduit means  23  containing motor driven air-cooler  24  and flow control valve  25  for subsequent downstream conduit end-connection to one or more partial premix sub-assemblies  27  that can be contained within one or more oxy-fuel combustion chamber assembly  26 , the said assembly may therein preferably be conventionally positioned radially about the centerline axis of the cited turbine power engine unit assembly.  
         [0087]     Conduit  22  conveys the second controlled stream of working motive fluid to the internal primary combustion zone  28  contained within each oxy-fuel combustion chamber assembly  26 . Conduit  21  conveys the first controlled stream of working motive fluid to the internal tertiary blending zone  29  contained within each oxy-fuel combustion chamber assembly  26  that can be positioned radially about the centerline axis of the turbine assembly. The combined streams of working motive fluid composition gases exiting tertiary blending zone  29  can be routed through conduit flow means  30  having end connection to the inlet of the hot gas expansion power turbine assembly  3 .  
         [0088]     Alternately the conduit  21  can convey the first controlled stream of working motive fluid to a common single tertiary blending zone that receives primary combustion zone working fluid composition gases from two or more oxy-fuel combustion chamber assembly  26  that is positioned immediately upstream of the described alternate single common (not shown) tertiary blending zone. The combined streams of working motive fluid composition gases exiting the common tertiary blending zone (not shown) are routed through conduit  30  having end connection to the inlet of the hot gas expansion power turbine assembly  3 .  
         [0089]     A pressurized stream of presented example methane fuel gas (or alternate acceptable liquid hydrocarbon fuel) is supplied from source  31  into conduit  32  that therein can contain sensor-transmitter devices for temperature, pressure, mass flow, and a fuel flow control valve device  33 , with said conduit having end-connectivity to either one or more preferred downstream partial pre-mix subassembly  27  contained within oxy-fuel fired combustion chamber assembly  26 .  
         [0090]     A controlled pressurized stream of predominant oxygen gas is supplied from a facility remote source  34  into conduit  35  that may contain sensor-transmitter devices for oxygen %, temperature, pressure, mass flow, and a flow control valve device  36 , with said conduit having end-connectivity to either one or more preferred partial pre-mix subassembly  27  contained within oxy-fuel combustion chamber assembly  26 .  
         [0091]     Within the partial pre-mix subassembly  27 , the said identified conduits  23 ,  32 , and  35  respectively supplied controlled stream flows of re-pressurized recycle gas, fuel, and predominant oxygen are therein partially blended therein for following downstream ignition and controlled temperature combustion within the temperature sensor-transmitter monitored primary combustion zone  28  therein having further admitted second controlled stream of working motive fluid composition gases supplied by conduit  22 .  
         [0092]     Within oxy-fuel fired combustion chamber assembly  26 , the combined mass flow of products of fuel combustion and streams of working motive fluid composition gases flows from the primary combustion zone  28  at a controlled highly superheated presented example equilibrium temperature of 2400 F into the downstream positioned tertiary blending zone  29  wherein these said gases are blended with the controlled mass flow of fore-described conduit  21  supplied first stream of working motive fluid composition gases.  
         [0093]     The combined working motive fluid composition gases&#39; mass flows entering the tertiary blending zone  29  within oxy-fuel fired combustion chamber assembly  26 , Mixing together with primary combustion zone gases, therein produces a resultant selected equilibrium temperature and mass flow rate of superheated working motive fluid gases through conduit  30  into the hot gas expansion power turbine subassembly  3 . Work is developed within the hot gas expansion power turbine subassembly  3 , and the heat energy or enthalpy (Btu/lb) contained within the mass flow of expanded and exhausted working motive fluid gases is decreased and discharged into conduit  37 . Conduit  37  routes the hot gas expansion power turbine subassembly exhaust gases through conduit end-branches  38  and  41  that are respectively connected to WHRU exchanger  18  and waste heat recovery steam generator (WHRSG) or waste heat recovery process fluid heater (WHRPF) exchanger  42 . The proportional division of the total mass flow of the hot gas expansion power turbine subassembly  3  exhaust gas contained within conduit  37 , between conduit end-branches  38  and  41 , can be flow-controlled or flow-proportioned respectively by damper valves  40  and  44  contained within the WHRU exchanger  18  and WHRSG or WHRPF exchanger  42  respective outlet exhaust branch conduits  39  and  43 . The predominant portion of conduit  37 &#39;s total mass flow of exhaust gases is divided and directed through WHRU exchanger  18  to satisfy the working motive fluid exhaust heat transfer requirements to the cited lower temperature re-pressurized recycle gas flowing through exchanger  18 .  
         [0094]     In the case of waste heat transfer to a power cogeneration facility&#39;s supplied hot water/steam or process fluid circuit, a pressurized stream of a power cogeneration facility&#39;s steam condensate feed water (or process fluid) can be supplied from source  46  into conduit  47  that can therein contain sensor-transmitter devices for both temperature and mass flow, and having end-connectivity to the inlet header  48  of a second WHRSG or WHRPF exchanger  49 . In the case of stream generation, the supplied stream of steam condensate can be changed from a liquid phase to a liquid/vapor 2-phase state or slight superheated steam vapor state within exchanger  49 , and exits from exchanger  49  through discharge header  50  into conduit  51  having end-connectivity to the inlet header  52  of the first WHRSG exchanger  42 . Within WHRSG exchanger  42 , the steam circuit stream can be highly superheated as desired to provide a power cogeneration facility produced steam superheat temperature that can range from less than 900° F. to over 1200° F. for discharge from outlet header  53  into conduit  54  end-connected to point  55 . For the alternative addition of the presented improved power cogeneration method&#39;s system having increased or independent mass flow steam generation (as described later in  FIG. 2 ), the hot gas expansion power turbine subassembly exhaust gas conduit  37 &#39;s end-branch conduit  41  can be supplied with a connected side-branch conduct  56  whose end flange connection  57  can be closed with a blind-flange cover in  FIG. 1 .  
         [0095]     The presented power cogeneration method system&#39;s reduced temperature exhaust gases exits from the WHRU exchanger  18  and the parallel-positioned WHRSG exchanger or WHRPF exchanger  42  (as earlier recited) through their respective exhaust gas discharge branch conduits  39  and  43 , each branch conduit respectively therein can contain controlled-flow damper valves  40  and  44 . The reduced temperature re-circulated exhaust gas flows from branch conduits  40  and  44  are combined within re-circulated exhaust gas manifold  45  having end-connectivity to a downstream-positioned second WHRSG exchanger or WHRPF exchanger  49 . The power cogeneration method&#39;s re-circulated exhaust gases are reduced in temperature within the second WHRSG exchanger or WHRPF exchanger  49  to a temperature that can be slightly above the dew point temperature of the re-circulated exhaust gas as it is discharged from the heat exchanger  49  into the exhaust gas distribution manifold  10 .  
         [0096]     Within the presented invention&#39;s power cogeneration method included partially-open gaseous thermal fluid energy cycle and apparatus devices, the slightly superheated example turbine power engine unit&#39;s re-circulated exhaust gas mass flow within exhaust gas distribution manifold  10  remains at a constant flow rate during steady-state power cogeneration thermal energy conversion operations. During the recited steady-state operation, the recited method&#39;s generated excess of slightly superheated re-circulated exhaust gas mass flow within manifold  10 , can be flow-directed from manifold  10  through side-branch conduit  58  having downstream connectivity to atmosphere at vent point  61 , and said conduit may therein contain back pressure control valve  59  and flow control valve  60 . The terminal end of exhaust gas distribution manifold  10  is provided with a closed blind flange connection  62  in  FIG. 1 .  
         [0097]      FIG. 2  is a schematic flow diagram of the invention&#39;s improved power cogeneration method system as shown in  FIG. 1 , but therein having specifically added described alternative apparatus assembly devices that can include both an alternate separate motor or steam turbine driven recycle gas compressor and an oxy-fuel combustion chamber assembly that is series-connected to a separate hot gas expansion turbine having an output power shaft.  FIG. 2  further shows the power cogeneration method&#39;s included partially-open gaseous thermal fluid energy cycle and apparatus devices with the recited alternative addition of a separate oxy-fuel fired combustion burner assembly that performs the function of a supplementary hot exhaust gas generator that can increase the power cogeneration system&#39;s method production of either steam, hot water, or the heating of process fluids.  
         [0098]     Referring now more particularly to  FIG. 2 , the recited alternative separately driven recycle gas compressor  63  can comprise two or more recycle gas compression stages, with a final gas compression stage that can incorporate an outward radially-directed discharge flow of re-pressurized recycle gas. The recycle gas compressor  63  can alternately be directly driven by either an electric motor or a steam turbine type driver  64 , or the said compressor indirectly-driven through either gearbox or variable speed coupling assembly device  65 . The recited hot gas expansion power turbine assembly  67  can comprise one or more power extraction turbine stages and an assembly output shaft that can be directly connected to electrical generator  7  wherein electric power is produced and transmitted through conduit means  8  to a control room module  9 . Control room module  9  therein contains the power cogeneration system&#39;s PLC control panel, and an electrical switchgear and motor control center which provides the means by which electric power production can be controlled and distributed to the operating facility&#39;s electrical grid and/or to the utility electrical grid. Alternately (not shown), a gearbox or variable speed coupling can be positioned between the power turbine assembly output shaft and alternative driven rotating pumps or compressors (not shown) in lieu of generator  7 .  
         [0099]     Referring now more particularly to  FIG. 2  and the flows of thermal fluids within the partially-open gaseous thermal fluid energy cycle contained within the presented invention&#39;s power cogeneration method containing alternative apparatus assembly devices. The slightly superheated exhaust recycle gas can flow from the exhaust gas distribution manifold  10  with exiting flows through open end-connection  62  that series-connects to manifold extension conduit  68  as further described later. Manifold  10  side-branch connected exhaust recycle gas conduit means  11  is end-connected to the inlet of the exhaust gas recycle gas compressor  63 . The higher-pressure and higher-temperature re-pressurized recycle exhaust gas (hereafter referred to as “re-pressurized recycle gas”) and related identical stream flows are thereafter the same as described as in  FIG. 1  for its routing through WHRU  18  and continuing to oxy-fuel fired combustion chamber assembly  26 . The highly superheated working fluid gases emitted from the oxy-fuel combustion chamber assembly  26  are routed through direct-connected gas transition assembly  66  with end connectivity to the inlet of the hot gas expansion power turbine assembly  67 .  
         [0100]     Conduit  37  routes the hot gas expansion turbine assembly  67  exhaust gases through conduit end-branches  38  and  41  that are respectively connected to WHRU exchanger  18  and WHRSG or WHRPF exchanger  42  and thereafter described associated conduit streams are as described for  FIG. 1 . For the alternative addition of the power cogeneration method&#39;s developed generation of additional thermal heat for transfer to steam, hot water, or process streams, fore-described conduit  68  can route a flow of slightly superheated exhaust recycle gas through preferred parallel end-branch conduits  69  and  70  that respectively can contain flow proportioning or flow control provided isolation/damper valves  71  and  72  and having end connectivity with one or more parallel-positioned  73  and  74  speed-controlled motor-driven exhaust recycle gas blowers. Exhaust recycle gas blower  73  provides a required mass flow of exhaust recycle gas at a slightly increased pressure into its discharge conduit  75  having end-connectivity with the tertiary blending zone  82  contained within the downstream-positioned oxy-fuel fired combustion burner assembly  79 . Exhaust recycle gas blower  74  provides a required mass flow of exhaust recycle gas at a slightly increased pressure into its discharge conduit  76  having end-connectivity with the partial pre-mix subassembly  80  contained within the downstream-positioned oxy-fuel fired combustion burner assembly  79 .  
         [0101]     A controlled stream of low pressure predominant oxygen gas mixture is supplied from facility remote source  77  into conduit  84  that can contain sensor-transmitter for oxygen %, temperature, pressure, mass flow, and oxygen flow control valve device  85 , with said conduit  84  having end-connectivity to either one or more preferred partial pre-mix subassembly  80  contained within oxy-fuel fired combustion burner assembly  79 .  
         [0102]     A low pressure stream of presented example methane fuel gas (or alternate acceptable liquid hydrocarbon fuel) is supplied from source  78  into conduit  86  that can contain sensor-transmitter means for temperature, pressure, mass flow, and fuel pressure/flow control valve means  87 , with said conduit  86  having end-connectivity to either one or more downstream-positioned preferred partial-premix subassembly  80  contained within oxy-fuel fired combustion burner assembly  79 .  
         [0103]     Within the partial pre-mix subassembly  80 , the said identified conduits  76 ,  86 , and  84  respectively supplied stream flows of exhaust recycle gas, fuel, and predominant oxygen gas mixture are therein blended for following downstream ignition and controlled temperature combustion within the temperature sensor-transmitter monitored primary combustion zone  81  contained within oxy-fuel fired combustion burner assembly  79 .  
         [0104]     Within oxy-fuel fired combustion burner assembly  79 , the predominant mass flow of combined products of fuel combustion and exhaust recycled gas flows from the primary combustion zone  81  (at a controlled high superheated presented example equilibrium temperature of 2400 F) into the downstream tertiary blending zone  82  wherein these said composition gases can be blended with the controlled mass flow of fore-described conduit  75  supplied blower discharge stream of slightly re-pressurized and low superheated exhaust recycle gases of identical molecular and Mol % gas composition.  
         [0105]     The oxy-fuel fired combustion burner assembly  79  provides a supplementary mass flow of slightly re-pressurized and highly superheated recycle exhaust gas (which now can be referred to as “working motive fluid gas”) at controlled temperatures into conduit  83  having end connectivity to conduit  56 &#39;s flanged connection  57 . The supplementary mass flow of slightly re-pressurized and highly superheated working motive fluid gas flow is routed through conduit  56  into branch conduit  41  having connectivity to WHRSG exchanger or WHRPF process fluid exchanger  42 , thereby enabling an increased mass flow of steam or hot water or process fluids (in conduits  47 ,  51 , and  54  at given desired temperature operating conditions) to be transmitted through the WHRSG or WHRPF exchangers  49  and  42  from the invention&#39;s increased conduit  41  mass flows of highly superheated working motive fluid gas and conduit  45  recirculated exhaust gas mass flows of lesser superheat gas temperature.  
         [0106]     Within the presented invention&#39;s improved power cogeneration system method, the slightly superheated partially-open cycle gaseous thermal fluid&#39;s recycle exhaust gas mass flow within conduit  11  remains at a constant flow rate for steady-state example hot gas expansion turbine shaft horsepower output production. The excess slightly superheated recycle exhaust gas mass flow within manifold  10  that is not required for steady-state power production, nor is required to maintain an existing steady-state recycle exhaust gas mass flow rate within conduit  68  for the oxy-fuel fired combustion burner assembly  79 , is flow-directed from manifold  10  through side-branch conduit  58  that can contain back pressure control valve  59  and flow control/isolation valve  60  with downstream connectivity to atmosphere occurring at vent point  61 .  
         [0107]     The numbers in Table 2 below are representative of: one example set of fluid stream conditions in which the thermal fluid energy cycle contained within the presented power cogeneration method system can operate (the conduit streams are those identified by the numbers in  FIG. 1 ). The following assumptions were made: the recycle gas compressor efficiency and hot gas expansion turbine efficiency are both 84%; the oxy-fuel combustion burner assembly operating pressure is 60 psia; and the methane fuel gas flow rate is 1 Mol/minute.  
                                                     TABLE 2                       Conduit                       Stream   Stream   Temperature   Pressure   Mass Flow       Number   Fluid   Degree F.   PSIA   lbs./Min.                                11   Recycle Exhaust   197   15   1879       12   Compressed Recycle   500   64   1879       22   WMF - Primary Zone   1350   63   686       21   WMF - Tertiary Zone   1350   63   1153       23   Cooled Compressed   280   63.5   40           Recycle       32   Methane Fuel   70   85   16       35   Predominant O.sub.2   110   65   64       30   Combustion Working   1800   60   1959           Motive Fluid       37   Turbine Engine Exhaust   1391   15.8   1959       45   WHRU &amp; WHRSG   530   15.4   1959           Exhaust       58   Cogen System Method   197   15.1   81           Vent Gas                 (WMF) = Working Motive Fluid             
 
         [0108]     With the same example stream conditions and assumptions made for Table 2, supra, Table 3 provides the thermodynamic values from which the tabulated compressor horsepowers and example power engine unit power outputs are derived.  
                                                 TABLE 3                       Conduit   Rotating               Delta   Horse-       Stream**   Equipment   Stream   Temperature   Mass Flow   Enthalpy   Power       Number   Name   Fluid   Degrees F.   lbs./Min.   Btu/Lb.   (HP)                   11 to 12   Exhaust   Inlet    197   1879    98.9   4377           Recycle   Discharge    500           Compressor       30 to 37   Hot Gas   Inlet   1800   1959   169.7   7837           Expander   Discharge   1391           Turbine            Net Shaft Horsepower Output   3460 SHP*                 *Note: (20,693,400 LHV Btu/Hr-Mol CH4) ÷ 3460 SHP = 5980 Btu/Hp-hr. fuel rate.            *Note: Fuel Rate: (2545 Bt/Hp-hr. ÷ 5980 Btu/Hp-Hr. = 42.55% turbine engine thermal efficiency:            **Note: Only the conduit stream numbers reference to both  FIG. 1  and  FIG. 2  drawings.             
 
         [0109]     With the same conditions and assumptions made for Table 2, supra, Table 4 contains six conduit streams (as noted) that appear in both  FIG. 1  and  FIG. 2 , with the thermal heat transfers and mass flow rates pertaining only to the  FIG. 1  presented improved power cogeneration method system and apparatus assemblies.  
                                                                                   TABLE 4                       Conduit   Heat       Temperature   Mass   Delta   Recovered       Stream   Exchanger   Stream   Change   Flow   Enthalpy   Heat Rate       Number   Name   Fluid   Degrees F.   lbs./Min.   Btu/Lb.   Btu/Min.                                37 to 45   18 + 42   Total Exhaust   1391 F. to 530 F.   1959   326   638,634       38 to 39   WHRU 18   Exhaust Gas   1391 F. to 530 F.   1805.15   326   588,480       13/14-21/22   WHRU 18   ‘WMF’ Gas    500 F. to 1350 F.   1839   320   588,480       41 to 43   WHRSG 42   Exhaust   1391 F. to 530 F.   153.85   326    50,154*       45 to 10   WHRSG 49   Exhaust    530 F. to 197 F.   1959   110    215,490*                    *Total Available Heat for Process Gas =   (215,490 + 50,154) =     265,644 Btu/Min.       or Steam Circuit       *Total Available Heat for Process Gas   (265,644 Btu/Min. × 60) =   15,938,640 Btu/Hr.       or Steam Circuit =       Total 910 Btu/SCF LHV of 1 Mol/Min.    344,890 Btu/Min. =   20,693,400 Btu/Hr.       Methane Fuel Gas =       Recovered Heat Rate from the Supplied   = (15,938,640 Btu/Hr ÷ 20,693,400   77.02%.       Fuel Gas Energy:   LHV Btu/Hr-Mol Methane Gas) =       Total Improved Cogeneration Method   = 42.5% Simple Cycle Turbine    119.5%.       System Thermal Efficiency:   Power Engine Unit Energy           Conversion Efficiency + 77.02%           Recovered Heat Rate =          
 
         [0110]     With the same conditions and assumptions made for Table 2 and 4 supra, Table 5 provides the thermal heat transfers and mass flow rates as contained within the Alternative Cogeneration Method System of  FIG. 2  with added supplementary heat blended into the hot gas expansion turbine exhaust stream to increase the cogeneration method system&#39;s apparatus assemblies effective transfer of heat to steam or process heated fluids by the example amount of 100%.  
                                                     TABLE 5                       Conduit   Heat       Temperature   Mass   Delta   Recovered       Stream   Exchanger   Stream   Change   Flow   Enthalpy   Heat Rate       Number   Name   Gas   Degrees F.   lbs./Min.   Btu/Lb.   Btu/Min.                   38 to 39   WHRU 18   Turbine Exh.   1391 F. to 530 F.   1805   326   588,480        13/14-21/22   WHRU 18   ‘WMF’ Gas    500 F. to 1350 F.   1839   320   588,480        41/83-43   WHRSG 42   Exhaust   1391 F. to 530 F.    763   326   248,738*       45 to 10   WHRSG 49   Exhaust    530 F. to 197 F.   2568   110   282,480*       10 to 11       Recycle       1879       10 to 68       Recycle    197 F.    556       10 to 61       Exhaust Vent        138       35 + 84       95% Oxygen Mixture    120 F.    112       32 + 86       Methane Fuel    70 F.    26                    *Total Available Effective Energy   = (248,738 + 282,480) = 531,218   31,873,080 Btu/Hr.       Conversion to Heat for Process Gas   Btu/Min. =       or Water/Steam Circuit:       Turbine Power Apparatus Effective    (2545) × (3460 SHP) =    8,805,700 Btu/Hr.       Energy Conversion Rate=               Total Effective Energy        40,678,780 Btu/Hr.       Conversion Rate=       Total System Fuel Energy   (20,693,400 LHV Btu/Hr. for Turbine   33,687,002 LHV Btu/Hr.       Consumption:   Apparatus + 12,993,602 LHV Btu/Hr           for Supplementary Oxy-Fuel Burner           System) =       Overall System Thermal   (40,678,780 Btu/Hr.) ÷ (33,687,002) =   120.75%       Efficiency:          
 
         [0111]     It should be understood that the forgoing description is only illustrative of the invention. Various altered method system and apparatus alternatives, fuels, and modifications to operating conditions can be devised by those skilled in the art without departing from the invention. Accordingly, the present invention is intended to embrace all such alternatives, modifications and variances which fall with the scope of the following appended claims.