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Icone20-Power2012-55076 Proceedings of the 2012 20th International Conference on Nuclear Engineering collocated with the ASME 2012 Power Conference ICONE20-POWER2012 July 30 - August 3, 2012, Anaheim, California, USA ICONE20-POWER2012-55076 DESIGN AND CONTROL OF BYPASS CONDENSERS Michael Phipps, P.E. Ranga Nadig, Ph. D. Maarky Thermal Systems Maarky Thermal Systems Cherry Hill, New Jersey, USA Cherry Hill, New Jersey, USA ABSTRACT INTRODUCTION In waste to energy plants and certain genre of Waste to energy plants generate their revenues cogeneration plants, it is mandatory to condense the from the burning of waste and production of electricity. steam from the boiler or HRSG in a separate bypass Waste is incinerated on a continuous basis and heat from condenser when the steam turbine is out of service. The incineration converts water to steam in a boiler. The high steam from the boiler or HRSG is attemperated in a pressure steam from the boiler flows through a steam pressure reducing desuperheating valve and then turbine generator producing electricity. The low pressure condensed in a bypass condenser. To avoid flashing of steam emerging from the steam turbine is condensed in a condensate in downstream piping it is customary to steam surface condenser. Continuous incineration subcool the condensate in the bypass condenser. mandates that the steam from the boiler must be Circulating water from the steam surface condenser is condensed whether the steam turbine is operational or used to condense the steam in the bypass condenser. not. When the steam turbine is not in service, the steam from the boiler is condensed in a bypass condenser. Some of the challenges involved in the design of the Typically the pressure and temperature of steam from the bypass condenser are: boiler is reduced in a pressure reducing desuperheating valve. This steam, at relatively lower pressure and • High shellside design pressure and temperature temperature, is condensed in a bypass condenser. The • Condensate subcooling entire process is illustrated in a cycle diagram included in • Large circulating water (tubeside) flow rate Figure 1. • Relatively low circulating water (tubeside) inlet temperature • Large Log Mean Temperature Difference (LMTD) • Large shell diameters • Small tube lengths The diverse requirements complicate the mechanical and thermal design of the bypass condenser. This paper highlights the complexities in the design and performance of the bypass condenser. Similarities with the design and operation of steam surface condensers and feedwater heater are reviewed. The uniqueness of the bypass condenser’s design and operation are discussed and appropriate solutions to ensure proper performance are suggested. Figure 1: SERIES CYCLE DIAGRAM 1 Copyright © 2012 by ASME From a design and operation standpoint, the bypass An alternate solution is to place the bypass condenser in condenser resembles a steam surface condenser as well series with the steam surface condenser. This as a feedwater heater. On the shellside, the steam is configuration is shown in Figure 1. The disadvantage is condensed at pressures normally higher than atmospheric the pressure drop through the bypass condenser. pressure. The condensate is subcooled to prevent Circulating water pumping power cost during the lifetime flashing in downstream piping. Higher condensing of the plant must be accounted for. The flow of water pressures and subcooling of condensate are typical through the bypass condensers is guaranteed at all times. features of a two-zone feedwater heater. The circulating The advantage of a series configuration is the elimination water on the tubeside is the same as that used in the of the large valves in the circulating water lines from steam surface condenser. The tubeside design of the steam surface condenser to bypass condenser. To assure bypass condenser is subject to the same restrictions as simplicity and reliability it has become a common practice that for the steam surface condenser. These include lower to place the bypass condenser in series with the steam temperature rises, large flow rates, tube velocities, surface condenser. The lifetime pumping power cost pressure drop, and water chemistry tube material through the bypass condenser is lowered by specifying a compatibility. The shellside design of the bypass lower allowable tubeside pressure drop typically in the condenser is similar to that of a feedwater heater whereas range of 4 psi to 5 psi. In general, the increased capital the tubeside design is similar to that of the steam surface cost of lowering the tubeside pressure drops in the steam condenser. There are also a number of unique surface and bypass condensers is smaller than the differences. The similarities and differences must be lifetime pumping cost of the plant. carefully evaluated while formulating the thermal and mechanical design of the bypass condenser. The major FOULING OR CLEANLINESS FACTORS issues to be considered while designing the bypass condenser are addressed in the following section. Cleanliness factors in the range of 75% to 90% are used in the design of steam surface condensers. Typical fouling SERIES OR PARALLEL ARRANGEMENT factors used in the design of feedwater heaters and heat exchangers are as follows: The bypass condenser and the steam surface condenser use the same circulating water. The bypass condenser • Tubeside = 0.0002 Btu/hr-ft2-°F can be located in series or in parallel to the steam surface • Shellside-Condensing Zone = 0.0000 Btu/hr-ft2-°F condenser. Each configuration has its own advantages • Shellside-Subcooling Zone = 0.0003 Btu/hr-ft2-°F and disadvantages. Locating the bypass condenser in parallel involves installation of large diameter fast acting The condensing zone fouling factor of 0.0002 Btu/hr-ft2-°F automatic valves in circulating water line that can divert (tubeside) and 0.0 Btu/hr-ft2-°F (shellside) correspond to the circulating water from the steam surface condenser to cleanliness factor of approximately 85%. Cleanliness or the bypass condenser in the event of a turbine trip. The fouling factors can be specified for bypass condensers. parallel configuration is illustrated in Figure 2. Circulating Fouling factors are preferred for bypass condensers with water either flows through the steam surface condenser subcooling zone. or the bypass condenser. The pressure drop is limited to one piece of equipment. Care must be exercised not to over specify the cleanliness factor or the fouling factors. In winter months lower circulating water inlet temperatures and clean tubes can lower the shellside condensing pressure. In certain cases, the shellside operating pressure may dip below atmospheric pressure leading to air in-leakage. This will have a detrimental effect on condensation heat transfer. In such instances, condensate may not flow out of the bypass condenser and will start to accumulate in the bypass condenser. With the rise in the condensate level, the tube surface will start to submerge thereby decreasing the heat transfer surface. Lowering the heat transfer surface will result in an increased shellside operating pressure. The condensate level will keep rising until an equilibrium pressure is reached that is high enough to drive the condensate out of the bypass condenser. In certain cases the operating pressure may oscillate Figure 2: PARALLEL CYCLE DIAGRAM between a range which is above or below atmospheric 2 Copyright © 2012 by ASME pressure. Prolonged accumulation of air inside the bypass The bypass condenser uses the same circulating water as condenser combined with elevated temperatures can the steam surface condenser. The restrictions that apply corrode the carbon steel shell internals and compromise to the tubeside design of surface condenser also apply to the life of the equipment. The problem can be avoided by the bypass condenser. Higher circulating water flow rates selecting a relatively high shellside operating pressure require large number of tubes. However, a higher shell and ensuring that in the worst case operating scenario side operating pressure leads to a higher TTD and LMTD (clean tubes, lowest steam flow rate, and lowest and therefore a lower heat transfer surface. Lower heat circulating water inlet temperature) will result in a shellside transfer surface combined with large number of tubes operating above atmospheric pressure. If the shellside results in a small tube length. The problem is severely operating pressure is below atmospheric pressure for compounded in a two pass unit. The low aspect ratio prolonged periods, then an evacuation package (steam jet leads to an entirely new set of design and performance air ejectors or vacuum pumps) must be deployed to issues. remove the non-condensable gases. In any event, it is prudent to place the critical connections, especially the HOTWELL steam inlet, well above the maximum water level to ensure that they are not submerged in any unforeseen Steam surface condensers are equipped with a operating scenario. condensate hotwell. The condensate storage time can vary anywhere between one minute to ten minutes. From SUBCOOLING OF SHELLSIDE CONDENSATE a dimension standpoint the hotwell occupies a small portion of the steam surface condenser. The hotwell The condensate from the bypass condenser can be condensate, at sub-atmospheric pressure, is pumped by directed to a deaerator, storage tank, steam surface condensate pumps into equipment downstream of the condenser hotwell, or an equivalent reservoir. The condenser. In the bypass condenser, the pressure condensate should be subcooled to prevent flashing in the gradient drives the condensate to the deaerator or piping downstream of the bypass condenser. The degree condensate storage tank. Except in certain unique cases, of subcooling depends on the operating pressure of the hotwells are not required for bypass condensers. Hotwells bypass condenser, length of downstream piping, can sometimes exceed the size of the bypass condenser. associated pressure drop, and the pressure in the Hotwell with limited capacity, if required, should be downstream reservoir. Typically subcooling in the range of designed as a separate storage tank as commonly found 50 °F to 60 °F avoids the problems associated with in deaerators.
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