Patent Number: 055263860
Section: description

DESCRIPTION OF THE PREFERRED EMBODIMENTS Nuclear power electrical generation plants have a tremendous potential to produce energy. However, these plants have technical problems that prevent them from reaching their full energy production and from lasting to the end of their design lifetime. These include corrosion due to the high temperatures that they must operate at, and erosion of turbine and secondary system components to name a few. The instant invention enables the lowering of primary T.sub.hot temperature, steam generator temperature, and the increasing of steam quality that greatly reduces erosion of piping and components as well as turbine blades and diaphragms. EXISTING STEAM PERFORMANCE Referring to FIG. 1, the typical nuclear power electric generation system that utilizes a light water reactor will typically operate with wet main steam 1. Wet main steam 1 for this type of system, including both pressurized water reactors and boiling water reactors, is typically supplied by a steam generator 5 to drive the main turbine 10 that is the mechanical force to operate an electrical generator 15. Electrical power 20 generated by these systems is supplied to a grid 25 that purchases the electrical power 20. Wet main steam 1 arriving at the main turbine 10 produces moisture problems such as corrosion and erosion of the turbine blades and diaphragms that limit plant life and are extremely costly in down time, replacement, and operational limitations. Main steam 1 at the entrance 30 to the main turbine 10 will typically be from 0.2% in moisture and be from 970 to 1030 psig (68 bar to 72 bar). The main turbine 10 typically consists of two stages, the high pressure (HP) 35 stage and the low stage (LP) Stage 40. After work is extracted from main steam 1 in the HP stage 35 the characteristics of the HP exhaust steam 45 must be enhanced to improve utilization of steam by the LP stage 40. Currently, nearly all the nuclear power plant turbines, operating on wet main steam 1, whose expansion starts from the saturation curve (quality 1.0), are equipped with moisture separator reheaters (MSR) 50. Without MSRs 50 the HP exhaust steam 45 leaving the HP stage 35 may contain up to 25% of water (quality less 75%) that is too damaging for operation because of the erosion and corrosion. The MSR 50 not only improves the turbine 10 reliability (reduce the erosion of blades, housings, and diaphragms), but also improves efficiency of low pressure (LP) stage 40 of steam turbine 10 as much as 2 to 4%. The construction of the MSR 50 is not critical to the instant invention and is well known in the art. FIG. 2 illustrates the typical construction of a MSR 50. Now referring to FIG. 2, moisture 55 that is typically removed by chevron separating elements 57 from the HP exhaust steam 45 is returned to the feed system through a reheater 60. After the chevron separating elements 57 the HP exhaust steam 45, it is heated by at least one set of tube bundles 58,59. Most MSRs 50 in service today have two sets of tube bundles 58 and 59, and HP exhaust steam 45 enters on the bottom in dual inlet portals 61 and 63, and exits the top of the MSR 50 through dual exit portals 67 and 69. Once the moisture 55 is separated from the HP exhaust steam 45 it is first heated by using extraction steam 65, then it is heated by main steam 1 with a set of tube bundles 59, and is then heated by tube bundle 58 that is supplied with main steam 1. Extraction steam 65 is then directed from the MSR 50 as MSR exhaust steam 70 and is then sent to the LP stage 40 of the main turbine 10, and is slightly superheated, and is typically from 85 to 185 psig (6 to 13 bar). The MSRs 50, one of the most unreliable components in the entire generation system, are extremely expensive, and are usually one-third the cost of the main turbine 10 itself. Also shown in FIG. 1 are other components that are typically found in light water nuclear reactor power generation systems. For example, turbine exhaust will proceed through the plenum 75 that connects the main turbine 10 and the condenser 80, to feed pump 85, to demineralizer 90, and then finally to pumping stages, 95 and 100, before being returned to the steam generator 5. Nuclear-electric generating systems of this type typically have an efficiency of about 33 to 35% with a heat rate of about 10,000 Btu/Kwh. Existing combined-cycle-electric plants currently utilize a heat recovery boiler 110 (HRB) to increase the efficiency. FIG. 3 illustrates how an HRB 110 would be utilized in a typical combined-cycle-electric plant. ENHANCEMENT OF OPERATIONAL PERFORMANCE FIG. 4 illustrates the overall plant schematic for a nuclear plant with the instant invention installed in the downstream portion of main steam 1 piping 1513 of the steam generator 5. It will become apparent how the instant invention improves the operational characteristics of HP inlet mixed steam 130 entering the entrance 30 to the HP Stage 35 and the LP stage 40 of the main turbine 10. It should be noted in both FIGS. 1 and 4, main steam 1 denotes the main steam piping 1513 and the flow of main steam 1 within that piping. Main steam 1 from the steam generator 5 arrives at a high-pressure-mixer superheater (HPMS) 105 where it is superheated to the temperature from 570.degree. to 680.degree. F. (299.degree.-360.degree. C.) by the high enthalpy-high pressure steam HRB outlet steam 107 from a heat recovery boiler (HRB) 110. USE OF HRB IN CONVENTIONAL APPLICATIONS Use of a HRB 110 in a conventional combined-cycle plant, is illustrated in FIG. 3 and is well known in the art. The cycle starts with water 115 that is returned to HRB 110 from the condenser 80 by the discharge of the feed pump 85 where it is heated by the exhaust 120 from a gas turbine 125. The fuel utilized by the gas turbine is not germane to the invention. The exhaust gas 120 from the gas turbine 125 arrives to heat recovery boiler (HRB) 110, where two pressures of steam are generated and then superheated. High pressure and high enthalpy, HRB high pressure steam 107 is generated in high pressure loop 109; the HRB low pressure steam 145 is generated in low pressure loop 108. The construction of HRB 110 is not critical to the present invention and is well known in the art. The gas turbine consists typically of several components: gas turbines 160, compressors 165, and burners 170. Operation of gas turbines is well known in the art. The gas turbine 125 is used to drive a generator 155 that supplies electricity 157 to the grid 25. This increases the overall plant efficiency to about 42 to 45% when the heat range is from 8200 to 7600 Btu/Kwh. USE OF HRB IN THE INSTANT INVENTION Use of a conventional HRB 110 as described above is contemplated by the instant invention. However, the steam generated in the HRB will be used in a different manner. The HRB high pressure steam 107 exits with high pressure (typically from 1000 to 1315 psig (93 bar)) and high temperature (typically from 830.degree. to 935.degree. F. (444.degree.-500.degree. C.)), and is sent to the high pressure mixer superheater (HPMS) 105 to mix and to superheat main steam 1. The HRB low pressure steam 145 exits with a pressure (typically from 80 to 200 psig (14 bar)) and high temperature (typically from 830.degree. to 935.degree. F. (450.degree.-500.degree. C.)), and is sent to the low pressure mixer superheater (LPMS) 140 to mix and superheat MSR discharge steam 137. Referring to FIGS. 18a and 18b, when it is desirable not to use a LPMS 140 the HRB high pressure steam 107 pressure should be boosted to approximately 2000 psig (140 bar), and the temperature should be from 830.degree. to 1050.degree. F. (444.degree.-565.degree. C.). USE OF MSR IN CONJUNCTION WITH INSTANT INVENTION Now referring to FIG. 6, the MSR 50 that is already installed in the plant can be used. The construction of the MSR 50 is not critical to the instant invention and is well known in the art. Moisture 55 that is removed from the HP exhaust steam 45 is returned to the feed system through a reheater 60. Once the moisture 55 is separated from the HP exhaust steam 45 it is reheated by using HPMS outlet steam 135 from the HPMS 105, becoming MSR discharge steam 137. The MSR discharge steam 137 is then sent to the LPMS 140 where it is superheated by the high enthalpy HRB low pressure steam 145 from the HRB 110 yielding high enthalpy low pressure steam, referred to as LPMS. This discharge steam 150 is then sent directly to the LP stage 40 of the main turbine 10. This treatment of HP exhaust steam 45 before entering the low pressure stage 40 of the steam turbine 10 results in high quality steam in flow passes, reducing erosion of rotor blades and diaphragms and increasing in efficiency by 3 to 5 percent. GAS TURBINE AS A GENERATOR Now referring again to FIG. 4, the gas turbine 125 is well known in the art as a reliable source of electrical energy. This enables the same turbine 125 that is used to supply heated exhaust 120 to act as the source of electrical power 157 for use in emergency situations. This emergency electrical power 157 would be in addition to, or to supplement, the diesel generators that are typically installed in nuclear power stations. The gas turbine generator heat is the heat available in the gas turbine exhaust 120. The amount of heat is only critical to the invention as long as it provides sufficient energy to make sure the heat recovery boiler high pressure steam 107 has sufficient enthalpy to increase the operation characteristics of the steam at the turbine inlet 30 and to supply the needed energy to the LPMS 140. Any energy available above this amount can be sent up the stack 143 as shown in FIG. 5. Therefore, the gas turbine generator can be used as an independent source of electrical power 157 to the grid 25. This enables the dual use of a gas turbine electrical generator set 155. One use is to supply energy for the instant invention, and another use is as an independent electrical energy source to supply electricity to the grid 25. GRAPHICAL REPRESENTATION OF TYPICAL PLANT PERFORMANCE The Mollier chart for the typical steam cycle of a typical light water reactor electric power generation system is illustrated in FIG. 9a. The diagram in FIG. 9a corresponds to equipment that is illustrated in FIG. 1. Expansion in the HP stage of the Main Turbine (a.sub.1 -a.sub.2) PA0 Removal of Moisture from HP exiting wet steam in the MSR (a.sub.2 -a.sub.4) PA0 Removal of Moisture from HP exiting wet steam in the MSR (a.sub.4 -a.sub.6) PA0 Extraction of Work by LP stage of the Main Turbine (a.sub.6 -a.sub.7) PA0 Enhancement of Main Steam (b.sub.1 -b.sub.3) PA0 Expansion in the HP stage of the Main Turbine (b.sub.3 -b.sub.4) PA0 Removal of Moisture from HP exiting wet steam in the MSR (b.sub.4 -b.sub.5) PA0 Removal of Moisture from HP exiting wet steam in the MSR (b.sub.5 -b.sub.6) PA0 Mixing and Reheating of MSR exiting wet steam in the LPMS (b.sub.6 -b.sub.8) PA0 Extraction of Work by LP stage of the Main Turbine (b.sub.8 -b.sub.9) PA0 Elimination of the MSR PA0 LP Stage utilizes Superheated Steam (b.sub.8 to b.sub.8') Main steam 1 expands in the HP stage 35 of the main turbine 10 until it exits as HP exhaust steam 45. This line on FIG. 9a represents a decrease in quality from about 1 to about 0.85, and is illustrated as going from point a.sub.1 to point a.sub.2. In the MSR 50 the moisture 55 from HP exhaust steam 45 is first removed by chevron separating elements 57 that increase the quality to about 0.98 that is graphically represented in FIG. 9a by the line from point a.sub.2 to a.sub.5. After the moisture 55 is separated, the exhaust steam 45 is heated in two stages. The first is by extraction steam 65 and then by main steam 1. This removes all remaining moisture or superheats the HP exhaust steam 45 to point a.sub.5 or a.sub.6 depending upon the operational characteristics in that plant at that time. At this point the HP exhaust steam 45 is typically at a temperature of about 570.degree. F. (299.degree. C.), and the MSR 50 exhaust steam 70 is typically at a temperature of about 500.degree. F. (260.degree. C.). Upon exiting the MSR 50, the MSR exhaust steam 70 feeds into the LP stage 40 of the main turbine 10 graphically shown as a.sub.6 on FIG. 9a. Work is extracted in the LP stage 40 that is graphically shown as going from a.sub.6 to a.sub.7, which is then directed to the condenser 80. The line representing the condenser 80 is also indicated on FIG. 9a. GRAPHICAL REPRESENTATION OF PLANT PERFORMANCE IMPROVED BY THE INSTANT INVENTION The Mollier chart for the typical steam cycle of a light water reactor electrical generation station with instant invention installed is illustrated in FIG. 9b. The diagram in FIG. 9b corresponds to equipment that is illustrated in FIG. 4. Referring now to FIG. 9b, main steam 1 enters the inlet to the HPMS 105 at point b.sub.1 as wet main steam 1 where it is superheated to point b.sub.3, and exits as superheated HP inlet mixed steam 130. The HP inlet mixed steam 130 then enters the HP stage 35 of the main turbine 10 where it expands and work is extracted until it exits as HP exhaust steam 45. As illustrated on FIG. 9b, this represents a decrease in quality from superheated condition to about 0.94. On FIG. 9b this is illustrated as going from point b.sub.3 to point b.sub.4, and corresponds to going from a.sub.1 to a.sub.2 in a conventional plant as illustrated in FIG. 9a. In the MSR 50 the moisture 55 from HP exhaust steam 45 is removed by chevron separating elements 57 that increase the quality to about 1.0 that is graphically represented in FIG. 9 by the line from point b.sub.4 to b.sub.5. After the moisture 55 is separated from the HP exhaust steam 45, it is heated in two stages by high pressure mixer separator (HPMS) outlet steam 135. This removes all remaining moisture and superheats the HP exhaust steam 45 to point b.sub.6. The HP exhaust steam 45 is typically at a quality of 0.94 at this point. At point b.sub.5 the temperature is about 390.degree. F. (200.degree. C.). If the embodiment without an LPMS 140 is used, the HP exhaust steam 45 is typically at a temperature of about 550.degree. to 600.degree. F. (288.degree.-316.degree. C.) at this point. At point b.sub.6 a temperature is about 550.degree.-600.degree. F. (288.degree.-316.degree. C.). After exiting the MSR 50 the MSR discharge steam 137 is mixed and reheated in the low pressure mixer superheater (LPMS) 140 by HRB low pressure steam 145 where it is fed into the LP stage 40 of the main turbine 10. Work is being extracted in the LP stage 40 and is represented by line b.sub.8 to b.sub.9 on FIG. 9b. The line representing the condenser 80 is indicated on FIGS. 9a and 9b. An additional advantage of the invention is elimination of the MSR 50. When the conditioning of the steam in going from b.sub.6 to b.sub.8 is greater than the conditioning that occurs in going from b.sub.4 to b.sub.6, the MSR 50 is no longer necessary. Still another advantage of the invention is that the LPMS discharge steam 150 that is utilized by the LP stage 40 of the main turbine 10 is superheated for a longer portion of travel through the LP stage 40, than that of the MSR exhaust steam 70. This reduces the erosion of the LP stage 40 blades (not shown). Referring to FIG. 9a and FIG. 9b the distance from b.sub.8 to b.sub.8, is much larger than the distance from a.sub.6 to a.sub.6', each distance being a diagrammatic representation of the path in which work is extracted from the superheated steam within the LP stage 40 of the main turbine 10. REDUCTION OF CORROSION TO STEAM GENERATOR The corrosion of secondary components in any nuclear power plant is temperature dependent. This dependence is illustrated in FIG. 7. The most detrimental aspect of corrosion in a nuclear power plant steam generator 5 is tube failure due to corrosion. As illustrated in FIG. 7, with temperatures below 600.degree. F. (315.degree. C.), plugging versus years of operation only slightly increases. However, above 600.degree. F. (315.degree. C.) plugging increases dramatically. Pressurized Water Reactors Referring now to FIG. 8a, the instant invention enables a reduction in T.sub.hot 701, which is due to the lowering of the temperature differential, T.sub.hot -T.sub.cold (701-702). For a given thermal output of the reactor 700, assuming that (1) the mass flow rate 705 in the primary cycle is held constant, and (2) that T.sub.cold 702 constant is held constant, as illustrated by the following equation: EQU Power.sub.reactor =C.sub.P *mass.sub.flow rate *(T.sub.hot -T.sub.cold), where C.sub.P is the specific heat of the primary system coolant. Boiling Water Reactors Referring now to FIG. 8b, the instant invention enables a reduction in T.sub.hot 801, which is due to the lowering of the temperature differential, T.sub.hot -T.sub.cold, (801-802) for a given thermal output of the reactor, assuming that (1) the mass flow rate in the primary system is held constant, and (2) that T.sub.cold is held constant, as illustrated by the previous equation, except where C.sub.P is the specific heat of the system coolant. The reactor 800 is a boiling water reactor, and T.sub.hot is considered to be the average temperature at the outlet of the reactor 800 and the inlet to the steam generator 5 which in a boiling water reactor is one unit. The thermal efficiency is higher; consequently for a lower value of T.sub.hot the same power level of the rated unit may be maintained. The reactor thermal power level can be reduced, the fuel cycle length can be extended, as well as a reduction in reactor vessel embrittlement. FUEL CYCLE AND ENRICHMENT EFFECTS Still another advantage of the instant invention is to decrease the enrichment requirements of the reduced thermal power of nuclear reactors. The conversion from thermal energy to electrical energy is typically from 33-35% for plants without the instant invention and about 42-45% for plants with the invention. Since the nuclear reactor thermal energy output is directly keyed to how much nuclear fuel is present in the reactor and at what fission rate it is operated at, less fissions will be required. Any given fuel assembly has so many fissions possible over the life of the plant therefore the life of the plant is extended. The reduction in the requirement of thermal power allows for the reduction of fuel enrichment. Efficiency Without the Instant Invention Net efficiency for a nuclear plant without the invention can be expressed by the following equation: ##EQU1## where MW.sub.E-gen is the total electrical output of the plant, and MW.sub.Rx is the total heat output of the reactor. Efficiency With the Instant Invention In a nuclear plant utilizing the instant invention, the net efficiency can be expressed by the following equation: ##EQU2## where MW.sub.E-tur is the output that the electrical generator of gas turbine generator 155 unit supplies to the grid 25, and MW.sub.tur-fuel is the energy release by the fuel in the burner 170 of the gas turbine 125. The increase in .nu..sub.net is due to both the powers added by the gas turbine generator and the lowering of the MW.sub.Rx for a given MW.sub.E-gen. Since the nuclear reactor thermal output is directly keyed to how much nuclear fuel is present in the reactor and at what fission rate it is operated at, less fissions will be required. Any given fuel assembly has so many fissions possible over the life of the plant; therefore, the life of the plant is extended while maintaining the same amount of electrical power 157 supplied to the grid 25. Simulated computer runs on cost and efficiency have indicated that a 41.5% efficiency is possible when the instant invention is used on a 1260 MW.sub.e PWR plant with 3570 MW.sub.th, which normally has an efficiency of 34%. In this computer simulation, T.sub.hot went from 615.degree. F. (323.degree. C.) to a T.sub.hot of 597.degree. F. (314.degree. C.). OPERATIONAL REQUIREMENTS There are many types of nuclear electrical generation plants now in operation. Each plant will have its individual operational requirements that can influence how the instant invention is applied to that particular system. The main factors that would influence the selection of the most applicable embodiment include but are not limited to: (1) steam pressure requirements; (2) steam temperature requirements; (3) steam quality requirements; (4) type of heat recover boiler (HRB) being used (i.e., does it have a plurality of steam discharge pressures); (5) maintenance condition of the equipment, for example does the moisture separator reheater (MSR) need replacing; and (6) cost and availability of the equipment needed to install that particular embodiment. Referring now to FIG. 13, an embodiment is illustrated that utilizes a heat recovery boiler that has only one steam pressure 107. This embodiment would use a second high pressure line 111 of the heat recovery boiler high pressure steam line 107. The second high pressure steam line 111 will require a pressure reduction device 112. In this embodiment the high pressure stage exhaust steam 45 is mixed with a second heat recovery boiler high pressure steam to form the low pressure mixer superheater (LPMS) discharge steam 150. Referring now to FIG. 14, an embodiment is illustrated that utilizes a heat recovery boiler that has two steam pressures; i.e., the HRB high pressure steam 107 and the HRB low pressure steam 145. This embodiment would mix the HP exhaust steam 45 directly with HRB low pressure steam 145 to form the low pressure mixer superheater discharge steam. SELECTION OF STEAM MIXING EQUIPMENT Some of the individual components utilized in the instant invention contains the same type of equipment and materials found in many existing combined cycle plants, as well as some found in existing nuclear power plants. The physical construction of these components is not material to the instant invention. There are many options for the selection of the mixer superheaters that are utilized in the instant invention in addition to the MSR's 50 discussed above. Specifically, the high pressure mixer superheater 105 and the low pressure mixer superheater 140. FIG. 10 illustrates a bellows 1010 connection for a tube 1020 injection of 107 through a nozzle 1030 into main steam 1 to form HP inlet mixed steam 130. The bellows arrangement 1010, or some other mechanism to allow for expansion and contraction, is necessary for all steam systems. Bellows arrangements 1010 typically have an upper hatch 1040 to allow for servicing. Typically an expanded portion of piping 1050 is installed to facilitate the insertion of the tube 1020 FIG. 11 illustrates a honeycomb mixer placed in an expanded portion of pipe down stream of where 107 enters the main steam 1 flow. This type of mixer-superheater typically resembles a piping tee, with pipe 1110 being the vertical leg and the expanded section 1120, between the inlet 1130 and the outlet 1140 forming the horizontal leg. FIG. 12 illustrates a vortex-vane mixer in which 107 a main steam 1 is fed into a series of vanes 1210 that induces a clockwise pattern, with the pipe and vane arrangement of FIG. 12, that causes 107 and 1 to mix. The resulting mixture, HP inlet mixed steam 130, is typically removed by pipe in the plane perpendicular to the plane of HRB high pressure steam 107 and main steam 1. These same type of mixers can be utilized in the mixer assembly 1507 that is used in the micro-jet mixer as the HPMS 105 that is discussed below. MICRO-JET MIXER Now referring to FIGS. 15a and 15b, the HPMS 105 is a micro-jet mixer that is particularly suited to achieving thorough mixing with a minimal pressure drop. In the first stage of the mixing process the micro-jet mixer mixes main steam 1 with HRB outlet steam 107 to form a combined steam flow 1501. The micro-jet mixer is a cylindrical tube and shell arrangement in which steam flows 1,107 are directed together in a mixing area 1503 wherein a combined steam flow 1501 is formed. In the second stage the combined steam flow 1501 flows through baffle slots 1529 into a timing chamber 1505 which allows further mixing, thereby forming mixed steam flow 1533. The final stage of mixing is done by directing the mixed steam flow 1533 through a mixer assembly 1507 mounted on or in an exit guide 1509, and then finally exiting the exit chamber 1511, where it becomes HP inlet mixed steam 130, which is finally directed via main steam piping 1513 to the steam turbine 10. The micro-jet mixer and its major components ares preferable cylindrical in shape. However, other shapes are within the contemplation of the practice of the invention. Particularly those that are substantially circular or have a regular geometric shape. Micro-Jet Mixer Detailed Flow Path Main steam 1 enters the mixer shell 1515 at the inlet chamber 1516 via the main steam inlet 1517 and then flows around the slotted baffle 1527 into the mixing area 1503. The HRB outlet steam 107 enters first through the outer annulus 1519 via a HRB steam inlet 1521 and then through micro-jets 1523 into the mixing area 1503. The typical arrangement of HRB steam inlets 1521 is to have a plurality of inlets distributed axially around the circumference of the mixer shell 1515. FIG. 15a illustrates two HRB steam inlets 1521 diametrically disposed one to the other. The combined flow 1501 proceeds in the space between the perforated baffle 1525 and the slotted baffle 1527 to the baffle slots 1529, which is referred to as the mixing area 1503. After the combined flow 1501 passes through the micro-jets 1523, it passes into the timing chamber 1505 which is defined as the space between the perforated baffle 1525 and the slotted baffle 1527. The slotted baffle 1527 has both an attaching end 1528 and an interior end 1530. The interior end 1530 is typically plugged to force the mixed flow 1533 into the mixer assembly 1507. The attaching end 1528 is typically attached to the main steam outlet 1537. The baffle slots 1529 are typically cut in the attaching end 1528 of the slotted baffle 1527. The direction of the combined flow 1501 in the timing chamber 1505 is substantially counter to the direction of the mixed flow 1533 in mixing area 1503. Once the combined flow 1501 has gone through the baffle slots 1529 it is then termed to be mixed flow 1533. Located within the slotted baffle 1527 is a substantially cylindrical exit guide 1509 of smaller overall diameter than the slotted baffle 1527. The mixed flow 1533 is then directed to a mixer assembly 1507 which is located at or in the interior end 1535 of the exit guide 1509. The mixer assembly 1507 can be simply the end of the exit guide 1509 or alternatively be vanes mounted inside the exit guide 1509. However, the mixer assembly will typically be of the type illustrated in FIGS. 10, 11, or 12. The mixed flow 1533 is then directed to a mixer assembly 1507 which can be either mounted on or in the interior end 1535 of the exit guide 1509. After passing through the mixer assembly 1507 the mixed steam 1533 is referred to as HP inlet mixed steam 130. The HP inlet mixed steam 130 then exits the exit chamber 1511 into main steam piping 1513 at the main steam outlet 1537 where it is directed to the steam turbine 10. It is within the contemplation of the instant invention that a plurality of exit chambers 1511 can be utilized. Specifically, now referring to FIG. 18a, outlet steam 135 is extracted from the micro-jet mixer and is used for conditioning within the MSR 50. The embodiments illustrated in FIGS. 15a and 15b are with a single perforated baffle 1525 and a single slotted baffle 1527, however, multiple baffles 1525, or multiple baffles 1527, or any combination can be used as needed to increase the degree of mixing. Thermal Differentials Due to the temperature differentials expected, the perforated baffle 1525 should be mounted to the main steam inlet 1517 by means of a thermal expansion joint 1539. Thermal expansion joints are well known in the art, and will allow for expansion and contraction without damage of the components of the micro-jet mixer. Slotted Baffle Construction Now referring to FIG. 16 the slotted baffle 1527 will typically be a substantially cylindrical pipe into which is cut a plurality of baffle slots 1529. For use in a nuclear power steam plant the baffle slots 1529 should be approximately 5 cm wide and 20 cm long, and substantially uniformly distributed transversely around the exit end 1543 of the slotted baffle 1527. The baffle slots 1529 can also be ellipsoid in shape with the major axis being 12 cm and the minor axis being 6 cm in length. The density of the baffle slots 1529 is determined by the design limitations on pressure drop. The more baffle slots 1529 would cause a reduction in pressure differential across the slotted baffle 1527. Perforated Baffle Construction Referring now to FIGS. 17a and 17b the perforated baffle 1525 is a substantially cylindrical into which is cut a plurality of micro-jets 1523. The micro-jets 1523 should be from 10 to 20 mm in diameter and substantially uniformly distributed over the entire surface of the perforated baffle. Or alternatively, the micro-jets 1523 can only be placed adjacent to the mixing area 1503. The density of the micro-jets 1523 is determined by the design limitations on pressure drop. The more micro-jets 1523 would cause a reduction in pressure differential across the perforated baffle 1525. The micro-jets 1523 are orifices cut through the perforated baffle 1525 from the outer surface 1545 to the inner surface 1547. Additional control of the HRB outlet steam 107 velocity and pressure can be obtained by shaping the orifices as nozzles 1549. The nozzle configuration would be used in application where a lower pressure drop is required. Nozzles would typically have a larger inlet 1551 surface area than a outlet 1553 surface area. Other configurations for the orifices is also possible. Examples of other possible orifice shapes include, rounded edges 1555, orifice walls 1557 can be concave, orifice wails 1557 can be convex, or where the orifice area on the outer surface 1545 is smaller than the orifice area on the inner surface 1547. A possible added advantage of using particularly shaped orifices is that steam erosion of the surface would be less in more rounded walls 1557 and edges 1555. Expected Equipment Sizes Referring now to FIG. 15c, based upon a typical nuclear plant main steam line size of 0.8 meters the micro-jet mixer described above is expected to be from 2.5 to 3 meters in length (l.sub.m, 1571) and about 1.6 meters in diameter (d.sub.m, 1573). This size estimate is also based upon the use of four HRB high pressure steam 107 steam lines feeding the mixer 105. A mixer 105 of this size will have a perforated baffle 1525 of about 1.3 meters and a slotted baffle 1527 of about 1.1 meters in diameter. This implies a distance (d.sub.sb-pb, 1575) between the slotted baffle 1527 and the perforated baffle 1525 of about 100 mm before any allowance is made for the thickness of the materials of construction. The exit guide 1509, is expected to be about 0.8 meters in diameter (d.sub.eg, 1585), causing a distance (d.sub.eg-ab, 1577) between the exit guide and the slotted baffle of about 150 mm. ELIMINATION OF THE LPMS Referring now to FIG. 18a, still another embodiment of the instant invention is the elimination of the requirement of a LPMS 140. In this embodiment the MSR discharge steam 137 is directed immediately into the LP stage 40. This is possible because the HPMS outlet steam 135 has high enough enthalpy before entering the MSR 50 such that the MSR discharge steam 137 entering the LP stage 40 is of sufficient quality and enthalpy to achieve the corrosion and erosion benefits discussed above, while having sufficient enthalpy to prevent the desired work in the LP Stage 40. This increase in enthalpy is accomplished by means of a booster turbine 1801 in conjunction with the HRB 110 to treat, i.e. increase the enthalpy, of the HPMS outlet steam 135 prior to entering the HPMS 105. This is done by increasing the enthalpy of the HRB outlet steam 107. The enthalpy of the HRB outlet steam 107, which is at a high pressure, is increased by directing the HRB low pressure steam 145 to the booster inlet 1803 of the booster turbine 1801. The booster discharge steam (BDS) 1805 of the booster turbine 1801 is then directed to the HPMS 105 via the HRB 110. The pressure of the BDS 1805 is typically only higher than that of main steam 1 to facilitate mixing as discussed above. After leaving the HPMS 105 the 135 is directed to the MSR 50 thence directly to the LP stage 40. The decrease in enthalpy of HRB low pressure steam 145 while in the booster turbine 1801 represents useful work and is used to produce electricity via generator 155. The shaft 1809 of the booster turbine will typically be mechanically connected to shaft of the gas turbine 125, but two shaft operation is also contemplated. It should be noted that BDS 1805 is typically directly fed into the HPMS 105 within the HRB 110 where it is heated in a HRB tube assembly (not shown). When the instant invention is operated in this mode it is the equivalent of using the booster turbine 1801 as a "high pressure stage", the HP stage 35 as a "medium stage", with the role of the LP stage 40 being unchanged. It is within the contemplation of the practice of the instant invention that a multiplicity of booster turbines can be used to achieve higher enthalpy entering the micro-jet mixer used as an HPMS 105 or LP stage 40 as desired. HPMS OR MIXER-JET VIBRATIONAL CONSIDERATIONS It is well known in the art that large mass flow rates of steam mixing at different temperatures and pressures can cause equipment vibration. In most embodiments of the instant invention vibrational characteristics of the system will have to be considered. When an HPMS 105 is used, the sizing of the components of the HPMS 105 can reduce the vibrations that can be experienced. Referring again to FIG. 15c, a mixing length l.sub.m 1571 to micro-jet mixer diameter d.sub.m 1573 ratio of approximately 15 to 1 will have advantageous vibrational characteristics. Similarly, the slotted baffle length l.sub.ab 1579 to slotted baffle diameter d.sub.ab 1581 can be adjusted to cause minimal vibration. Also, the exit guide length l.sub.eg 1583 to exit guide diameter d.sub.eg 1585 can be adjusted to achieve minimal vibration. Any time the length/diameter ratio is adjusted, due consideration should be given to the resulting volume. Volume not only influences the pressure drop and change, due to friction or bernouli's effect respectively, but it is also important in allowing the desired mixing to take place. For example, the volume V.sub.oa of the outer annulus 1509 which is determined by the micro-jet mixer diameter d.sub.m 1573, the micro-jet mixer length l.sub.m 1571, and diameter of the perforated baffle d.sub.pb 1587, and for a circular micro-jet mixer can be expressed as EQU V.sub.oa =I.sub.m *.pi.*1/4* (d.sub.m.sup.2 -d.sub.pb.sup.2), is an important consideration. As is the volume of the timing chamber 1505, exit chamber 1511, guide chamber 1512, and the inlet chamber 1516. Each of these volumes can be expressed using same method of calculation and is well know in the art. USE OF THE LPMS WITH THE BOOSTER TURBINE To provide maximum plant flexibility it may be desirable to be able to have both a LPMS 140 and a booster turbine 1801 installed. Referring now to FIG. 18b the LPMS 140 and the booster turbine 1801 can be used in conjunction with one another, or used alone, depending upon operational needs. In this embodiment the HRB high pressure steam 107 is directed to the booster turbine 1803 inlet where work is extracted as previously discussed. In this embodiment steam will be extracted from the booster turbine 1801 in two ways. After work has been extracted the DBS 1805 will also be directed to the HRB 110. However, at mid-turbine 1813, extraction booster steam (EBS) 1815 will be extracted and directed to the HPMS 105. The HRB low pressure steam 145 is directed to the LPMS 140 in order to increase the enthalpy of the LPMS discharge steam 150 to the desired level. The EBS 1815 extracted from 1803 will be at a slightly higher pressure than main steam 1 and is directed to HPMS 105. From this point the flow is substantially the same as discussed above. PIPING, EQUIPMENT, AND VALVE PERMUTATIONS It is obvious to one skilled in the art that various combinations of the piping and equipment disclosed can be used. For example, all components and piping necessary for any embodiment can be installed. The use of valves will enable any specific embodiment to be achieved as desired. OTHER EMBODIMENTS POSSIBLE While several preferred embodiments of the present invention have been shown and described, it will be apparent to those skilled in the art that many changes and modifications may be made without departing from the invention in its broader aspects. The appended claims are therefore intended to cover all such changes and modifications as fall within the true spirit and scope of the invention.