Epri Acc Design

Air-Cooled Condenser Design, Specification, and Operation GuidelinesTechnical Report Air-Cooled Condenser Design, Specification, and Operation Guidelines 1007688 Final Report, December 2005 EPRI Project Manager K. Zammit ELECTRIC POWER RESEARCH INSTITUTE 3420 Hillview Avenue, Palo Alto, California 94304-1395 • PO Box 10412, Palo Alto, California 94303-0813 • USA 800.313.3774 • 650.855.2121 • [email protected] • www.epri.com (EPRI).DISCLAIMER OF WARRANTIES AND LIMITATION OF LIABILITIES THIS DOCUMENT WAS PREPARED BY THE ORGANIZATION(S) NAMED BELOW AS AN ACCOUNT OF WORK SPONSORED OR COSPONSORED BY THE ELECTRIC POWER RESEARCH INSTITUTE. Copyright © 2005 Electric Power Research Institute. INC. OR SIMILAR ITEM DISCLOSED IN THIS DOCUMENT. ANY COSPONSOR. CA 94520. OR (III) THAT THIS DOCUMENT IS SUITABLE TO ANY PARTICULAR USER'S CIRCUMSTANCE. APPARATUS. All rights reserved. 1355 Willow Way. EVEN IF EPRI OR ANY EPRI REPRESENTATIVE HAS BEEN ADVISED OF THE POSSIBILITY OF SUCH DAMAGES) RESULTING FROM YOUR SELECTION OR USE OF THIS DOCUMENT OR ANY INFORMATION. (925) 609-1310 (fax). INCLUDING MERCHANTABILITY AND FITNESS FOR A PARTICULAR PURPOSE. PROCESS. METHOD. OR (B) ASSUMES RESPONSIBILITY FOR ANY DAMAGES OR OTHER LIABILITY WHATSOEVER (INCLUDING ANY CONSEQUENTIAL DAMAGES. APPARATUS. (925) 609-9169. ORGANIZATION(S) THAT PREPARED THIS DOCUMENT Karl Wilber Maulbetsch Consulting ORDERING INFORMATION Requests for copies of this report should be directed to EPRI Orders and Conferences. Inc. (800) 313-3774. NEITHER EPRI. EXPRESS OR IMPLIED. Suite 278. OR SIMILAR ITEM DISCLOSED IN THIS DOCUMENT. OR (II) THAT SUCH USE DOES NOT INFRINGE ON OR INTERFERE WITH PRIVATELY OWNED RIGHTS. . THE ORGANIZATION(S) BELOW. Electric Power Research Institute and EPRI are registered service marks of the Electric Power Research Institute. ANY MEMBER OF EPRI. METHOD. PROCESS. (I) WITH RESPECT TO THE USE OF ANY INFORMATION. INCLUDING ANY PARTY'S INTELLECTUAL PROPERTY. Inc. NOR ANY PERSON ACTING ON BEHALF OF ANY OF THEM: (A) MAKES ANY WARRANTY OR REPRESENTATION WHATSOEVER. Concord. press 2 or internally x5379. California 95403 Principal Investigator K. and Operation Guidelines. Specification. #211 Menlo Park. CA: 2005. Palo Alto. EPRI.CITATIONS This report was prepared by Karl Wilber Consultant 2017 Turnberry Court Santa Rosa. The report is a corporate document that should be cited in the literature in the following manner: Air-Cooled Condenser Design. iii . 1007688. Wilber Maulbetsch Consulting 770 Menlo Avenue. California 94025 Principal Investigator J. Maulbetsch This report describes research sponsored by the Electric Power Research Institute (EPRI). . it offers perspectives on economic and operational issues that factor into selecting ACC design points. Results & Findings This report provides information to guide the development and specification of ACC design conditions. It incorporates operating experience from recently commissioned plants to provide insight into issues that confront staff in operating and maintaining ACCs and balancing ACC performance relative to plant performance and output. the report provides a test procedure to determine ACC thermal acceptance. Finally. and commission ACCs that have optimum design and performance characteristics for the application at hand. and owner/operators. they will need information to assist them in answering the following questions: What are the primary ACC operating and performance problems? What information should be provided to bidders in a specification and request for proposal? How should developers evaluate and compare bids for ACC supply? What are the most important considerations in conducting performance and acceptance testing? What are some key ACC commissioning and startup issues? v . available from ACC suppliers. In order to accomplish this. specification. It also speaks to the dynamics of a typical bid process. design. While the report cautions the power plant owner/purchaser relative to performance impacts of wind on the ACC. in addition to an examination of startup and commissioning issues. and operation guidelines. especially in the United States. While operating experience and performance data are. greater industry focus on water conservation – combined with continued concern over the environmental effects of once-through and evaporative cooling – will almost certainly increase interest in ACC applications. Challenges & Objective(s) The objective of this specification is to provide engineering and purchasing personnel with information they need to specify. there is no one repository of such information. use of the air-cooled condenser (ACC) for heat rejection in steam electric power plants has historically been very limited. This report provides a single resource for ACC application. consultants. to some extent. In doing so.PRODUCT DESCRIPTION In contrast to once-through and evaporative cooling systems. procure. it recognizes that wind effects are site specific and that more information regarding both impacts and remedial action is required before improved guidance can be provided. with the objective of forging more of a partnership between the supplier and the purchaser. However. California. These included wind effects on ACC performance. operation.S. Several such programs – funded by EPRI.S. which include more detailed assessments of wind effects on ACCs and performance enhancement strategies via inlet air cooling.Applications. and jointly sponsored by EPRI and the CEC. in most cases. and design. Department of Energy/National Energy Technology Laboratory (U. the California Energy Commission (CEC). will complement and supplement this specification. such specifications do not ensure the optimum economic selection of an ACC for the plant. held June 1-2. and inlet air cooling/conditioning systems. and the U. As a result of site visits and interviews with both plant personnel and suppliers. Further. specification. in Sacramento. these specifications have not addressed areas that might be problematic in terms of ACC performance. and maintenance. Key drivers for increased application of ACCs include the Scarcity of water and the attendant elimination of evaporative water loss realized by the use of ACCs from both once-through and evaporative cooling systems Reduction or elimination of thermal pollution and entrainment and impingement issues typically associated with once-through and evaporative cooling Elimination of the visible plume and drift from the operating cooling system EPRI Perspective As a result of the increased interest in water conservation and ACCs in particular. Keywords Cooling System Air-Cooled Condenser Steam Electric Power Plant Thermal Acceptance Test Water Conservation ACC Specification ACC Performance and Acceptance Testing vi . its environment. 2005. Accordingly. reliable ACC performance over a range of operating conditions. and the economic situations in which the plant must compete. as ongoing projects will shed light on key areas that will ultimately improve the specification and operational understanding of ACCs. both internationally and in the United States. DOE/NETL) – are summarized in the proceedings of the Advanced Cooling Strategies/Technologies Conference. Approach Numerous specifications have been developed for ACCs. Values & Use This specification provides much-needed industry insights while alerting the purchaser to issues that impact ACC application. a number of programs are have been commissioned to further examine operational and performance issues. aspects of this specification may be considered a work in progress. fouling and cleaning of ACC finned tubes. EPRI anticipates that the results of such studies. In many cases. a number of areas surfaced that deserved additional attention beyond the historical level that they have received. As a result of limited ACC operating experience and the nature of proprietary and evolving drycooling technologies. with emphasis on language that might be incorporated into such specifications An example procedure for evaluation and comparison of bids Guidelines for ACC performance and acceptance testing Issues associated with ACC startup and commissioning This report’s summary of a proposed ACC test guideline is particularly important. operations. especially in the United States. Recognizing the increased industry interest in ACCs and the aforementioned limitations in available data. However. this has already occurred. and maintenance experience. use of the air-cooled condenser (ACC) in steam electric power plants has historically been very limited. as codes for various ACC tests are under development by the American Society of Mechanical Engineers (ASME) and the Cooling Technology Institute (CTI) and are not expected to be published in the foreseeable future. including the effects of wind on ACC performance Development of information that should be included in and solicited via ACC procurement specifications. greater industry focus on water conservation – combined with continued concern over the environmental effects of once-through and evaporative cooling – will almost certainly increase interest in ACC applications. This study covers a number of key elements of ACC specifications. Indeed. the Electric Power Research Institute (EPRI) has commissioned this project to develop ACC procurement guidelines.ABSTRACT In contrast to once-through and evaporative cooling systems. including the following: Assessment of ACC operating and performance issues. in the southwestern United States. there is no single repository of performance. vii . . John Maulbetsch was a key contributor in the development of performance specification information. Specific review and comments were provided from representatives of GEA and Marley SPX. Dr. Detlev Kröger provided project input in the areas of air-cooled condenser (ACC) operational issues. ix . Where differences in opinion or point of view remain. These acknowledgements are not meant to imply that the contributors are in complete accord with or endorse all areas of the ACC specification. Additionally.ACKNOWLEDGMENTS This effort was aided and the quality of its results improved by the contributions of a number of individuals and organizations. ACC suppliers. Dr. and Dr. the specification reflects the views of the author. Ram Chandran contributed in areas of ACC design and performance. and related technical guidance. performance testing. Environmental Systems Corporation contributed significantly to development of the performance testing guidelines. . allowable stress design American Society of Mechanical Engineers Air and Waste Management Association British thermal unit combined-cycle power plant California Energy Commission computational fluid dynamics condensate receiver tank Cooling Technology Institute adjusted decibel(s) expansion line end point free on board heat recovery steam generator inch(es) of mercury. HgA ITD J K kg/m3 kg/s kPa kW lbm m m/s LMTD MCC MMBTU/h MWe OSHA psia psig PTC °R RFP RTD air-cooled condenser actual cubic feet per minute American Institute of Steel Construction Inc.LIST OF ACRONYMS ACC acfm AISC ASD ASME AWMA Btu CCPP CEC CFD CRT CTI dBa ELEP FOB HRSG in. atmospheric initial temperature difference joule Kelvin kilogram(s) per cubic meter kilogram(s)/second kilopascal kilowatt pounds mass meter meter(s)/second log mean temperature difference motor control center million British thermal units/hour Megawatt (electric) Occupational Safety & Health Administration pound(s) per square inch absolute pound(s) per square inch gage Performance Test Code degree(s) Rankine request for proposal resistance temperature detector xi . SRC TEFC UEEP VFD single row condenser totally enclosed fan-cooled used energy end point variable frequency drive xii . ................3 Steam Ducting ...11 Spare Parts............................................. 1-5 1...........................2 Potential Assumptions and Positions of the Purchaser............................... 1-2 1........................................................................2 Structure .................................4........4.. 1-5 1....4......4.......7 Access ....... 1-5 1............................... Monorails ......................4 Overview of Air-Cooled Condenser Scope of Supply.............13 Cleaning System... Davits......................................................10 Instrumentation and Controls................................................1...6 Mechanical Equipment ..............................................................................................................4 Condensate Receiver Tank ...........................1...................................15 Shipping................4....................................................... 1-6 xiii ......................................................9 Abatement Systems................1.................................... 1-5 1................... 1-1 1.......... 1-6 1..................4..................................................... 1-4 1.......................................................................................2 Objectives ................................................................................... 1-5 1.......4........ 1-1 1......................................3 Process ..............................................3 Potential Assumptions and Positions of the Supplier................1 Finned-Tube Bundle and System .............................. 1-6 1........................................................................................................... 1-5 1.............. 1-1 1.......................................4......................1 Bid Process Dynamics – Situation Analysis.....4....4. 1-3 1..................................................14 Factory Testing ....................................... 1-5 1.........4....................... 1-6 1....... 1-2 1............................ 1-6 1........................................................................4.........................CONTENTS 1 INTRODUCTION..................5 Air Removal System ........... 1-4 1........................................... 1-4 1.5 References........... 1-5 1...... 1-3 1..........................................1 Background......................................4...................12 Lightning Protection System .......... 1-6 1........4..8 Hoists........................................................................................................................4............... ........11 Hybrid Systems.....................................................................................6 Electricity Price vs. 3-9 3................3 Basic Design Specifications ........................9 Site Noise Limitations ........... 2-11 2............................................................................................................................................................. 2-1 2......5 References.................4 Lifetime Total Evaluated Cost ............... 3-1 3............................................................8 Site Wind Conditions ...................2 Plant Type ...... 3-8 3... 2-13 3 AIR-COOLED CONDENSER SPECIFICATION .................................................................................................................2 Air-Cooled Condenser Performance...............................5 Economic Factors ... 3-24 xiv ..................................4 Site Meteorology............ 2-5 2.....1....1 Selected Performance Goals ........................... 3-17 3............ 3-3 3........................................... 2-3 2...........4..................................................................................................................... 3-5 3.......................................................... 3-15 3.....................2................................................ 3-12 3................................................................................ 3-23 3..............................3 Dry Cooling ...........................................................................................7 Multiple Guarantee Points ...................2 CONDENSER COOLING SYSTEMS OVERVIEW – INTRODUCTION AND BACKGROUND ................................................................3. 3-21 3.....4 Air-Cooled Condensers in the United States..2...................................... 3-8 3......................................................1 General Description ..... 3-16 3........1 Site Elevation.... 3-12 3.............................................................................................4..........3 Plant Design and Operating Strategy .................. Ambient Temperature ... 3-14 3.......... 3-3 3...........................................1.........3...................3............................. 3-2 3...............................................................2 Complete Optimization .....1...3...........................2 Selecting the “Optimum” Design Point .1 Sizing an Air-Cooled Condenser.....3.....2.......................3 Capital Cost Annualization..............3................3 Turbine Back Pressure and Ambient Temperature...........................................1 Steam Flow...............................3.................10 Use of Limited Water Supply ..................................................................1 Once-Through Cooling......................1 ACC Performance Characteristics................3..........................4....2 Steam Quality ......2........3....................................................3.................. 2-3 2.......3.............................................................. 2-10 2.............................................................. 3-13 3...... 2-2 2.................. 3-17 3..........2 Recirculating Wet Cooling......................2....................................... 2-1 2.................................................... 3-7 3.......... 3-19 3..................................... 3-1 3................. .. 4-12 4...............................2..................... 4-1 4............ 4-1 4..........2....12 Cleaning System............7 Hoists...................................................................... 4-11 4..............................................................................1...................1 General Requirements Overview ... 4-14 4...........................2 Specific Components ..............................2 Structure ...........................................5 Mechanical Equipment ..............2............................ 3-25 3.....................................................................................................2 Gearboxes.................................................................. 4-14 4. 4-7 4....10 Spare Parts............. 4-1 4............................................................................5 Additional Vendor-Supplied Data.................................................2..... 5-1 5.......................2........1...... 4-5 4...............................................................................2......................................4 Air Removal System ................................. 4-8 4................................9 Instrumentation and Controls.. 4-10 4....3 Steam Turbine Exhaust Pressure ...............1.....................................................8 Abatement Systems...................................................................... 4-5 4.......................................... 4-12 4..... 4-15 5 AIR-COOLED CONDENSER BID EVALUATION ............................. 4-5 4.11 Lightning Protection System .......................... 4-1 4... 5-1 5..... 4-4 4............................ 4-12 4.......................................................................................................2.....................................................4 References.....5..........................................2..............................................................2........................3 Steam Ducting ............................................2..............................3..........................................6 Access ..........................4 Verification of Supplier Performance Requirements for the Air-Cooled Condenser .... 5-1 5..................................... 5-2 xv ......1 General Requirements ................................5...........................3 References.....................2...................14 Shipping.......................................................................... 4-2 4............................................................ Davits......................................1 Initial Temperature Difference (ITD) .....................15 Additional Options..............2...................................... 5-1 5.............3............................................................................................2......................2 Steam Quality .........1.......................... 4-2 4.2..... 5-1 5............................................ 5-1 5................2... 4-14 4.........12 Spray Enhancement ..................................................1..2.............................. 3-27 4 AIR-COOLED CONDENSER COMPONENT SPECIFICATION .............................1 Finned-Tube Bundle and System .........13 Factory Testing ................................................................2.......................1 Fans .......... Monorails ......... ........ 6-6 6.........3 Test Plan ..............................................6 Fan Motor Input Power ..................3 Duration of the Test ........................ 6-3 6.....5.................. 6-9 6.............................................1 Introduction .......................................................................... 6-5 6..........1.3 Condensate Flow...........6 Important Items for Verification ...........................................7 Wind Speed .....4 Frequency of Readings ........................................... 6-9 6.................................................. 5-3 5..............................................4 Inlet Air Temperature .......................................................8 Basic Equations (A) ........................ 6-10 6....................2.............................. 6-20 xvi ..........................................................5..1 Condenser Pressure.................2 Pricing ........................................................5...................5 Test Measurements ................... 6-4 6..........................................................6.. 6-5 6..................................... 6-10 6..6 Evaluation of Test Data..........6................1 Purpose . 6-6 6....................................................3 Operating Conditions .............9 Calculation of Condenser Characteristics (B) ..........................................................................................6.........................6...................................................... 6-9 6.......5 Corrected Test Steam Mass Flow Rate .................................... 6-3 6...........................................................5. 6-11 6...............................................................................................................................7 Test Uncertainty.......................................................... 6-7 6..... 6-1 6...............................................................................5 Barometric Pressure .............................................................. 6-4 6...............2 Condition of the Equipment .......................................4 Constancy of Test Conditions ....................................2 Basis........................................................................2................. 5-4 6 PERFORMANCE AND ACCEPTANCE TESTING ..........................................................1 Test Witnesses .................................................5.................2 Steam Quality (Steam Content) ........2.4 Definitions and Nomenclature................................................................. 6-1 6........ 6-2 6...1......4 Predicted Steam Mass Flow Rate............................................................................................. 6-9 6..............................2 Manufacturer’s Data ...............................2 Conditions of Test ...................................... 6-1 6.............5............................ 6-11 6.............6.5............ 6-12 6.................................. 6-8 6....................... 6-3 6............... 6-10 6...................................................................................... 6-1 6................................................1................... 6-15 6.....................5.... 6-1 6...........1 Scope .......................3 Calculation of Condenser Capability................................ 6-14 6.2.........................................................................................................................1............1.................................... ..................... B-1 C TERMINOLOGY .................... 6-21 6...............................................2 Unloading of Air-Cooled Condenser Components .. 6-29 7 AIR-COOLED CONDENSER INSTALLATION AND COMMISSIONING ISSUES .........................................3: Combined ACC Installations as of September 2003.................................10..........10.............................................................................1: GEA Power Cooling..............3 Erection of the Air-Cooled Condenser ..A-1 Appendix A......................... 7-1 7............................ 7-1 7.................1 Overview ..... 7-3 7...............................................4.................................................................................2..... 6-27 6........ 6-21 6.. 6-23 6.....................2 Performance Curves....................4 Calculation of Condenser Characteristics ................................. 6-21 6.......................................................................................... 7-4 A AIR-COOLED CONDENSER INSTALLATIONS........ 7-2 7....................10................................................................................................................................... 7-2 7..........2..............................................2.A-11 B EXAMPLE OF AIR-COOLED CONDENSER DESIGN CHECK ....4..4.........................................................................A-9 Appendix A...................2 In-leakage Testing ............. 6-24 6....................6...................5 Correction to Guarantee Conditions ..................................10.................12 References..... C-1 xvii ...4 Rotating Equipment and Vibration Assessments ....................2 Unloading and Storage .....................................................2: SPX Cooling Technologies Reference List ...............3 Storage of Air-Cooled Condenser Components.........................6 Calculation of Condenser Capability......................... 7-3 7.......................... 7-3 7..................................................................................................................10 Example Air-Cooled Condenser Capability Calculations.... 7-1 7.............1 Shipping and Receiving ............................................................................................. 7-2 7............ A-1 Appendix A....... 7-2 7.............................................................. Inc...................................1 Pressure Testing............... 7-1 7............................... Direct Air-Cooled Condenser Installations ..................10........... 6-25 6.......................5 Walk-Through Inspection .............4...... 6-27 6........3 Internal Cleaning and System Inspections..............................4 Startup and Commissioning Tests .......................1 Design and Test Data ................................4...............................3 Predicted Steam Flow at Test Conditions ....10..... 7-1 7............................11 Calculation of Steam Quality...................................................... 1 Steam Side.............. C-3 C...................................Glossary of Air-Cooled Condenser Components ....................3 Steam/Condensate Carryover Lines .. C-2 C......7 Structural Steel.................................................... C-2 C.................................... C-3 xviii ............5 Air Take Off Side.......................... C-2 C........................... C-1 C.......................................................................................6 Mechanical Equipment....................................................................................................................8 Drain Pot System ........................................................................................................................4 Condensate Side........ C-2 C................ C-2 C........................................................................................................................................................ C-1 C.................2 Tube Bundles ............ ........................................................3-11 Figure 3-10 Turbine Output Corrections ............................................................................................................................................................................. Piping..................3-14 Figure 3-11 Sample Site Temperature Duration Curves..................LIST OF FIGURES Figure 2-1 Schematic of Once-Through Cooling ................................................................................... Condensing Pressure...2-10 Figure 2-9 Condensing Temperature vs.3-24 Figure 3-15 Schematic of Spray Enhancement Arrangement .........2-11 Figure 2-10 Air-Cooled Condenser Size vs..........................3-15 Figure 3-12 Effect of Wind on Air-Cooled Condenser Performance at Wyodak .................................................................3-4 Figure 3-3 Example Temperature Duration Curve for an Arid Southwest Site ..........3-6 Figure 3-5 Dry Cooling Initial Temperature Difference Trends ........ and Access...................................................................................................2-6 Figure 2-5 Wyodak Air-Cooled Condenser ................. Gear..................3-10 Figure 3-8 Effect of Annual Average Power Price .................. Turbine Output ...................2-3 Figure 2-4 Air-Cooled Condenser at El Dorado Generating Station – Depicting 3 of 5 Streets................................................3-11 Figure 3-9 Effect of Peak Power Price.................2-7 Figure 2-6 Schematic of an Air-Cooled Condenser (Courtesy of Marley Cooling Tower Company)....... Initial Temperature Difference ............................................................2-13 Figure 3-1 Steam Flow vs.....................................2-12 Figure 2-11 Design Fan Power vs...................................................................2-9 Figure 2-8 Photograph of a Single Row Condenser Finned Tube [e] ............................................................... Noise Reduction .............................................. Back Pressure ............... Initial Temperature Difference ....................................................................................................4-4 Figure 4-4 Example Motor.......................................................................................................................................................................................................................................................4-6 xix ...... Air-Cooled Condenser Size ...........................................2-2 Figure 2-3 Schematic of Indirect Dry Cooling System ..................................3-20 Figure 3-13 Air-Cooled Condenser Cost Multiplier vs...................................4-2 Figure 4-2 Example Steam Ducting and “Pant Leg” Distribution .............................3-6 Figure 3-6 Variation in Amortization Factor ..................................................................3-22 Figure 3-14 Hybrid (Dry/Wet) Cooling System................3-26 Figure 4-1 Example of Steam Ducting and Finned-Tube Bundles.......................4-3 Figure 4-3 Example Condensate Tank........................................3-9 Figure 3-7 Annualized Cost vs................ and Fan Hub Assembly ...........................................................3-5 Figure 3-4 Schematic of Air-Cooled Condenser Cost Tradeoffs............................2-8 Figure 2-7 Photographs of Several Finned-Tube Geometries [e] ....................2-1 Figure 2-2 Common Wet Cooling Tower Types...................3-3 Figure 3-2 Steam Turbine Performance vs........................... ..................................4-9 Figure 4-7 Upwind Screen for Reduction of Wind-Entrained Debris and Wind Effects (Chinese Camp Cogen) ..6-7 Figure 6-3 Example Performance Curve .......6-7 Figure 6-2 Schematic of Guide (Baffle) Plate ......Figure 4-5 External Walkway and Caged Ladder on a Typical Air-Cooled Condenser .........................................................................................................................................................................................................6-12 Figure 6-5 Air-Cooled Condenser Performance Curves .......................................................................4-13 Figure 4-9 Close Up of Spray Cleaner Valving on Movable Cleaning System .........4-10 Figure 4-8 Movable Cleaning Ladder System Above Tube Bundles ..................................................................6-11 Figure 6-4 Cross Plot of Test Data ......................................................6-23 xx ..............................4-8 Figure 4-6 Example Monorail System and Truss Work for Conveying Motor and Gear Assemblies for Service and Repair .......4-14 Figure 6-1 Schematic of Basket Tip......................................................................................................................................................................... .......................3-23 Table 5-1 Typical ACC Component Cost Breakdown ................................................................................3-17 Table 3-4 Multiple Operating and “Guarantee” Points ..........................................................6-5 Table 6-2 Air-Cooled Condenser Test Data..................................................6-21 Table 6-4 Condenser Pressure at Test Conditions................................................................LIST OF TABLES Table 2-1 ACC Installations in the United States......................................................................3-19 Table 3-6 Low Noise Fan Performance [g] ...............................3-23 Table 3-7 Low Noise Fan Cost Comparisons [g] .......................................................................................................................................2-4 Table 3-1 Selected Performance Goals for an Arid Southwest Site ......................6-21 Table 6-3 Performance Curves..........................................................................3-7 Table 3-2 Comparative Characteristics of Site Meteorology..........................3-18 Table 3-5 Ranking of Operating Points to Establish Limiting Case .......3-16 Table 3-3 Electricity Price Variability With Ambient Temperature........................................................................................................6-24 xxi .........5-4 Table 6-1 Measurement Frequency.................................................................................................... . methods for improving ACC performance are under consideration and evaluation.1 INTRODUCTION 1. Experience from recently commissioned plants has provided additional insights into operation and maintenance of ACCs and balancing ACC performance relative to plant performance and output. Beyond additional understanding concerning wind effects. the bid process for capital equipment in a given utility may effect a set of dynamics that does not necessarily lead to the optimum selection and purchase of equipment for the end user. However. by late 2004. and owner/operators. Indeed. Factors such as those listed below may influence and characterize this process.1 Background The use of air-cooled condensers (ACCs) for power plant applications is relatively new in the United States. Moreover.1 Bid Process Dynamics – Situation Analysis In general. The main drivers for the increased use of ACCs in the United States include the Scarcity of water and the attendant elimination of evaporative water loss from both once-through and evaporative cooling systems Reduction or elimination of thermal pollution. that number had nearly tripled. the impact of ambient wind on ACC performance is not well understood by owner/operators or their representatives in the specification and bid evaluation process. This is in contrast to a worldwide installed base of more than 700 systems (Appendix A). and impingement issues typically associated with once-through and evaporative cooling Elimination of visible plume and drift from the operating cooling system (though clearly not the primary driver) A number of quality studies exist relative to ACCs (references [a-e] at the end of this chapter). with ACCs serving approximately 7000 MWe in 60 power generation units. to some extent. no consolidated information on these methods is available to the architect/engineer or owner/operator. entrainment. This area is highlighted due to the potential for prevailing winds to degrade ACC performance. This specification provides much-needed industry insights while alerting the purchaser to issues that impact ACC specification and design. though information regarding current designs and operating issues is lacking. consultants. the total capacity of power plants with ACCs through the end of the 20th century was less than 2500 MWe. For example. 1. there is no single repository of such knowledge. while operating experience and performance data are. however. 1-1 . available from ACC suppliers.1. their motives for selecting a higher cost system... They may assume that any features or safety margins added to their bid offering would render them less competitive.Introduction 1.1. Indeed. The purchaser assumes that all suppliers have the same understanding of the technology they are proposing and are essentially offering the same solution or performance.1.3 Potential Assumptions and Positions of the Supplier Based on historical precedent. even though these features or safety margins may ultimately be in the best interest of the purchaser. Indeed. The purchaser assumes that the equipment proposed to meet their specification will perform in accordance with their expectations under a variety of ambient and plant conditions. they will not be successful in their bidding efforts. If there is basis for even some of the aforementioned assumptions and positions 1-2 .e. it can be argued that the personality of some capital equipment procurement processes is one of “low price” and skepticism regarding innovation versus cooperation and “teaming” between purchaser and prospective supplier.g. make no exceptions to the specification). e. may be diminished. The purchaser concludes that the lowest priced option is the best long-term selection for their plant. 1. They may be less apt to offer innovative solutions or advancements in the technology for fear of adding costs to their offering or exposing themselves to additional risk in execution or performance. despite the lack of operating experience for such equipment at the purchaser’s site and under circumstances that might be present there.2 Potential Assumptions and Positions of the Purchaser The purchaser or their representative assumes that the supplier of the equipment is fully aware of and has incorporated in their bid the features and impacts of the site and process wherein the equipment must perform. power industry. albeit potentially at differenct price points. one with design innovations or additional performance margins. While not all of the assumptions and positions listed above prevail in all bid processes. they are typical of the procurement dynamics for major capital equipment purchased in the U. if the supplier does not submit a low-price offering. They must seek any opportunity to reduce risk in an environment where profit margins are typically low and performance penalties may be significant. The purchaser attempts to assign all of the risk of performance and operation to the supplier of the equipment. if an architect engineer is under a fixed-price contract for the design and supply of a new plant. and that they have sufficient experience and design expertise to extrapolate from one site or experience to the next. The suppliers/bidders assume that they must meet all requirements of the specification or otherwise be disqualified from the bid process (i.S. The purchaser or their representative may unwittingly discourage technology innovation by requiring a minimum number of installations or years of experience for such offerings. beyond the historical level of attention they have received. Additionally. for the most part. both internationally and in the United States. This area of wind effects in total represents the major challenge associated with ACC specification. etc. These specifications. The following areas surfaced as ones deserving additional attention. The information contained in these ACC specifications was obtained through a number of site visits. In order to accomplish this. operation. leading to decreased airflow rates and cell thermal performance. Prevailing winds can also lead to recirculation of heated exhaust air from the ACC. they will need information to assist in answering the following questions: What are the primary ACC operating and performance problems? What information should be provided to bidders in a specification and request for proposal (RFP)? How should developers evaluate and compare bids for ACC supply? What are the most important considerations in conducting performance and acceptance testing? What are some key ACC commissioning and startup issues? 1. At the time that this report was completed.. scope of supply. and conditions. these specifications have not addressed areas that might be problematic in terms of ACC performance. 1. in many cases. 50–100 ft [15–30 m]) on an ACC. With the limited number of projects.3 Process Numerous specifications have been developed for ACCs. cover the design conditions. 1-3 . and performance. If the purchasers continue to buy low bid. but may not reflect optimum design criteria for the economic operating environment anticipated for the plant. and maintenance. the vendors will be more conservative. High winds can reduce inlet pressures on ACC upwind fans. the number of installations that do not meet owner expectations is likely to increase. design. also reducing ACC performance. codes and standards. Wind Effects – Prevailing winds can be significant at many sites. procure. Interviews with plant personnel and suppliers provided a balanced viewpoint on key issues.Introduction regarding the prospective bid dynamics. especially given the typical height of air inlets and fans (e. the market for ACCs is supplied by only two major vendors. However. each of them with large and costly proposal efforts and uncertainties associated with performance testing.2 Objectives The objective of this specification is to provide engineering and purchasing personnel with information they need to specify. and commission ACCs that feature optimum design and performance characteristics for the application.g. a review of many of these specifications suggested that the ACC design points were based on prior experience and rules of thumb. contract terms. then it is certainly possible that the final selection of supplier and equipment design are not optimal. additional pressure drop on the inlet air side can be a challenge. The notion of reducing the inlet air drybulb temperature.Introduction Range of Operating Conditions – ACCs may be required to operate over ambient temperatures ranging from less than 0°F (-18ºC) to more than 110°F (43ºC). As a result of site visits.. etc. However.2 Structure Structure refers to all materials and systems required to support and anchor the ACC and its auxiliary equipment. the following areas are typical of a U.-based solicitation. leaky gearboxes lead to carryover of gearbox grease to heat exchange surfaces. Further. In the case of film cooling. initial operation without a heat load) and operate successfully over a full range of heat loads. they may be required to undergo “cold starts” (i.e. In doing so. 1. Inlet air cooling typically involves evaporative cooling of the air via filming media or spray systems. In the case of spray cooling. it is clear that potential dust loadings.4.1 Finned-Tube Bundle and System This system is comprised of all finned tubes. fin-tube cleaning systems. particularly during periods of elevated temperatures. since the cooling media is typically installed year-round but operated on occasions of high temperature. and/or orientation of atomizing technologies.4. positioning.. Fouling of ACC Coils – Many ACCs operate in areas with high ambient dust loadings. is obviously important when power output requirements are highest. It may also be the case that nearby fuel piles – including coal. 1. and performance degradation trends warrant additional consideration. Inlet Air Conditioning – A number of ACC owner/operators have experimented with and/or are using methods for inlet air cooling of their ACCs.e. Indeed. pollen. spray cooling via atomized sprays has resulted in degradation of finned-tube surfaces at a number of sites. In some situations. 1-4 . Accordingly. carryover of sprayed droplets can also be problematic. Furthermore.S. This is particularly true in the desert Southwest portion of the United States. particular attention to ACC design and operation is critical to prevent freezing of condensate as well as proper removal of noncondensables. – can contribute to the inlet air dust loadings to the ACC and resultant fouling.4 Overview of Air-Cooled Condenser Scope of Supply The actual ACC scope of supply can include a number of areas outside of this specification. hog fuel (i. wood waste). anyone considering the use of inlet air cooling via sprays should carefully design away from such conditions. including steam distribution manifolds and the condensate collection system. The main reason for this may be improper selection. and other materials can foul heat exchange surfaces. This may also consist of necessary anchors and flanges required for interfacing with site-supplied foundations. insects. where a number of ACCs have recently been commissioned. 1. 1. 1. gearboxes. and operate the ACC.8 Hoists.10 Instrumentation and Controls This area refers to all temperature. convey across the ACC. Monorails Encompassed here are all systems required to remove. and level sensors as well as control devices to properly monitor and control the ACC. inspection ports. 1-5 . flow. rupture discs.7 Access Access refers to all stairways. 1. Davits.4.4. 1.5 Air Removal System The air removal system is comprised of a steam jet air ejector or vacuum pumps and associated skids as well as a basic control system. etc. drive shafts. structural steel. and drive motors.6 Mechanical Equipment Mechanical equipment includes fans. maintain. etc.Introduction 1. typically involves expansion joints. which begins at the turbine exhaust flange and leads to the ACC.3 Steam Ducting Steam ducting. It typically includes a protective screen at the inlet to the fan shroud. and replace/maintain all mechanical equipment.4. to safely access. manways. vacuum pumps. Also included are blanking plates for each ACC duct necessary for leak testing.9 Abatement Systems Abatement systems may involve noise abatement devices.4 Condensate Receiver Tank This tank is of sufficient size for condensate collection and a heating/freeze protection system.4. pressure. fan shrouds. and possibly a lightning protection system. lower to grade.4. Included are thermowells and pressure ports in strategic testing and monitoring locations. etc. wind screens. 1.4.4. 1. platforms. necessary vent and drain connections. ladders. It also includes the vacuum deaerator system connected to the condensate tanks.4. 1. fan hubs. inspect. etc. if required by site conditions. and associated electrical grounding. 1-6 . 1. 1. loading. Department of Mechanical Engineering.4. “Design and Specification of Air-Cooled Condensers. March 30 .5 References a) D.” presented at the ASME Power Conference. Reichelm. Thermal Flow Performance Evaluation and Design.13 Cleaning System The cleaning system includes any vendor-recommended system designed for efficient mediumpressure cleaning of finned tubes.4.April 1. (Comprehensive lightning protection may not be required on ACCs located near taller structures such as stacks or boilers. Chandran. South Africa. Moles.15 Shipping Shipping takes into account all packing. “Maximizing Plant Power Output Using Dry Cooling Systems.12 Lightning Protection System This system. 1. 1978.4. 2004.G. Private Bag X1. 1998.” Chemical Engineering.E. b) M. 7602. More detail on the above components is provided in Chapter 4. Air-Cooled Heat Exchangers and Cooling Towers. Also included are startup and maintenance lubricants for the gearboxes.4. and R. which may be provided by a specialty or electrical contractor or the ACC supplier. Kröger.) 1.14 Factory Testing Factory testing refers to all shop and key subcontractor tests required to demonstrate that infactory functionality and quality control requirements are met for each ACC. 1.Introduction 1.11 Spare Parts Spare parts are defined as all backup parts and systems required to reliably maintain the ACC and its control systems.4. conductive cable. protection. Because the ACC supplier typically is not directly responsible for ACC field erection. c) R. University of Stellenbosch. May 22. encompasses lightning rods. Larinoff. and transportation modes required to properly transport ACC equipment to the site.W. Matieland. W. construction-related aspects are not part of this specification. ” presented at the International Joint Power Generation Conference.Introduction d) D. Aug. Sohal and J.” Geothermal Resources Transactions. Chandran. 1-7 .E. 1992.S. O’Brien. 2001.F Sanderlin and R. “Operation of Air-Cooled Condensers in Cold Climates. Vol. 25. “Improving Air-Cooled Condenser Performance Using Winglets and Oval Tubes in a Geothermal Power Plant. e) M. . It has efficiency advantages related to low auxiliary power requirements (low pumping head and no fans) and lower cooling water temperature given meteorological conditions.1 Once-Through Cooling In once-through cooling. this was the commonly used form of cooling at most plants and still is used on approximately one-half of the nation’s generating capacity. dry cooling.2 CONDENSER COOLING SYSTEMS OVERVIEW – INTRODUCTION AND BACKGROUND All modern power plants with steam turbines are equipped with a cooling system to condense the steam as it leaves the steam turbine and to maintain a desired turbine exhaust pressure (back pressure). including once-through cooling. at least as of this writing. lake. Commonly employed cooling systems are described below.. However. passed through the tubes of a conventional shell-and-tube surface condenser. Steam Condenser Cooling Water Discharge Thot Cooling Water Inlet Tcold River Thot . river. water is withdrawn from a surface water source (e. recirculating wet cooling. A variety of cooling systems are used at power plants. 2. and hybrid (wet/dry) cooling. it is rarely used on new plants due to permitting difficulties related to thermal discharge and intake fish protection regulations.g. Historically. It is shown schematically in Figure 2-1. and returned to that source at an elevated temperature. while references [a-d] provide information on cooling systems that have seen less use in the United States.Tcold = Range = 20ºF (typ. ocean. etc).) Figure 2-1 Schematic of Once-Through Cooling 2-1 . Schematics of common wet cooling tower designs. Rather. The most commonly used system in recent years is the counterflow. are shown in Figure 2-2. or spray canals).2 Recirculating Wet Cooling Recirculating cooling systems are similar to once-through cooling in that the steam is condensed in a water-cooled surface condenser.Condenser Cooling Systems Overview – Introduction and Background 2. this water is sent to a cooling element/device (typically a cooling tower. Recirculating systems differ from once-through cooling systems in that the heated cooling water is not returned to the environment. The cooling is substantially accomplished through the evaporation of a small fraction of the circulating water (typically 1–2%). mechanical draft tower.and natural-draft towers in counterflow and crossflow configurations. which must be made up from local water sources. spray-enhanced cooling ponds. but in some cases cooling ponds. where it is cooled and then recirculated to the condenser. Figure 2-2 Common Wet Cooling Tower Types 2-2 . including mechanical. much like what is accomplished in an automobile radiator. 2. Figure 2-3 Schematic of Indirect Dry Cooling System In a direct system.Condenser Cooling Systems Overview – Introduction and Background 2. is shown schematically in 2-3. The direct system with a mechanical-draft ACC has been the system of choice for all dry cooling in the United States and will be the sole focus of this document.3 Dry Cooling Dry cooling refers to the cooling systems in which the ultimate heat rejection is achieved by sensible heating of atmospheric air passed across finned-tube heat exchangers. This system. which has not been used in the United States. installations as of late 2004.S.4 Air-Cooled Condensers in the United States The use of ACCs at power plants in the United States has become more common in recent years. 2-3 . the steam is ducted directly to an ACC. Indirect dry cooling systems condense the steam in a surface condenser. The remainder of this chapter identifies and discusses important considerations involved in specifying the design and performance requirements for an ACC for a particular power plant application with given site characteristics. but the heated cooling water is then cooled in an air-cooled heat exchanger. The two general types of dry systems are referred to as direct and indirect dry cooling. Either of these systems can be implemented either as mechanical-draft or natural-draft units. Table 2-1 provides a list of known U. as do once-through and recirculating systems. Extension Gordonsville Onondaga County Saranac Neil Simpson II Fairbanks Lowell Union County Huntington Linden Sayreville Silver Springs Norcon-Welsh Bellingham North Branch 1980's Exeter Spokane Grumman Haverhill Hazleton Chicago SEMASS Sherman Chinese Station Gerber 1970's Beluga Wyodak Benicia Plant Capacity MWe Turbine Capacity** MWe t/h 460 55 3x5 5 3 200 Service Date 2006 2004 2004 2004 2004 2004 2004 2004 2003 2002 2001 2002 2002 2001 2001 2001 2001 2001 2001 2001 2001 2001 2000 2000 2000 2000 2000 2000 1999 1999 1999 1998 1996 1996 1995 1994 1994 1994 1994 1994 1993 1993 1992 1992 1992 1991 1991 1991 1991 1990 1990 1990 1990 1990 1990 1989 1989 1988 1987 1987 1986 1986 1985 1984 1981 1979 1977 1975 500 450 650 278 490 1600 800 697 277 350 2 x 200 80 350 500 150 2 x 256 110 3 x 120 3x 2x 4x 2x 80 150 80 60 275 9 210 40 46.9 9 6 11 15 2x50 50 80 80 10 73 50 35 285 100 55 20 100 80 30 26 13 47 67. Browning Ferris Gas Serv. Crockett Browning Ferris Gas Serv. Bechtel. Lowell Odgen Martin Sys. Naval Station Snowflake Curant Creek Silverhawk Poletti Big Horn Ravenswood Chehalis Mystic Fore River APEX Otay Mesa Choctaw County Moapa WyGen I/Unit 3 Hunterstown Sutter Front Range Bellingham Goldendale Atherns Lake Road Blackstone Midlothian Hays 1990's Rumford El Dorado Tiverton Dighton Crockett Mallard Lake Landfill Rosebud Cedar Falls Haverhill Extension Arbor Hill Pine Bend Landfill Islip Dutchess Co.Condenser Cooling Systems Overview – Introduction and Background Table 2-1 ACC Installations in the United States State NY MN AL CA AZ UT NV NY NV NY WA MA MA NV CA MS NV WY PA CA CO MA WA NY CT MA TX TX ME NV RI MA CA IL MT IA MA MI MN NY NY VA NY NY WY AK MA NJ NY NJ NJ NY PA WA WV CT WA NY MA PA IL MA ME CA CA AK WY CA Vendor* SPX GEA GEA GEA GEA GEA Hamon Hamon Hamon Marley/BDT Marley/BDT Hamon Hamon Marley/BDT GEA GEA GEA GEA GEA Hamon GEA Marley/BDT GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA GEA Marley/BDT GEA Marley/BDT GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT GEA Hamon GEA GEA Marley/BDT GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Customer Astoria Energy FibroWatt US Army Noresco Pinnacle West PacifiCorp Genwest LLC/Silverhawk NYPA/GE/Sargent & Lundy Reliant/Sargent & Lundy Key Span Parsons Sithe/Raytheon Sithe/Raytheon Mirant Calpine Reliant Nevada Power Black Hill Generation Reliant Calpine/Bechtel Front Range Power ABB GoldendaleEnergy PG&E Generating ABB ABB ABB ABB Rumford Power Associates Sempra Energy / Reliant Energy Tiverton Power Associates Energy Mangement Inc. Billings Generation Municipal Electric Utility Ogden Martin Sys. Agency Dutchess County Mission Energy Odgen Martin Sys. Inc. of Haverhill Browning Ferris Gas Serv. TBG Cogen Ogden Martin Systems ABB Chicago Northwest American Ref-Fuel Wheelabrator Sherman Energy Pacific Ultrapower Pacific Gas & Electric Chugach Electric Black Hills Power/Pacific Power Exxon Project/Site Astoria Fibrominn Biomass Ft. Wainwright CHP Plant 32nd St. Intercontinental Energy Indeck Energy Falcon Seaboard Intercontinental Energy Energy America Southeast Oxford Energy Wheelabrator Environ. Inc. Ogden/Marin/Huntington Cogen Technologies Inc. MacArther Res.5 1 54 20 22. Inc. Rec.7 65 330 NA 256 256 255 256 2-4 . Falcon Seaboard Black Hills Power & Light University of Alaska CRS Sirrine. Sys.4 3. are clustered in bundles typically 8 ft (2.5 m) across. One cell in each row – typically one of the center cells out of five or six along the row – is a “reflux” or “dephlegmator” cell.1 General Description A schematic of an ACC is shown in Figure 2-6.” (Three out of five streets are visible in Figure 2-4. For typical cell plan dimensions of 40 ft x 40 ft (12 x 12 m). The ACC footprint is typically 200 ft x 250 ft (60 m x 75 m). This cell functions to remove noncondensable gases from the condenser. Uncondensed steam from the other cells in the row along with entrained noncondensables flow along the condensate header to the bottom of the reflux-cell tube bundles. An air-removal system (vacuum pumps or steam ejector) removes the noncondensables through the top of the reflux cell bundles. These typically lowspeed fans feature two-speed (100/50 rpm) drives and five to eight blades. providing forced-draft air cooling to the finned-tube heat exchangers.2 million pounds of steam per hour (125–150 kg/s) – might typically have 30–40 cells. In the direct dry cooling system. inclined rows in both walls of the A-frame cell. The finned tubes. sometimes referred to as “streets” or “lanes.4. Large axial flow fans – typically 28–34 ft (8. while Figure 2-8 depicts the SRC finned tube. Vertical steel columns and extensive bracing support the cells and fans. with the steam duct at the top of the cells rising to 100–120 ft (30–35 m) or more above grade. Steam from the steam distribution manifold enters the tubes at the top.0–1. each having the aforementioned geometry. Designs vary considerably depending on allowable noise levels at the site. air-cooled heat exchangers arranged in an A-frame (or delta) configuration. The condensate flows by gravity to a condensate receiver tank from which it is pumped back to the boiler or heat recovery steam generator (HRSG). typically about 30–40 ft (9–12 m) long. condenses on the inner tube walls and flows downward (concurrent with remaining uncondensed steam) to condensate headers at the bottom of the bundles. Additional condensation takes place in this cell and the condensate runs down (flowing countercurrent to the entering steam) into the condensate header. there are five bundles on each face. Each cell consists of several bundles of finned tubes arranged in parallel. A 500-MW combined-cycle plant – condensing approximately 1. round fins to elliptical tubes with plate fins. Figure 2-4 provides a photo of an ACC installation at the Wyodak Station. Figure 2-7 shows pictures of several finned-tube geometries. Most recent ACC designs have used elongated.5–10 m) in diameter – are located in the floor of the cells. A typical full-scale ACC consists of several such rows. arranged in a 5 x 6 or 8 x 5 or two 4 x 5 layouts. or 10 bundles per cell. nearly rectangular flow passages separated by plate fins.Condenser Cooling Systems Overview – Introduction and Background 2. referred to as a single row condenser (SRC). usually arranged in two to four rows in a staggered array. 2-5 . as shown in Figure 2-6.) Each row consists of several cells. Finned-tube geometries have evolved from circular tubes with wrapped. turbine exhaust steam is ducted from the turbine exit through a series of large horizontal ducts to a lower steam header feeding several vertical risers. The fan deck is often 60–80 ft (20–25 m) above grade. Each riser delivers steam to a steam distribution manifold that runs horizontally along the apex of a row of finned-tube. This windwall is not shown in the schematic (Figure 2-6). Figure 2-4 Air-Cooled Condenser at El Dorado Generating Station – Depicting 3 of 5 Streets 2-6 .Condenser Cooling Systems Overview – Introduction and Background The cells are typically surrounded by a windwall to reduce the possibility of hot air recirculation and wind effects. but is visible in the Figure 2-5 photograph as a yellow wall surrounding the A-frame tube bundles. Condenser Cooling Systems Overview – Introduction and Background Figure 2-5 Wyodak Air-Cooled Condenser 2-7 . Condenser Cooling Systems Overview – Introduction and Background Figure 2-6 Schematic of an Air-Cooled Condenser (Courtesy of Marley Cooling Tower Company) 2-8 . Condenser Cooling Systems Overview – Introduction and Background Figure 2-7 Photographs of Several Finned-Tube Geometries [e] 2-9 . The condensation of steam requires the removal and transfer of large quantities of heat (~1000 Btu/lb steam [2. since a saturated two-phase mixture of water and steam is present. Figure 2-9 gives the relationship between the condensing temperature and condensing pressure over the range of pressures typically relevant to cooling system design. The condensing side temperature is nearly isothermal.2 Air-Cooled Condenser Performance The previous section described general ACC circuitry as well as the flow paths of the steam. The condensing temperature is related to the condensing pressure. 2-10 .Condenser Cooling Systems Overview – Introduction and Background Figure 2-8 Photograph of a Single Row Condenser Finned Tube [e] 2. and cooling air.3 x 106 J/kg]) to the atmosphere. minus any pressure drop in the steam lines between the turbine exhaust flange and the heat exchanger bundle inlet. which is equal to the turbine exit pressure. or back pressure.4. condensate. The heat of condensation is transferred to the cooling air stream by the temperature difference between the condensing steam and the cooling air. 4. ITD = Tcond – Ta inlet Equation 2-1 For a given ACC.39475907p3 . known as the initial temperature difference (ITD). Condensing Pressure The cooling air enters at approximately the ambient dry-bulb temperature and is heated. 2. 2-11 . for a given heat load. There is a discussion of selection of the ACC design point in Section 3. the size (number of cells.2.01209797p4 + 0. Under some conditions. a small amount of the heated air leaving the ACC may be entrained (recirculated) into the inlet air stream. in Hga Figure 2-9 Condensing Temperature vs. as it passes across the heat exchanger bundles.80059594 Condensing Pressure. the heat load Q [Btu/hr (W/s)] is related to the ITD by Q/ITD = Constant Equation 2-2 Alternatively.90131432p2 + 32. heat transfer surface) is inversely related to the ITD as ACC “Size” α 1/ITD β Equation 2-3 where a low ITD corresponds to a large ACC.Condenser Cooling Systems Overview – Introduction and Background 170 160 Condensing Temperature. deg F 150 140 130 120 110 100 90 80 70 0 2 4 6 8 10 12 14 T = -0.1 ACC Performance Characteristics The ACC design point is frequently characterized by the difference between the condensing temperature (Tcond) and the entering air temperature (Ta inlet).4.63687841p + 51. resulting in an increased inlet temperature to some cells. typically by 25–30°F (~14–17°C).2. etc. ACC Performance Curves) 80 70 60 No. It is important to note that the number of cells does not vary continuously. two 5 x 4). for example. fin spacing. With ITD increases at constant heat load.Condenser Cooling Systems Overview – Introduction and Background Figure 2-10 shows ACC size (as number of cells) vs. but is always a number that can be factored into a reasonable rectangular or square array. deg F 45 50 55 60 Figure 2-10 Air-Cooled Condenser Size vs. with ITD variations from the mid-50s to the upper 30s (as. the number may shift from 25 to 30 to 36. ITD for a heat load of about 1.0 million lb steam/hour (125 kg/s) over a wide range of ITDs corresponding to various ACC sizes. 40 (5 x 8. Initial Temperature Difference (For a condensing duty of ~1. Number of Cells (from National Study. 36 (6 x 6). 25 (5 x 5).0 billion Btu/hr (0. Cost Info. Over this range. However. in Figure 2-11). the number of cells does not change continuously. 30 (5 x 6 or 6 x 5). in order to maintain a reasonably square array. of Cells 50 40 30 20 10 0 20 25 30 35 40 ITD. as this is a common motor size. Figure 2-11 shows a typical range of design fan power for an ACC sized for 1. and other design values. Additional variability can also be obtained by changing tube length. 2-12 .0 million lb steam/hour) ACC fans for recent designs are typically rated at 200 hp (150 kW). Syst. Typical values are 20 (4 x 5 or 5 x 4). the performance shifts are modulated by varying the design fan horsepower over the range of ITDs for a given number of cells.3 x 109 W) (approximately 1. and the input power may be 480-V supply. the design fan power decreases along with the ACC size and number of cells.0 million lb steam/hr [125 kg/s]). As noted earlier. c) P.” presented at the California Energy Commission (CEC)/EPRI Advanced Cooling Strategies/Technologies Conference.000 10. Sacramento. HP 8.000 2.0 million lb steam/hour [125 kg/s]) 2. June 1-2. California. Matieland. Private Bag X1. “Cost/Performance Comparisons of Alternative Cooling Systems.S. Sacramento. 2-13 .000 0 20. Demakos. 7602. Maulbetsch and K. b) Balogh and S. 1998. d) Benefiel.000 4. 2005.D. South Africa.0 25. Air-Cooled Heat Exchangers and Cooling Towers.0 50.000 12. “Closed-Loop Wet Surface Evaporative Cooling Systems for Steam Condensing and Auxiliary Loop Cooling in Water Limited Power Plants. 2005. University of Stellenbosch. Initial Temperature Difference (For a heat duty of 1. California. June 12. June 1-2.0 55. and M.000 Fan Power.0 60. Zolton. F Figure 2-11 Design Fan Power vs. Department of Mechanical Engineering.0 30. 2005.G.000 6. Thermal Flow Performance Evaluation and Design.0 45. 2005. Sacramento. June 1-2. J. “Water Conservation Options for WetCooled Power Plants.S.0 ITD. California.” presented at the CEC/EPRI Advanced Cooling Strategies/Technologies Conference. California.Condenser Cooling Systems Overview – Introduction and Background 14. Zammit.” presented at the CEC/EPRI Advanced Cooling Strategies/Technologies Conference. Kröger. DiFilippo. e) D. “The Advanced Heller System: Technical Features and Characteristics. Maulbetsch.0 35.” presented at the CEC/EPRI Advanced Cooling Strategies/Technologies Conference. Sacramento.5 References a) J.0 40. . ºF (ºC) Site elevation. In addition. An equivalent description sometimes used is “steam moisture” (ξ). is the method of determining the preferred or optimum design point for that plant at that site.0). in Sacramento. The first is the approach to choosing an ACC to meet a particular level of performance at specified operating conditions for a given plant at a given site. W. held June 1-2. The second. there are a number of plant and site characteristics and business factors that influence the choice of the optimum ACC.” Therefore. All dry steam at saturation conditions has a quality of 100% (x = 1. HgA) (kPa) Ambient dry-bulb temperature. Tamb. inch(es) of mercury. 3.1 Sizing an Air-Cooled Condenser The minimum amount of information required to establish the simplest ACC design point is as follows: Steam flow. ft (m) above sea level “Steam flow” refers to the total flow passing through the steam turbine exhaust flange and consists of both dry steam and entrained liquid water droplets. pb. and more complex question. 2005. These will be identified and discussed later in this section. defined as the percent of liquid water in the “steam flow. “Steam quality” refers to the fraction of the steam flow that is dry steam and is expressed as a decimal fraction or a percent. atmospheric (in. California. The reader should also review references [a-g] at the end of this section along with proceedings of the CEC/EPRI Advanced Cooling Strategies/Technologies Conference.3 AIR-COOLED CONDENSER SPECIFICATION Specification of an ACC requires consideration of two key issues. lb/hr (kg/s) Turbine exhaust steam quality. 3-1 . x (lb dry steam/lb turbine exhaust flow) Turbine back pressure. The following discussion will be organized into two sections: ACC sizing for a given operating point Determination of the optimum design point The initial discussion will illustrate the approaches for the simplest set of design considerations. hcond [Btu/lb (J/kg)].5 kg/s). the steam-side capacity is approximately one-third of the plant total.5) 0.Air-Cooled Condenser Specification ξ = 1. HgA.95) 4. at the design condensing pressure) to determine the heat load. Q [Btu/hr (W)]. The following example illustrates the considerations in selecting an appropriate design point.1 x 106 (137. combined-cycle plant located in an arid desert region might select the following design values: Steam flow. Although some differences exist among plants of comparable size.8132 Equation 3-3 1.1. An ACC for installation at a 500-MW (nominal).1 Steam Flow Figure 3-1 displays the design steam flow for a number of modern plants plotted against steam turbine output.0 – x Equation 3-1 These properties are used. gas-fired.3 kPa)] For a nominal 500-MW. (kPa) Ambient temperature.1 x 106 lb/hr (137. which must be handled by the ACC. with a corresponding steam flow of approximately 1. lb/hr (kg/s): Quality. or about 170 MW. 2 x 1 combined-cycle plant. pb.95 (0.7) [pamb = 29. and the difference between the enthalpy of the inlet steam. Specification of the five quantities above is sufficient to obtain a “budget” estimate from ACC vendors. according to the following equation: Q[Btu/hr (W)] = W[lb/hr (kg/s)] * x[lb/lb (kg/kg)] * hfg[Btu/lb (J/kg)] Equation 3-2 The turbine steam flow and quality at the plant design load are obtained from information provided by the turbine vendor. The heat load is determined by the total steam flow. hfg [Btu/lb (J/kg)]. F (C) Site elevation – Sea level The values were selected as follows: 3. along with the thermodynamic properties of steam and water (including the latent heat of vaporization.459 * (MWsteam)0. lb/lb (kg/kg) Back pressure.5) 80 (26. in. x. W.0 (13. 3-2 .92 in. a reasonable correlation is shown and given by W(lb/hr) = 17. hsteam inlet [Btu/lb (J/kg)] and the enthalpy of the leaving condensate. Tamb. HgA (101. the turbine efficiency improves (heat rate decreases) as the back pressure is lowered.98.000 3.2 Steam Quality Turbine steam exit quality (or enthalpy) must be obtained from the specific turbine design information or be determined from full-scale turbine tests. MW Flow = 17.0–2.000.000. lb/hr 3.459MW 0.1. fan power.000.000 1.3 Turbine Back Pressure and Ambient Temperature For a given heat load.5 kPa).92–0. a slight increase occurs. back pressure curve for a turbine selected for use on a combined-cycle plant with an ACC.500. in some instances.000 2. the combination of turbine back pressure and ambient temperature at the design point essentially determines ACC size. Turbine Output 3.Air-Cooled Condenser Specification Steam Flow Per Unit Output APEX Choctaw County Hunterstown Poletti Athens El Dorado Lake Road Silverhawk Bellingham Fore River Midlothian Sutter Big Horn Front Range Moapa Blackstone Goldendale Mystic Chehalis Hays Otay Mesa 4. Back Pressure – Over the normal operating range.000 Steam Flow. cost.8–8. no further reduction in heat rate is achieved and. HgA (6.000 0 0 100 200 300 400 500 600 Capacity (Steam side only).1.95 (5% moisture) represents a reasonable value.8132 Figure 3-1 Steam Flow vs. For estimating purposes. Most turbines are restricted to operating at back pressures 3-3 . Below about 2.500.000 500. a quality of 0. Typical values range from 0.5 in. 3.000.000 1.500. and off-design performance. Figure 3-2 displays a typical load correction vs.000 2. 3-4 . giving an ITD (from equation 2-1) of 46. HgA (13.1ºF (52. Backpressure Combined Cycle with ACC 10 5 Correction to Load.0 in. the ambient temperature varies widely during the year. Other southwestern sites are comparable.1 kPa).5 kPa). Figure 3-3 shows a temperature duration curve based on 30-year average data from El Paso. Texas.7 kPa) and “trip” @ 8. HgA (27.1ºF (25. A summer average temperature of 80 ºF is reasonably consistent with the choice of an intermediate back pressure for an example operating point.0 in.3ºC).0 in.0 in.5 kPa) corresponds to a condensing temperature of 126. Typical guidelines are: “alarm” @ 7. From Figures 2-10 and 2-11. Back Pressure Ambient Temperature – At the desert site chosen for this example. Load Correction vs. HgA (23. this would require an ACC of about 30 cells and a fan power requirement of about 5000 hp (3750 kW).6ºC). HgA. the back pressure was set at an intermediate value of 4. % 0 -5 -10 -15 0 1 2 3 4 Turbine Backpressure. HgA (13. For this example.0 in. in Hga 5 6 7 8 Figure 3-2 Steam Turbine Performance vs. A back pressure of 4.Air-Cooled Condenser Specification below 8. The trend has moved toward ITDs in the mid-40 ºF range. a large ACC may defer or avoid the need to reduce load on the highest temperature days during the summer. experience and market forces have led to the selection of larger ACCs (lower ITDs). A large ACC with a low ITD entails high capital costs and high fan power consumption. there is no assurance that the choices above result in a preferred design for the particular plant. F 120 100 80 60 40 20 0 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Hours Above Temperature. the choices of back pressure and ambient temperature essentially fix the ACC design size for a given heat load. This design optimization requires that selection of the ACC design point be based on an informed tradeoff between initial capital cost of the installed equipment and the operating and penalty costs to be incurred during the operating life of the plant. In addition. These tradeoffs are illustrated schematically in Figure 3-4. Figure 3-5 [g] provides a trend of ACC design choices for modern ACCs. and increased plant capacity during the hotter periods of the year.Air-Cooled Condenser Specification Temperature Duration Curve Ambient Temperature. it achieves lower turbine back pressures at any given ambient temperature with correspondingly higher plant efficiency and output throughout the year. Such ACCs have resulted in higher capital cost but improved performance. site. and business conditions. However. greater plant efficiency throughout the year. hr Figure 3-3 Example Temperature Duration Curve for an Arid Southwest Site 3.2 Selecting the “Optimum” Design Point As noted above. However. 3-5 . Over the past 20 years. The second is to perform a complete optimization analysis to determine which ACC specification would correspond to the minimum annual (or lifetime) total evaluated cost. and most common. 3-6 . there are two approaches to selecting the optimized design point.Air-Cooled Condenser Specification Tradeoffs 35 30 25 Cost 20 15 Total Evaluated Cost 10 Capital Cost 5 Operating and Penalty Costs 0 2 3 4 5 Optimum 6 7 8 9 10 Cooling system size Figure 3-4 Schematic of Air-Cooled Condenser Cost Tradeoffs Figure 3-5 Dry Cooling Initial Temperature Difference Trends In general. is to base the choice on a few performance goals at selected ambient conditions during the year. The first. 8) 36.2/(22.0 in. Alternatively.5 in. ºF/(ºC) 65/(18) 2.1 Selected Performance Goals The choice of desired performance at a few conditions depends on a knowledge of plant operating characteristics (such as heat rate and capacity as a function of ambient temperature and steam turbine back pressure) along with the owner’s business strategy and financial performance goals. especially performance at periods of peak system demand.7/(42. the purchaser’s primary concern might be to maintain the rated plant output and heat rate at average annual site conditions. It must be emphasized that this comparison is very approximate. but is intended to illustrate the point that knowledge of plant characteristics and performance goals over the range of expected site conditions can be used to bracket the options for specifying ACC performance. but will result in higher back pressure and. This is a common approach to specifying the ACC design point. One set of performance goals covering these situations might be the following: Maintain rated plant performance at a steam turbine back pressure of 2. may be a particularly important consideration. HgA (13. it must include consideration of a number of factors in much more detail than the simple assumption of 3-7 . These conditions for a site in the arid U. Table 3-1 Selected Performance Goals for an Arid Southwest Site Ambient Temperatures.2) Summer Average 80/(27) 4. lower efficiency and lower output at the summer average and peak temperature conditions.5 kPa) at the annual average temperature. occurs during the peak summer hours.6) 43. For example.0/(13. ºF/(ºC) Annual Average Tambient. hence.5 kPa) at a temperature reached no more than 50 hours per year.2/(49) 40. Avoid turbine alarm conditions at a back pressure of 7. Maintain an acceptable heat rate at average summertime conditions and a maximum output reduction from rated design output of 2%. but to be done properly.2.0 in. HgA/(kPa) Condensing Temperature.5) 146.7/(24. Similarly.9/(63. the smallest and least expensive ACC will satisfy the annual average requirement. requiring the largest ACC.Air-Cooled Condenser Specification 3.5 kPa). summertime performance. corresponding to a back pressure of 4.0/(23. HgA (23. ºF/(ºC) ITD.5) This rough comparison of the ITDs at each condition suggests that the most demanding condition.5/(8. HgA (8.3) 50 Hottest Hours 110/(43) 7. in.S. ºF/(ºC) Back Pressure.5) 120. Southwest (Figure 3-3) are shown in Table 3-1.9/(20.5) 108. Some of these factors include plant design characteristics.2. expected power price as a function of ambient conditions. 3. 3.2 Complete Optimization While consideration of a few chosen performance goals. These issues are reviewed in greater detail in succeeding sections. n.2. using ACC cost and fan power correlations vs. site temperature duration curves. as determined from the limitation on plant output required to avoid laststage turbine over pressure during the hottest hours Each of these costs must be evaluated for a range of ACC sizes. motor and gearbox upkeep.Air-Cooled Condenser Specification desired back pressure. and steam turbine heat rate (or output reduction) curves. design ITD. the operating. the contractual status of the plant within the larger power system. The initial capital cost is then converted to an equivalent annual cost as a function of expected plant life. as determined from the influence of ACC performance on plant efficiency and output reduction throughout the year Capacity penalty cost. severity and duration of peak load periods.3 Capital Cost Annualization In this method. and the effect of other site conditions such as prevailing wind patterns. etc. is a common approach to ACC specification. a more complete analysis is required to balance the initial capital costs against the continuing operating. To determine the optimum design. centered on routine inspection. The capital cost and the future operating and penalty costs must then be expressed on a common basis. and penalty costs are calculated for the first year of operation using current cost information. This can be done in one of two ways. it does not assure that the selected ACC is the economically optimum choice for the plant. as described above. and penalty costs. and an expected discount rate. 3-8 . primarily in the form of ACC fan power consumption Maintenance cost. maintenance. cleaning. i. The full set of costs to be considered includes: ACC capital cost. including equipment and installation Cooling system operating and maintenance costs Operating cost. maintenance. All such factors must be considered when assessing the relative importance of seasonal performance goals in terms of ACC capability and cost. Penalty costs Heat rate penalty cost. using an amortization factor given by: F = {i x (1 + i)n}/{(1 + i)n – 1} Equation 3-4 Figure 3-6 displays this conversion. and penalty costs are projected year-by-year into the future for the expected life of the plant.4 Lifetime Total Evaluated Cost In this method. and power. maintenance. and electricity differ from one another and cannot be properly represented by a single amortization factor.020 0. This requires assumed future costs and prices for labor. Each yearly cost is then discounted to a present value using expected long-term discount rates.000 4 5 6 7 8 9 10 11 Discount Rate. 3-9 . Describing and providing the data. correlations.040 0. arid site with the ambient temperature duration curve shown in Figure 3-3. and procedures for the complete optimization methodology are beyond the scope of this document. as in the “capital cost annualization” method. % Figure 3-6 Variation in Amortization Factor 3. the annual operating. a complete treatment is developed and presented in a recent EPRI report [c].2. fuel.Air-Cooled Condenser Specification Amortization Factor n = 10 0. That EPRI study featured a case study for a combined-cycle plant at a hot.100 0.060 0. However. The results of the two methods vary to the extent that future increases in the prices of labor. Two points are noteworthy.140 n = 12.120 0. The yearly costs are then summed and added to the initial capital cost. fuel. The results are shown in Figure 3-7.160 0.180 0. The minimum annualized cost is seen to occur at an ITD of approximately 45ºF.080 0.5 n = 15 n = 20 n = 30 Amortization Factor 0. F 45 50 55 60 Figure 3-7 Annualized Cost vs.000 $4. $ $6. the sacrifice of hot weather performance in exchange for a lower cost ACC resulted in a lower annualized cost.000 $3.000.000.Air-Cooled Condenser Specification Annualized Cost vs. Figures 3-8 and 3-9 display the results of the same example for a range of annual average (Figure 3-8) and peak load (Figure 3-9) power prices.500. It would be expected that assumptions of higher expected value of electric power (either throughout the year or especially at peak demand periods in the summer) might alter the result.000 $5.000 $5.500.500.500.000 Annual Cost. Air-Cooled Condenser Size This result is reasonably consistent with the overall trend of ACC selections shown in Figure 3-5. As shown. 3-10 . This has no generalized significance but suggests that for the assumptions used in that particular example. ACC Size--Site 1 $6. The result is at the high ITD (small ACC size and cost) end of the example choices shown above for the “Selected Performance Goals” approach in Table 3-1.000.000 20 25 30 35 40 ITD.000 $4. increases in either one drive the optimum ACC size to lower ITDs and thus larger ACCs. F Figure 3-8 Effect of Annual Average Power Price Effect of Peak Period Power Prices on ACC Optimization Site 1---Hot.000 $5.000.000.000.000 Annual Cost.000.000 $7.000.000.500.000 $6.000 $4.000 $3.000 $1.000 $8.000.000.000 20 25 30 35 40 45 50 55 60 ITD.500.000 $3.000 $100/MWh $250/MWh $500/MWh $6.000.000 $5.000.000 $0 20 25 30 35 40 45 50 55 60 ITD.000.000 $2.000 $50/MWh $75/MWh Annual Cost. F Figure 3-9 Effect of Peak Power Price 3-11 .000 $4.Air-Cooled Condenser Specification Effect of Year-Round Power Price--Site 1 Base--$35/MWh $9.000 $4.500.000. $ $5.500. $ $6. arid Base $7.000. freezing conditions) Topography and obstructions Nearby hills. the ambient air density is only 83% of that at sea level. as developed on a site-specific basis. which are listed here but will be discussed in the following sections. including auxiliary coolers. the ACC design (and cost) will be affected by a number of plant and site characteristics.Air-Cooled Condenser Specification 3. etc. which is the driving force for heat transfer across the finned-tube bundles. Geological Survey databases as part of their National Seismic Hazard Mapping Project 3. For the same heat load. Other heat sources or interferences Noise limitations at the ACC itself or at some specified distance.S.3 Basic Design Specifications In addition to these basic quantities. Site topography and features Site elevation Site meteorology Annual temperature duration curves Prevailing wind speeds and directions Extreme conditions (hottest day. width) Location restrictions.92 in. coal piles. requirements. Nearby structures. particularly distance from turbine exhaust Seismic loads. etc. a 6% increase in fan speed would result in the same fan power but a reduction in the mass flow of air of about 12%. valleys. fan power. with pertinent data obtained from U. An analysis of the effect of elevation on ACC size. At 5000 ft (1500 m). etc. HgA. and cost over an elevation range of sea level to 5000 ft (1500 m) indicates no change in the basic size (number of cells) or fan horsepower.3. This is explained in the following way. the air temperature rise will therefore be 12% greater with a corresponding decrease in the log mean temperature difference (LMTD). but a moderate cost increase of 5–10%. plant vents. To compensate for 3-12 . Nearby heat sources. as set by neighboring communities or open space sanctuaries Maximum height restrictions “Footprint” constraints (length. and zones. Using conventional fan laws. The effect of site elevation on ACC design is minor but not negligible.1 Site Elevation The site in the earlier examples was assumed to be at sea level with a normal barometric pressure of 29. In some merchant plant situations. Because of the higher steam turbine inlet pressure and temperature in steam plants.3. the steam plant suffers less performance penalty during the hotter periods. The comparison between the output correction curves is shown in Figure 3-10.2 Plant Type The choice of the optimum ACC is affected by the performance characteristics of the type of plant at which it is to be used. and shallower output correction curves (vs. a number of recent ACC procurements have resulted in selections with ITDs in the 28–40 ºF range. or about 170 MW. This increase in height results from the need to elevate the fan deck more for a larger cluster of cells in order to provide free flow of air to the interior cells. mixing coefficients. higher ITD. 3-13 . and lower cost per unit heat load. lower steam flow per unit output. Similar modifications of some structural dimensions (such as tube length to maintain comparable air-side velocities. a significantly larger unit may have higher costs for extended steam supply ducting and a higher structure. even neglecting differences in steam turbine heat rate. The comparison of most interest is between simple-cycle steam plants (normally coal-fired) and gas-fired combined-cycle power plants (CCPP). back pressure) than turbines designed for CCPPs. Most CCPPs of recent design have been (nominally) 500-MW plants. the turbines typically have lower heat rates. One important difference is simply size. Having said this. the heat load to be rejected through the ACC is typically two to three times greater at a steam plant than at a CCPP. As a result of the lower reduction in output at elevated back pressure. with a steam turbine providing approximately one-third of the plant output at design. While similar considerations would apply to nuclear steam plants. Coal-fired steam plants. Therefore. Another and more important distinction is the difference in steam turbine performance characteristics between the two plant types.to mid-50s (degrees F). range from 350–500 MW or larger and the entire output is generated by the steam turbine. 3. While the equipment cost for an ACC is essentially linear with heat load. and other flow characteristics) would likely be required and appear reasonably consistent with a modest (~5–10%) increase in cost. A recent study [c] indicates that ACCs at steam plants optimize at ITDs in the low. turning losses. The ACC therefore optimizes at a smaller size. there is little experience with the use of dry cooling at nuclear plants.Air-Cooled Condenser Specification this reduced heat transfer driving force. on the other hand. modest increases in the finned-tube surface area are made. while those at CCPPs optimize in the mid-40s (degrees F). the ability to competitively deliver power during summer can drive the selection to lower ITDs. The crucial question is: What are the purchaser’s expectations for plant performance during the hottest hours of the year? During the hightemperature periods. As a result. It must be recognized in this latter case. The penalty is valued as increased fuel cost.3 Plant Design and Operating Strategy Plant design and planned operating strategy also have an important influence on the choice of the optimum design point for the ACC. For a combined-cycle plant. As the ambient temperature increases. it can increase its firing rate. the situation is more complicated. and hold the power output at the design level. costlier turbine and ACC than would be chosen for the former (constant firing rate) assumption. resulting in a larger. Consequently. the mass flow of air to the combustion turbines decreases as the inlet air density decreases. that the ACC must be sized to handle a higher steam flow at the highest ambient temperatures.3. resulting in increased turbine heat rate.Air-Cooled Condenser Specification Output Correction Curve Comparison Steam 2 0 -2 CCPP % Output Reduction -4 -6 -8 -10 -12 -14 0 1 2 3 4 5 6 7 8 9 Backpressure. Combustion turbines are essentially constant volume flow machines. the steam turbine back pressure will increase. nearly all 3-14 . the plant must accept a reduction in plant output. not only is the steam cycle portion of the plant affected by the higher steam turbine back pressure. the power output of the combustion turbines decreases as well as the hot gas flow to the heat recovery steam generator (HRSG) and the steam flow to the steam turbine. With a rise in ambient temperature. inHga Figure 3-10 Turbine Output Corrections 3. In this situation. but also the combustion turbine portion of the plant is affected as well. send a higher flow rate of steam to the turbine. in areas where high summertime temperatures are expected. If the plant was designed and built to do so. in which case the cost penalty is valued as lost revenue from reduced output. 3. They are based on 30year average data from a hot. help maintain the mass flow of air to the combustion turbines closer to the design flow. instead of the nominal one-third (~170 MW). arid site in the Southwest and a cold. Obviously.3. arid site in the Northern Plains. where the plant owner has specified that design plant output must be maintained throughout the year. Temperature Duration Curves Hot.4 Site Meteorology The ambient dry-bulb temperature and its variation throughout the year are the most important site characteristics influencing the optimum design point of an ACC.Air-Cooled Condenser Specification CCPPs are equipped with both combustion turbine inlet air coolers and duct burners. deg F 60 40 20 0 -20 -40 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Hours Above Tambient. the steam turbine may be sized to deliver nearly one-half the plant output (nominally 250 MW) during the hot periods. arid T ambient. which are either chillers or evaporative coolers of the spray or matrix type. Duct burners supplement the input to the HRSG as the combustion turbine exhaust gas flow decreases. arid 120 100 80 Cold. In some cases. Figure 3-11 displays the temperature duration curves for two sites with very different meteorology. The inlet air coolers. hr Figure 3-11 Sample Site Temperature Duration Curves 3-15 . this requires an ACC sized for the higher load at the highest ambient temperature. future operating costs and performance penalties. certain elements of economic expectations and business strategy have an important influence on the selection of the optimum design point. Such factors will also impact the relative importance of initial capital cost vs. inflation. These considerations are highly specific to individual companies and 3-16 . the annual average heat penalty is much lower and the high ambient temperature capacity penalty is incurred for a much shorter time at the plains site compared to the desert site. the plains temperatures are from 10–30 ºF (5–15 ºC) lower. etc.) Variability of electricity price with ambient temperature Differing circumstances and assumptions regarding these factors can greatly affect the size of the cost penalties associated with ACC performance limitations at high temperatures. unregulated) Expected duration of plant ownership Future economic projections (fuel and electricity price.5 Economic Factors In addition to plant and site characteristics. These lower penalty costs drive the optimum system design to a much smaller ACC with a much lower capital cost for the plains site. hours Hours above 100 ºF Hours below freezing ~ 60 ~340 ~6 ~3000 65 (18) 80 (27) 105 (41) 15 (-9) 42 (5. Freezing conditions are a rare occurrence in the desert. the duration of sustained hot weather is much shorter at the plains site. ºF (ºC) Annual average Summer average Extreme high (median) Extreme low (median) Durations. Table 3-2 Comparative Characteristics of Site Meteorology Southwest Desert Ambient Temperatures. but the potential for such conditions exists for nearly one-third of the year in the Northern Plains. Noteworthy among these are Status of generation operation (regulated vs. As a result.Air-Cooled Condenser Specification The characteristics of the temperature profiles at the two sites are given in Table 3-2. 3.5) 65 (18) 100 (38) -28 (-33) Northern Plains Although the highest temperature reached during the year is nearly the same at both sites. For most of the year.3. However. For the next hottest three days.3. and it may not be obvious to the non-specialist which of these conditions is the most demanding. the capacity penalty can be an important element of the annual cost. a detailed analysis will not be provided here. should also be considered. especially during warmer months. Therefore. back pressure. Ambient Temperature In unregulated markets. and ambient temperature essentially sets the ACC design. the purchaser may have more than one set of conditions that must be met. the specification of heat load. In addition to wind effects. However. the increases were lower but still substantial. prevailing wind conditions.7 Multiple Guarantee Points As noted previously.Air-Cooled Condenser Specification their economic expectations.6 Electricity Price vs. an optimization computation that accounts correctly for an expected large increase in power price on hot days will drive the optimum design point toward a low ITD (large ACC). Therefore. a broad indication of the qualitative effect of these factors on ACC optimization will be given. 3. If the ACC limits output at precisely the time of year when electricity prices are at the highest levels.3. the potential revenue loss can be large. Table 3-3 shows behavior of wholesale power prices at a Southern California location during the months of July for the seven years of 1997 through 2003. 3. Examples include: A maximum allowable back pressure on the hottest expected day 3-17 . the price of electricity exhibits high volatility with availability and demand and can strongly depend on location within the power grid. Table 3-3 Electricity Price Variability With Ambient Temperature Price for Palo Verde (Southern California) (for month of July) Hottest Three Days Next Three Days % above average % above average 40 25 45 25 61 35 96 64 43 34 50 29 16 9 Year 1997 1998 1999 2000 2001 2002 2003 Average (excluding 2000 and 2003) 48 48 At sites with long periods of very hot weather. It shows that the price during the hottest three days of the month was an average of nearly 50% above the monthly average and in 2000 was nearly double the average. given the importance of wind effects on the ACC’s performance. 90 3.00 33 65 Case 5 Case 6 Case 7 Case 8 X Case 9 Case 10 X 320.000 152. In this instance.1 41.000 58.000 373.400.6 63.000 353. Four of these conditions were designated as “guarantee points.1 36. the highest value will be the limiting case. is the design point. the “hot day guarantee” point (Case 8) is the limiting case and therefore the design point. then all other points will be met or exceeded.700 531.6 54.400.500 567.90 1 1.6 Of the several “multiple guarantee” points. therefore.000 152.90 0.000 0. a first-cut at ranking the points can be made using equation 2-2. cogeneration plant equipped with an ACC.000 0.1 52. if the quantity [Q/ITD] is calculated for each case. imposing a larger steam flow change on the ACC Table 3-4 lists a set of 10 operating conditions considered important to one combined-cycle.80 1. This may be particularly important for – – Combined-cycle plants where duct burning may be employed during hot periods.000.Air-Cooled Condenser Specification A minimum allowable plant efficiency at the annual average operating conditions A lower.600. However.91 1.000 622.92 0.500. For a given ACC.000 474. which shifts a higher load onto the steam cycle Cogeneration plants at which the host site may be unable or unwilling to accept steam under certain conditions. Therefore. Table 3-5 displays the results for such a ranking for the 10 cases in Table 3-4. efficiency under average summer conditions A required performance level for several different steam flows and at different ambient temperatures.7 3.” If the performance at this “limiting” point is achieved.000 305. it is always the case that one of the points is the most demanding or the “limiting guarantee point. 3-18 . the heat load divided by the ITD is reasonably constant over a wide range of operating points.000 486.93 1 65 65 65 85 96. In the actual design process.96 0.000 608.000 233.8 54.100.0 36.2 65 510.” Table 3-4 Multiple Operating and “Guarantee” Points Item Guarantee Point Ambient Temperature Steam Flow Steam Quality Backpressure Heat Duty ITD Units Case 1 X Case 2 Case 3 Case 4 X Specified Points F lb/hr inHga Btu/hr F 85 605. each of the points must be carefully analyzed to determine which is the limiting case.92 0.1 Calculated Values 550.000 557.2 2. but still acceptable.90 0.200.91 0.65 65 241.100. This.000 581.300 0.6 36.000 0.700.000 519.15 1 2.4 74.900. at higher wind velocities.8 Site Wind Conditions It is well known that the influence of wind is to reduce ACC cooling capability. First.465.251. thus opposing the flow of cooling air through the bundles.000 241.497 6. Under these circumstances. the plume rises essentially vertically above the unit and does not interfere or mix with the airflow entering the unit through the open sidewall areas below the fan deck.614.220 4.0 2.840 7. is also well known with wet cooling towers.7 6.767.4 2.549. axialflow fans and have a static pressure rise (at design conditions with uniform. While helping to reduce recirculation. This is the result of both hot air recirculation and degraded fan performance under windy conditions.5 5.0 2.946 8. the heated air can become entrained in the inlet stream of ambient air. Degraded Fan Performance – As noted earlier. the fans on an ACC are large.000 605. H2O (80–125 Pa). the bulk of the ACC cells and their windwall act as a bluff body and produce a low-pressure wake region and associated vorticity that can draw a portion of the plume down below the top of the windwall and the fan deck.Air-Cooled Condenser Specification Table 3-5 Ranking of Operating Points to Establish Limiting Case Case No 8 1 7 10 2 5 4 9 3 6 Guarantee Point * * * * Ambient Temperature F 96 85 85 65 65 65 65 33 65 65 Steam Flow lb/hr 567. resulting in an ACC inlet temperature that is slightly higher than the surrounding ambient air. Recirculation – An operating ACC discharges a large volume of air heated typically to about 30 ºF (17 ºC) above the inlet air temperature. the A-frame cells are typically protected with a windwall.500 608.5 4. parallel axial flow at the inlet) of perhaps 0.478.680 9. the plume of heated air is bent over in the downwind direction.000 373.226.000 531.787.600 320. this wind screen also prevents crosswinds from impinging on the outer surfaces of the cell walls.3–0. Under quiescent ambient conditions.4 2. As previously explained.690. referred to as recirculation.000 622.300 152. two additional impacts occur. bringing it closer to the inlet areas below the fan deck.5 in.3 3.3.0 ACC Const (Q/ITD) Btu/hr-F 9. In the presence of a significant crosswind 3-19 .930 8.087 8.939 3. low-speed.368.000 510.700 Backpressure in Hga 7. Some studies recommend the use of a “recirculation allowance” (a common practice with wet towers) in which the design inlet temperature is assumed to be 2–3 ºF (1–1. Second. (See Figure 2-6).395 9.3 2.5 ºC) higher that the design ambient temperature. which is erected completely around the unit and usually extends from the fan deck to the top of the Aframes. However. This phenomenon.392 8. Figure 3-12 Effect of Wind on Air-Cooled Condenser Performance at Wyodak It is very difficult to accurately predict the effect of wind on performance without detailed siteand design-specific computational fluid dynamics (CFD) or physical modeling. From the viewpoint of the purchaser. It is generally believed that the effect on fan performance is the more important of the two effects. which primarily affects downwind cells. for a wind direction where a large building is directly upwind of the ACC. several points are noteworthy. there can be a large and sudden reduction in the airflow to the affected cell.5 m/s). Figure 3-12 shows data at an operating coal-fired steam plant. In contrast to recirculation. direction. 3-20 . However.4–8. this can vary with details of the site topography. the presence of nearby obstructions. The effect of wind on ACC performance can be significant. indicating an 8–14% reduction in turbine output for wind speeds ranging from 7. If this occurs.Air-Cooled Condenser Specification shearing across the fan inlet. turbulence. and gustiness at the ACC. and any other factors influencing wind speed. ACC orientation relative to the prevailing winds. the fan performance degradation is most apparent in the upwind cells. turning losses at the inlet can be a significant factor on performance.5–20 mph (3. the distortion of the velocity profile (or velocity triangle) on the leading edge of the fan blades can result in a stall condition over all or a portion of the fan. In addition. Indeed. the situation is exacerbated. increased inlet air temperature) as well as projections of reduced airflow and ACC performance. even under still air conditions.9 Site Noise Limitations Noise limitations can be an important consideration at some sites. From there. Therefore. and even if it were available. to forego high-wind performance guarantees in order to reduce capital costs. There is little data available in the open literature to assist purchasers in estimating the probable effect of wind.3. the plant is likely to be operating at high back pressures close to the alarm/trip points. with significant effect on ACC performance and cost. In all cases. as a result of anticipated wind effects. The safest approach under the current state-of-the art is to request a model of on-site test results for the design as part of the bid package. In 3-21 . high-temperature conditions of interest may occur only rarely and intermittently.. typically less than 3–5 m/s. therefore. Even if they were willing to do so.e. a purchaser desires to inject additional performance margin in the specification. 3. a more informed decision can be made relative to the resultant balance of increased capital (and operating) costs against power sales revenues and associated margins. During hot periods. the cost would likely be very high. If.Air-Cooled Condenser Specification If meteorological conditions at the site are such that high winds coincide with high summertime temperatures. Such high winds may require a voluntary shedding of load to avoid the plant trip condition at just the time when demand and the power prices are at their highest points of the year. suppliers may be reluctant to bid and guarantee such a design. so that the purchaser understands the consequences of the decision and has the information to evaluate the tradeoffs intelligently. the supplier should be asked to provide some estimates of the expected reduction in performance with increasing wind speed. The solicitation of “additional heat transfer surface” or “lower tube cleanliness” may result in different proposals and different actual performance levels from competing ACC suppliers. shutdown based on exceedance of a preset pressure limit). All existing test codes as well as those currently under development stipulate that ACC testing will be conducted at low wind speeds. It should also be recognized that it could be difficult to conduct a rigorous acceptance test of a high-wind design since the high-wind. If the choice is made.e. Designing an ACC to be immune to wind effects would be difficult. This reduction prediction may include both recirculation (i. site-specific differences may dominate performance and render the data inapplicable to the purchaser’s site.. a sudden or sustained period of high wind may result in a turbine “trip” (i. a successful acceptance test does not ensure that the performance will not degrade significantly under higher wind conditions. Occupational Safety & Health Administration (OSHA) regulations [f] limit the noise at ground level for the ACC to about 85 adjusted decibels (dBa). it may best be done in terms of artificially higher heat loads or a recirculation allowance on inlet temperature. At that time. Air-Cooled Condenser Specification the absence of particular far-field limitations, the usual design with standard fans produces a noise level at 400 ft (140 m) from an ACC boundary of about 65 dBa. However, some sites have special requirements. Plants located near residential neighborhoods; facilities such as schools, hospitals, and houses of worship; critical habitat areas; or national parks and other sensitive recreational areas may require significant noise reductions at specified distances. Figure 3-13 shows a rough estimate of the effect of noise reduction on ACC capital cost [g]. Progressively greater levels of noise reduction are achieved in various ways. For modest reductions of 5 dB or less, fans with more blades can be run at lower speeds requiring about the same power. Reductions of up to about 10 dB can be achieved with reduced airflow, compensated for by increased heat transfer surface, but not requiring any additional cells. For reductions above 10 dB, a combination of more surface per cell, additional cells, and low noise fans will be required. When the limit of what can be achieved with fan selection and ACC design modification is reached, somewhere in the range of 15–17 dBa, external noise barriers will be required. 1.3 1.25 ACC Price Multiplier 1.2 1.15 1.1 1.05 1 0 5 10 Noise Reduction, dB 15 20 25 Figure 3-13 Air-Cooled Condenser Cost Multiplier vs. Noise Reduction Low noise fans come in several categories, characterized in some descriptions as “standard,” “low noise,” “very low noise,” and “super low noise.” Tables 3-6 and 3-7 show the comparative performance and cost information for these four categories. 3-22 Air-Cooled Condenser Specification The correspondence between an approximate 3.5-fold increase in fan cost for a 16-dB noise reduction and an ACC cost multiplier of ~x 1.17 for a similar noise reduction implies a fan cost of about 7% of the ACC cost for standard fans, which appears reasonable. Table 3-6 Low Noise Fan Performance [g] ACC Fans---34 ft. diameter 1,468,200 ACFM; 0.375 " WG Low Noise 6 83.9 8,957 139.9 99.1 Very Low Noise 6 65.4 6,988 158.2 92.6 Super Low Noise 6 65.4 6,988 161.4 89.9 Blades RPM Tip Speed HP Sound Power Sound Pressure (@ 400 ft) Standard 4 116.9 12,481 137.4 104.8 56.2 48.6 42.8 40.1 Table 3-7 Low Noise Fan Cost Comparisons [g] ACC Fans---Relative Cost Factors (in %) Standard 5 100 100 100 100 Low Noise 5 115 140 100 100 Very Low Noise 5 145 225 125 125 Super Low Noise 5 325 450 125 300 Blades Weight Fan Costs Gearbox Costs Transport 3.3.10 Use of Limited Water Supply The preceding discussions make clear that “hot day” performance of ACCs and the associated heat rate and capacity penalties have a significant influence on the optimum design point. High penalty costs drive the optimization toward larger and more costly ACCs. An alternative approach to the design of large ACCs can be considered if a limited amount of water is available at the site for use as supplementary wet cooling during those limited periods of hot weather. Two systems are commonly considered. 3-23 Air-Cooled Condenser Specification 3.3.11 Hybrid Systems Hybrid systems, in this context, refer to those with a conventional, shell-and-tube surface condenser and a wet cooling tower installed in parallel with an ACC. The system is shown schematically in Figure 3-14. Figure 3-14 Hybrid (Dry/Wet) Cooling System During peak load hot periods, cooling water from the wet tower is circulated through the surface condenser, which then draws steam away from the ACC. The system is self-balancing. The steam flow will divide to establish an operating point in which the condensing pressures in the ACC and surface condenser are the same. The heat load on the ACC is thus reduced and the turbine back pressure is lower than it would have been for an ACC operating alone. The system permits the use of a smaller and therefore less expensive ACC than would have been required in an all-dry design. On the other hand, the system incurs the costs of a small wetcooling system, which, though small in size compared to what would be required for an all-wet system, requires the full complement of equipment. This includes the shell-and-tube condenser, the cooling tower, circulating water pumps and piping, intake and discharge lines, and structures and associated water treatment capability. In-depth discussion and analysis of the tradeoffs are beyond the scope of this document. A more detailed discussion is available in a recent EPRI report [c]. General guidelines have been presented [d] that suggest for annual water availability, ranging from 15–85% of the water 3-24 which will assist in formulating reliable design guidelines. typically with natural draft cooling towers. ACC performance is improved to a level consistent with an artificially lowered ambient temperature. Recent information on spray enhancement and the deluge system was reported at the CEC/EPRI Advanced Cooling Strategies/Technologies Conference. This approach has been tested at several installations on an ad hoc basis. and is available from EPRI. 3-25 . 2005. performance. is shown schematically in Figure 3-15. if not carefully designed and operated. the capital cost of the hybrid system is less than that for an optimized all-dry ACC system. which has resulted in a satisfactory rating. To date. no new ACC designs have incorporated spray enhancement into the original design. Detailed discussion of spray enhancement or deluge cooling options is beyond the scope of this report.5–5 ºC) are readily achieved.12 Spray Enhancement Another approach. 3. which use indirect dry cooling. The water evaporates and cools the air before it enters the finned-tube heat exchanger bundles. It involves the spraying of water into the inlet air stream of an ACC. Cooling effects of 5–10 ºF (2. runs some risk of scaling or corrosion damage to the finned-tube bundles from unevaporated spray droplets impacting the surfaces. The performance enhancement is achieved with a relatively low-cost retrofit.Air-Cooled Condenser Specification required for all-wet cooling. The approach. Some European installations have included deluge cooling in the Heller systems. and operating procedure information for spray enhancement.3. where sprays were retrofitted to an existing ACC that had lower-than-desired performance on hot days. Current research and development work will provide well-documented cost. which is normally more than sufficient to avoid the need to reduce load. called spray enhancement. June 1-2. Air-Cooled Condenser Specification Steam header Air out Condensate Header Heat exchange finned tubes Fan Fan Shroud Cooled air Spray frame & nozzles Air in Figure 3-15 Schematic of Spray Enhancement Arrangement 3-26 Air-Cooled Condenser Specification 3.4 References a) Balogh and Z. Takacs. Developing Indirect Dry Cooling Systems for Modern Power Plants. 98. b) J.M. Burns and W.C. Micheletti. Comparison of Wet and Dry Cooling Systems for Combined Cycle Power Plants. Burns Engineering Services, Inc. and Wayne C. Micheletti, Inc.: November 4, 2000. Final Report (Version 2.1). c) Comparison of Alternate Cooling Technologies for U.S. Power Plants: Economic, Environmental, and Other Tradeoffs. Electric Power Research Institute, Palo Alto, CA: August 2004. Final Report 1005358. d) J.S. Maulbetsch, M. DiFilippo, K.D. Zammit, M. Layton, and J. O'Hagan. “Spray Cooling – An Approach to Performance Enhancement of Air-Cooled Condensers,” presented at EPRI’s Cooling Tower Technology Conference. Electric Power Research Institute, Palo Alto, CA: August 2003. Proceedings Report 1004119. e) D.G. Kröger. Air-Cooled Heat Exchangers and Cooling Towers. Thermal Flow Performance Evaluation and Design, Department of Mechanical Engineering, University of Stellenbosch, Private Bag X1, Matieland, 7602, South Africa, 1998. f) OSHA. Occupational Noise Exposure/1910.95. g) D. Sanderlin and F. Ortega. Dry Cooling History in North American Power Plants. Dry Cooling for Power Plants – Is This the Future? Air and Waste Management Association (AWMA): 2002. 3-27 To facilitate cleaning.4 AIR-COOLED CONDENSER COMPONENT SPECIFICATION 4. 4.06 in. from the main steam header to the condensate collection system. A performance testing procedure was developed and is included in Chapter 6 of this specification.1 Finned-Tube Bundle and System In general. This spacing limitation may vary as a function of the nature of the ambient and airborne contaminants that might be entrained with the inlet air. The total finned-tube system needs to accommodate expansion and contraction with changes in thermal loads. (1. The fabrication and testing of equipment will be in accordance with recognized codes and standards.2. assuming that the ACC system is not operated in a corrosive environment or one where extremes in temperatures and operating conditions preclude such expectations.1 General Requirements The ACC and associated equipment shall be designed to meet the performance requirements developed as a result of the process outlined in Chapter 3. A design life of 25 years or more is likely achievable under typical operating conditions.5 mm) prior to galvanizing. The finned tubes are normally arranged in a sloping A-frame type installation. 4-1 . shown in Figure 4-1.2 Specific Components 4. As to strength and arrangement of fins and connections. Materials of construction may be galvanized carbon steel with a minimum thickness of 0. Aluminum-clad tubes are also acceptable with aluminum finned heat exchange surfaces brazed to the tubes. the fins shall be capable of withstanding spray cleaning pressures of up to 1200 psi at a distance of one foot or greater. the number of fins should not exceed more than 10–15 fins per inch. finned-tube bundle systems. consist of the heat exchanger finned tubes and associated headers. The finned-tube systems may consist of multiple rows of tubes but are more commonly single-row tube systems characteristic of today’s low-capital-cost scope of supply. Connections are of welded type. 2. it shall be designed for local snow and ice loadings absent any type of heat tracing. inspection ports. rupture discs. All connections for the structural steel members shall be designed and detailed for bearing-type connections. structural steel. 4-2 .2 Structure Structural steel and associated steel work shall be in accordance with the latest edition of the American Institute of Steel Construction Inc. The ducting typically includes expansion joints. Blanking plates for each ACC duct permit leak testing of the entire ACC. If the ACC is expected to operate in a snow and ice environment. necessary vent and drain connections. etc. (AISC) ASD Manual of Steel Construction [a].2. Associated welding shall conform to the American Welding Society Standard Code for Welding in Building Construction [b].Air-Cooled Condenser Component Specification Figure 4-1 Example of Steam Ducting and Finned-Tube Bundles 4. The structure shall be designed for the required seismic rating of the site. Figure 4-2 below depicts steam ducting on a combined-cycle plant in Nevada.3 Steam Ducting The steam ducting begins at the turbine exhaust flange and leads to the ACC. 4. 4-3 . depending upon site conditions. may require a heating/freeze protection system. again. An example of this is provided in Figure 4-3. from a combined-cycle plant in the southwestern United States.Air-Cooled Condenser Component Specification Figure 4-2 Example Steam Ducting and “Pant Leg” Distribution The steam ducting also includes a sufficiently sized tank for condensate collection and. The air removal systems shall be configured and supplied as stand-alone units. it shall be equipped with isolation valves for the steam inlet. including all piping. etc. Piping. gauges.4 Air Removal System Air removal systems are normally of the steam-jet air ejector type. and Access 4. Common accessories required include: Volumetric flow and temperature indicators Steam strainers Bypass line with valves affording determination of flow rates 4-4 .2. Two 100% air removal systems are typically required. and discharge of the ejectors. Those having surface-type condensers are typically designed in accordance with the Heat Exchange Institute’s Standards for Steam Jet Vacuum Systems [c]. drains. The air removal system shall be designed for accommodating both noncondensable and air inleakage that might occur in the operation of the system over a range of heat loads. pressure relief valves.Air-Cooled Condenser Component Specification Figure 4-3 Example Condensate Tank. Further. condensable inlet. helical. and seal disks to provide optimum efficiencies over the expected range of ambient temperatures and fan speed modulation. comprised of blades.5. including two-speeds forward. Gearbox internal lubrication will be forced type.5. Gearboxes shall be equipped with a means of simple access for filling and servicing of lubricating oil.2. or spiral bevel type designed for continuous service. hub. An American Gear Manufacturer’s Association rating of 2. 4. plus a recirculation allowance.2. Gear Speed Reducers [d]. They shall also be equipped with a vent line for ease of filling. and the like from being carried into the rotating fan assemblies. They shall also be designed to operate in both directions and accept design thrust values. without adverse impacts to static balancing. 4-5 . Fan blade systems and operations will be designed so that there are no natural frequencies set up between the intended operations of the fans and the ACC structure itself.Air-Cooled Condenser Component Specification 4. Fans shall be capable of operating at 110% of their design operating speeds. The inlets to each fan shall be protected with a screen capable of preventing objects such as local birds. Fan systems shall be equipped with inlet bell rings to improve the entering airflow characteristics upstream of the fan.5 Mechanical Equipment 4. Fan systems shall further be designed so as not to exceed 2 mils (50 microns) maximum vibration amplitude under any operating condition for the bearings and bearing pedestals. They shall be designed to meet the Cooling Technology Institute’s Standard 111.1 Fans This equipment includes the complete fan assemblies. shall result in fan tip clearances not to exceed the performance and installation guidelines set forth by the fan manufacturer. The supplier shall verify that the fans and the ACC will perform in minimum and maximum density inlet air environments. complete with hubs. Fan blades. Obviously. The inlet fan rings shall be fabricated from fiberglass or polypropylene.2. including those associated with warm weather conditions. and to operate for 100.000 hours before major repair or replacement. Replacement fan blades shall be manufactured in such a fashion as to be interchangeable. shall be assembled and statically balanced before shipment. including inlet bell. The fan system installation. (Smaller fan diameters may warrant consideration of aluminum or other similar materials of construction). entrained paper. Fan drives may be variable speed or multi-speed. a record system of fan blade and hub assemblies must be maintained and communicated with the shipment of separate fan blades and hubs. Fan blades shall be fiberglass-reinforced epoxy and fan hubs shall be galvanized. each gearbox shall have a magnetic drain plug system for pick up and retention of metal particles in the gearbox oil. In addition.0 shall apply to the design and operating criteria. Fan blade and hub assemblies shall be designed to facilitate adjustment of blade pitch following installation and operation in the ACC. plastic bags.2 Gearboxes Gearboxes can be of the hypoid. The “flex-coupling” will also be designed to fail under manufacturer-recommended thrust levels. and Fan Hub Assembly 4-6 . shows a motor and offset gearbox on an ACC in the southwestern United States.Air-Cooled Condenser Component Specification The gearbox shaft shall be equipped with a flexible coupling that will accommodate typical angular misalignments in the gearbox /fan shaft drive shaft system. Figure 4-4 Example Motor. Gear. Figure 4-4 below. Clearance above walkways shall be a minimum of 7 ft (2.3 ft (1 m) wide and shall have no obstructions. etc.2. inspect. catwalks. shall be hot-dip galvanized steel materials. Dimensioning – All walkways and stairways shall be a minimum of 3. Recommended Access Type and Locations: – – – – – – – – Single stairway on one end of the ACC Two caged ladders on opposing end of the ACC from stairway access Grating platforms connecting the ACC cells and accessing the mechanical equipment Walkway around the ACC perimeter at the tube-bundle condensate collection level Access to steam duct rupture disc and any valving that may require manual operation Access to instrumentation and sensor locations. to safely access. gratings.6 ft (0. All catwalks shall be a minimum of 1.6 Access General – Access refers to all stairways. stairways. Appurtenances – All stairways. and platforms will be equipped with kickplates and handrails as well as intermediate piping and baseplates. maintain. etc.2 m). ladders. including all permanent and temporary test wells or ports Hinged doorways with automatic closure and full seals for access to each end of a street and between each cell within a street Optional rolling staircase for access to upper surfaces of tube bundles – may also include cleaning spray nozzles Galvanizing – All access platforms. and operate the ACC. Figure 4-5 below shows a walkway and lighting on a typical ACC. platforms.5 m) wide.Air-Cooled Condenser Component Specification 4. ladders. 4-7 . manways. fan motor. with removable panels at intermediate and end walls to convey equipment through and out of the ACC. Monorail Trolley and Hoist – The monorail trolley and hoist. or gearbox. convey across the ACC. Such equipment will be permanently mounted. and replace/maintain mechanical equipment fall into the general category of hoists. davits. Davits. Monorail Beams – This includes a full run of monorail along the length of any entire “street. Monorails General – All systems required to remove.2. lower to grade. The beams will have sufficient overhang on one end of the ACC to raise or lower removed or replacement assemblies to and from grade to the fan elevation level. 4-8 .. as shown in Figure 4-6. along each condensing run.7 Hoists.” i. include a movable roller-type assembly and electric hoist with movable operating panel and cable to run the length of a condensate run or street.Air-Cooled Condenser Component Specification Figure 4-5 External Walkway and Caged Ladder on a Typical Air-Cooled Condenser 4. fan hub.e. It shall be designed to suspend and convey the weight of a fan blade bundle. and monorails. Air-Cooled Condenser Component Specification Figure 4-6 Example Monorail System and Truss Work for Conveying Motor and Gear Assemblies for Service and Repair 4-9 . especially those having to do with wind abatement. wind screens may be deployed under the ACC in a variety of arrangements. In cases where debris entrainment is an issue. In some cases. namely. these are not typically required for ACCs and would obviously result in additional capital cost. the screens may be deployed in the area upwind of the ACC. etc. uses low noise. The primary noise abatement vehicle is the fan and fan design. low velocity fan designs. the screens serve multiple purposes. and are under consideration by research groups such as EPRI and the CEC [e]. however. An example of this type of situation is shown in Figure 4-7. Noise Abatement – Sound-pressure levels can be reduced via sound walls and similar external sound absorption systems. Figure 4-7 Upwind Screen for Reduction of Wind-Entrained Debris and Wind Effects (Chinese Camp Cogen) When winds alone are of concern. As these are considered experimental at this time.8 Abatement Systems Abatement systems may include noise abatement devices. Most plant sites in the United States are sufficiently distant from residential or population areas to preclude the use of low noise fans or noise abatement devices.2. The Crockett Cogeneration Plant in Crockett. These systems tend to be site-specific. 4-10 .Air-Cooled Condenser Component Specification 4. no additional guidance is provided in this document. California. wind screens. Wind Screens – A variety of wind screen designs have been employed at sites in the United States. The degree to which either noise absorption devices or low noise fans are employed depends upon the sound-pressure levels required by the site. reduction of entrained debris and reduction of wind effects. Some general guidelines for abatement systems are provided below. on the corner of the ACC facing the prevailing wind 4-11 . and devices to properly monitor and control the ACC. minimize subcooling. Additional guidance on potential instrumentation and sensor locations is provided below. etc. alarm. based on input to the American Society of Mechanical Engineers Performance Test Code 30 [f] Committee (ASME PTC 30 Committee) in progress at the time of this writing. pressure ports. if wind speed and direction information is for monitoring and research only. level sensors. Condensate return temperature sensors – remote Condensate level sensors – remote Vacuum pump skid hogging flow rate Wind speed and direction sensor – remote. Tubing runs shall be sloped downward to prevent pressure head from the condensate. symmetrically disposed. depending on the apportionment of work between the electrical and instrumentation contractor and the ACC supplier. without impacting ACC or plant operation. flow. in strategic testing and monitoring locations. including at the fan level and upwind of the ACC. It also includes thermowells. If these data are for performance testing.Air-Cooled Condenser Component Specification 4. near the connection to the turbine exhaust flange Local Wind Speed and Direction – Anemometer and wind vane at least 3 m above the wind walls. – – – – All sensor systems shall be designed and installed such that they can be safely removed while the ACC is in operation. Turbine Exhaust Pressure – At least four pressure taps with basket tips. in the steam duct. placement guidance is provided in Chapter 6. pressure. A lightning protection system may be included. and cutout switches – remote Gearbox lube oil pressure and level – local Steam duct temperature sensors – remote Steam duct pressure sensors – remote.9 Instrumentation and Controls General – Instrumentation and controls refer to all temperature. should be considered.2. multiple locations. Specific Control and Monitoring Features (and their locations): – – – – Fan vibration. and eliminate risks of the system freezing during low loads and low ambient temperatures. Location of such sensors should be done with objectives clearly in mind. Optimization of Operation – Instrumentation and controls may be provided to modulate operation of the ACC fans in order to optimize operation of the turbine generator. Pressure sensors shall be designed to prevent impacts of velocity pressure. For instance. in the steam duct near the connection to the turbine exhaust flange Turbine Exhaust Temperature – A minimum of one thermowell. Figures 4-8 and 4-9 below show a popular “library ladder” type cleaning system.e.2. including integration into the plan for other high-elevation structures such as combustion stacks. This also refers to startup and maintenance lubricants for the gearboxes.10 Spare Parts Spare parts include all backup parts and systems required to reliably maintain the ACC and its control systems.2.12 Cleaning System The cleaning system includes a vendor-recommended cleaning system designed for efficient medium-pressure cleaning of finned tubes. The movable ladder affords coverage of the total exit plane of the finned-tube bundles. and appropriate grounding. 4.11 Lightning Protection System This system includes lighting rods.Air-Cooled Condenser Component Specification Condensate Flow Rate – The flow element should be installed at a point at least 10 diameters of straight pipe in the condensate line downstream of the condensate pump. It is important to note that flushing of the tubes is recommended countercurrent from the direction of airflow in order to achieve maximum cleaning of collected contaminants. which can be used to periodically clean the finned tubes with a high-pressure (i. 500–1500 psig) supply system. 4-12 .. It may best be provided by the electrical or grounding contractor for the plant in total. with a removable flanged spool that can be used to install an in-line flow transducer Condensate Temperature – At least two thermowells in the condensate tank Isolation – Isolation valves on all drain inlets to the condensate tank Fan Power Measurements – Accessible wattmeter taps where the fan power cables exit the motor control center (MCC) or variable frequency drive (VFD) cabinets 4. Recommended spare parts include: One spare fan and hub assembly One spare gearbox One each pressure and temperature transducer used for routine monitoring and control 4. conductive cable.2. Air-Cooled Condenser Component Specification Figure 4-8 Movable Cleaning Ladder System Above Tube Bundles 4-13 . etc. GEA offers a system that can track ACC performance at their headquarters and alert the plant if something is wrong (heavy fouling.2. excessive air inleakage. 4.2. One example is a system for continuous performance monitoring. 4.2.Air-Cooled Condenser Component Specification Figure 4-9 Close Up of Spray Cleaner Valving on Movable Cleaning System 4.14 Shipping Shipping refers to all packing. The few units that don’t have such controls rely on the operators to pay attention and know when to put fans on full or half speed or 4-14 . Automatic fan controls are another important consideration. loading. and should be considered.15 Additional Options There are options that are available.).13 Factory Testing Factory testing includes all shop and key subcontractor tests required to demonstrate that infactory functionality and quality control requirements are met. protection. and transportation required to properly transport ACC components from the point(s) of manufacture to the job site or nearby staging area. . AWS D 1. 2004. b) American Welding Society. Sacramento. 4-15 . Variable speed fans are also getting more attention and some installations considering retrofitting them. Panel Discussion and Presentation at the CEC/EPRI Advanced Cooling Strategies/Technologies Conference. Texas: CTI. Florida: American Welding Society. Chicago. Miami. New York. 4. June 1-2. e) J. California. 2005. Illinois: Heat Exchange Institute. 170-M021-00. ASD Manual of Steel Construction. 2000. Volumes 1-2. d) Cooling Technology Institute.S. Gear Speed Reducers – STD-111. c) Heat Exchange Institute.3 References a) American Institute of Steel Construction Inc. PTC 30 – 1991 Air Cooled Heat Exchangers. 5th Edition. 2003.Air-Cooled Condenser Component Specification off. Chicago. Standard Code for Welding in Building Construction. New York: ASME. Maulbetsch. Standards for Steam Jet Vacuum Systems. 9th Edition. Houston. Revised May 1998. f) American Society of Mechanical Engineers.1/D 1M. Illinois: AISC Inc. 1991. . e. may well result in derating of the power generation unit or a steam turbine trip.4 Verification of Supplier Performance Requirements for the Air-Cooled Condenser This section focuses on the single row condenser (SRC) design as it is the most widely offered in response to current ACC bid solicitations. 5.” will typically be in the range of 2.1. automatic shutdown) for the unit. but may be lower depending on operating conditions of the system. especially in the event of wind-induced performance deficiencies. Number of Cells – The number of cells (also referred to as modules) is clearly an important part of the supplier data. Accordingly.5–7. it would suggest superheated steam still exists at the turbine exhaust.1 General Requirements Overview 5.3ºC). this high level may be set as a “trip point” (i. It is typical to have some moisture in the exhaust steam. commonly referred to as “back pressure.2 Steam Quality Steam quality is the weight fraction of steam or percentage of steam at the turbine exhaust.1.1. high ITDs.3 Steam Turbine Exhaust Pressure Steam turbine exhaust pressure. 5. Pressures above this level will typically exceed steam turbine manufacturers’ warranties. 5.5 AIR-COOLED CONDENSER BID EVALUATION General verification of ACC performance can be conducted by solicitation and evaluation of some of the following information. Obviously. the number of cells dictates the amount of mechanical equipment 5-1 . notwithstanding the obvious benefits to turbine efficiency. On the other hand. 5. HgA. If steam quality were to exceed 100%.5 in.1. Note that ITDs approaching the low end of this range will result in equipment sizing that may not be economical for a specific plant. Usual values of steam quality are 90–95%.1 Initial Temperature Difference (ITD) The ITD will typically be in the range of 25–60ºF (14–33.. a bid specification may solicit the following information: Overall heat transfer coefficient. Length of Primary Modules – The length of the primary modules is typically on the order of 33–40 ft (10–13 m) for an SRC type system. m`air 5-2 . It is typically the case that a margin of 5–10% is provided.5 Additional Vendor-Supplied Data Beyond the guidance provided in Chapter 3. (based on air-side surface area) Total air-side surface area. As a result. Motor Characteristics – Fan motor power must be equal to that required by the fan shaft power divided by the motor and gearbox efficiencies. Number of Primary Modules – The number of primary modules is typically about 80% of the total number of modules. fans. while the secondary modules are responsible for residual heat transfer and noncondensables collection and evacuation. Primary Module Dimensions – (Width) – Obviously. an ACC cell may use 33-ft (~10-m) diameter fans.e. depending on the fan supplier and the performance requirements.5 m).5 m) in width. A Total mass flow rate of air at each design condition. U.1. Length of the Secondary Modules – These modules are typically shorter than the primaries by about 3–5 ft (~1–1. many current large-scale SRC designs use components whose dimensions are optimized for shipping and erection. The primary modules are responsible for the majority of heat transfer and condensing processes. The number of blades per fan will minimally be 5 but may be as many as 8–10. individual tube bundle sections of approximately 36 ft (~11 m) in length and 8 ft (~2.. and 5 bundles per cell per side. motors.Air-Cooled Condenser Bid Evaluation (i. the total number of cells often dictates a number of ACC features. The total number of cells or modules is the sum of the primary and secondary modules. Number of Secondary Modules – The number of secondary modules is typically about 20% of the total number of modules and there is typically one module per row (or street). for a plan area of 36 ft by 40 ft (~11 m by 12 m) per cell. Fan Characteristics – Fan diameters for ACCs used in most recent power plant applications are typically 30–37 ft (10–12 m). in addition to service factor margins. For example. gearboxes) required by the ACC. Furthermore. 5. including the mechanical equipment as well as the total amount of heat transfer surface. the width of the primary modules must be greater than the fan diameter and typically run on the order of 15–25% larger than the fan diameter. An example of this process is provided in Appendix B.20%) for a standard fan and system design. Power Requirements – Total fan power can be calculated using the aforementioned information and assuming nominal gearbox efficiencies of approximately 97% and motor efficiencies of approximately 92–94%. For an SRC. in) Face Velocity of the Air – The face velocity of the air. Engineers who have performed velocity measurements at the ACC exit plane know that. Outlet Air Temperature – The outlet air temperature is obviously less than the steam temperature and can be calculated from the following equation: Qrequired = m` x Cp air x (Tair. Fan Shaft Power or Brake Horsepower – Depending on the fan static efficiency. the air density. which in essence is the force required to overcome the system resistance (with the required design airflow rate)..6 Important Items for Verification Thermal Duty – It is important to verify that the thermal duty solicited (i.= m`steam x (h steam. Typical values will run from about 3 ft/sec (~1 m/s) to as much as 8–10 ft/sec (~3 m/s). can be calculated from the mass of airflow rate. it is possible to calculate whether the fan system will deliver the appropriate amount of air. will typically run from 0.e. Fan Static Pressure – Fan static pressures will vary depending on whether the fan is a low noise or more standard design.3–0. while the average velocity may be in those limits. Qrequired . with the average being about midway between those limits. the ratio of the air-side surface area and the total “face” area is approximately 120. out – Tair. and the total face area of the ACC. Fan static pressure.1. (turbine exhaust) – h (condensate)) Q rejected = U x A x LMTD Heat Transfer Area – This is calculated knowing the total heat transfer area of ACC tubes.Air-Cooled Condenser Bid Evaluation Fan static pressure (pstatic) or total system pressure drop Log Mean Temperature Difference (LMTD) Steam duct pressure drop Heat exchanger bundle pressure drop (steam side) 5. while not typically provided by the supplier. the amount of heat to be rejected) is matched or exceeded by the supplier’s offering. variations of a factor of five can occur at the outlet. 5-3 .5 inches of water (~100 Pa +/. 000 3.2 Pricing This section is provided to indicate the relative costs of components associated with the SRC design.000 5. Subtotal Overhead.4% 1. etc.Air-Cooled Condenser Bid Evaluation 5.5% 5.0% 1. While providing general insight into the estimated cost and pricing of ACCs at the time of this writing. manufacturing sources. such as may be the case if a vendor or contractor other than the ACC designer/supplier provides steam piping. 5-4 .4% 0. condensate system components.400 36. Destination) Engineering/Project Mgmt.8% 18.800 9. Table 5-1 data may also be used as a guideline for spare-parts inventory development and budgeting.000 600 1. Profit Total 32.0% 5. it should not be used as a backdrop to second guess or negotiate with a prospective ACC supplier relative to the overall pricing of a proposed ACC.S.1% 0.000 $ 491. However.960 $ 600.2% 100. Contingency.5% 0.400 3.3% 1. and methods are constantly under development.5% 0. Table 5-1 Typical ACC Component Cost Breakdown Component % Cost Est.2% 11. newer design approaches.440 66.000 32.0% 16. $ Heat Exchanger Bundles Structural Steel Casing Fan Inlet Bell Ducting Expansion Joints/Bellows Piping Mechanical Equipment Air Removal Pumps Valves and Instrumentation Drain Pumps & Rupture Disc Condensate Tank / “Decorator Dome” Shipping (U.040 $ 108.9% 6.0% 0.000 $ $ $ $ $ $ $ $ $ $ $ $ $ 96.000 Information in Table 5-1 might be used as the basis to evaluate “adds” and “deducts” in the bid process.0% $ 192.000 7. These are especially helpful when multiple suppliers of ACC components are being considered.400 8.000 30.0% 81. Air-Cooled Condenser Bid Evaluation Beyond the component cost breakdown.S. EPRI hopes that one byproduct of this document is the forging of a more open and cooperative relationship between the purchaser and the supplier. it is worth noting in this Table 5-1 example that the “Overhead. General. 5-5 . Profit” line item (also referred to in many companies as “Gross Margin”) of 18.2% reflects the competitive marketplace for capital equipment in the U. as indicated in Section 1. Contingency.0 of this specification. and Administrative Expense line item) runs on the order 12–15% of revenues. Assuming that a supplier’s overhead (or Sales. Again. and profit. research and development. This perspective should be borne in mind when negotiating final contract terms and conditions. there is clearly little remaining for performance and execution contingencies. power industry today. . particularly flow elements. Karl R. there is no current U. anticipated deviations to the governing test code. required preparations. the same procedure may be used for performance testing of an existing unit. test measurements. Both the Cooling Technology Institute (CTI) and ASME are currently working on performance test codes for this major plant component.2 Basis As of this writing.3 Test Plan A test plan is a convenient vehicle for specification of responsible test participants. acceptable test conditions. As an example. instrumentation.1. principal investigator. calculation procedures.1.2 – 1998 Steam Surface Condensers [b] CTI ATC-105 Acceptance Test Code (2000) [c] ASME PTC 23 – 2003 Atmospheric Water Cooling Equipment [d] 6. test instrumentation. measurement locations. test code or procedure for performance and acceptance testing of ACCs. through EPRI subcontracted efforts that began in late 2002. with emphasis on condensers and condenser cooling systems. In the absence of a controlling test code. Wheeler. several resources have been used in the preparation of this guideline.6 PERFORMANCE AND ACCEPTANCE TESTING 6. the measurement of steam flow and the estimation of steam quality will require the use of plant instruments. Wilber. It is vital 6-1 . While the procedure focuses on contractual acceptance testing of a new unit. and data reduction procedure required for determination of the thermal capability of a dry ACC. a division of Environmental Systems Corporation (ESC).1. who has significant power plant testing and analysis experience.1 Scope This section details the measured test parameters. These include: VGB – Acceptance Test Measurements and Operation Monitoring of Air-Cooled Condensers under Vacuum (1997) [a] ASME PTC 12. 6. provided minor edits. ESC’s principal scientist was David E.1 Introduction The material and methodology cited in this chapter was developed solely by Power Generation Technology. adjustments to plant operations. and expected test uncertainty.S. 6. W steam quality heat capacity at constant pressure. 6.4 Definitions and Nomenclature Definitions: Capability – A measure of ACC thermal capacity expressed as a ratio between the design steam flow and the predicted steam flow at the test conditions Condenser Pressure – The condensing steam pressure at the ACC boundary Predicted Steam Flow – The steam flow rate predicted by the ACC manufacturer for a given set of test conditions Nomenclature A C Fc NTU P Q T U & V W X cp h mk s ∆Tlm Φ Γ α ρ = = = = = = = = = = = = = = = = = = = = area. °C (°F) overall heat transfer coefficient. m2 (ft2) condenser capability (%) correction factor from test to guarantee conditions number of heat transfer units pressure. The preparation of a test plan. kg/m3 (lbm/ft3) 6-2 . Watts (Btu/hr) temperature. psia) heat transfer rate.Performance and Acceptance Testing that such instruments be identified prior to the test so that any necessary calibrations can be performed.1. kJ/kg/°C (Btu/lbm/°F) specific enthalpy. approved by manufacturer and the ACC purchaser prior to the test. kJ/kg (Btu/lbm) exponent for the correction of test fan motor power to guarantee conditions specific entropy. kJ/kg/°C (Btu/lbm °F) log mean temperature difference. HgA. °C (°F) condenser effectiveness condenser characteristic parameter film heat transfer coefficient. measurement of condensing pressure requires the installation of basket tips that may be different in number and location than those used by the plant for monitoring purposes. In addition. W/m2/°C (Btu/hr/ft2/°F) density. W/m2/°C (Btu/hr/ft2/°F) volumetric flow rate m3/s (ft3/min) power. is highly recommended. Pa (in. representatives of the owner and ACC manufacturer shall be given adequate notice prior to the test. Water level in the condensate hot well tank shall be at the normal operating level.2. In no case shall any directly involved party be barred from the test site.. dust.2. Steam duct and condensate piping systems shall be essentially clear and free of foreign materials that may impede the normal flow of steam and condensate. The air-side of the ACC fin tube bundles shall be essentially free of foreign material. the ACC shall be in good operating condition. etc. gears. 6. ACC air inlet perimeter area and discharge area shall be essentially clear and free from temporary obstructions that may impede normal airflow. Air in-leakage must be such that the vacuum equipment has 50% excess holding capacity during the test. opportunity. Mechanical equipment. Representatives of the ACC purchaser and manufacturer shall agree prior to commencement of testing that the cleanliness and condition of the equipment is within the tolerances specified 6-3 . motors. pumps. paper. as measured at the motor switchgear. shall be clean and in good working order. such as pollen.1 Test Witnesses For acceptance testing. scale. air ejectors.2 Conditions of Test 6. Fan blade pitch shall be set to a uniform angle that will yield within ±10% of the specified fan driver input power load. and adequate notice to inspect the ACC and prepare the ACC for the test. oil.2 Condition of the Equipment At the time of the test. Fans shall be rotating in the correct direction. The manufacturer shall be given permission. with proper orientation of the leading and trailing edges. animal droppings. including fans. etc.Performance and Acceptance Testing Subscripts a c e l G P T i o s v = = = = = = = = = = = air or atmospheric condensate exhaust or exit liquid guarantee predicted test inlet outlet condensing steam vapor 6. which can function as an independent unit. variations in test conditions shall be within the following limits: The variation in test parameter shall be computed as the slope of a least squares fit of the time plot of parameter readings. a “module” is defined as the smallest ACC subdivision.4 Constancy of Test Conditions For a valid test. 6-4 . One-minute duration velocity shall be less than 7 m/s (15.2. All fans should be at full speed. 6. In any event.2. There shall be no rain during the test period or in the one-hour period preceding the test period. The following variations from design conditions shall not be exceeded: Dry-bulb temperature – ±10°C from design (18°F) but greater than 5°C (41°F) Condensate Mass Flow – ±10% of the design value Fan Motor Input Power – ±10% of the design value after air density correction (equation 6-8) Steam turbine exhaust steam shall be distributed to all modules as recommended by the manufacturer. Prior establishment of cleanliness and condition criteria is recommended.6 mph). bounded externally by fin tube bundles and internally by partition walls. The wind velocity shall be measured and shall not exceed the following: Average wind velocity shall be less than or equal to 5 m/s (11 mph). the test shall be conducted within the following limitations: The test dry-bulb temperature shall be the inlet value. All emergency drain lines that have the potential for delivering superheated steam to the condenser shall be isolated. 6. Steady-state operation of the ACC shall be achieved at least one hour before and maintained during the test.Performance and Acceptance Testing by the manufacturer. Condensate mass flow shall not vary by more than 2% during the tests. Each module generally has a single fan. A closed valve shall be considered adequate isolation. For the purposes of this procedure.3 Operating Conditions The test shall be conducted while operating as close to the operation/guarantee point(s) as possible. 1) 0.005 (0. Table 6-1 Measurement Frequency Minimum Readings Per Hour Per Station 60 60 60 60 60 1 60 1 Parameter Measured Unit Recorded to Nearest 0. HgA) °C (°F) °C (°F) kPa (in.03) 0.05) 0.1 (0.5% ACC Condensate Mass Flow Rate Condensate Hot Well Tank Level Exhaust Steam Pressure Exhaust Steam Temperature (for comparison) Inlet Air Dry-Bulb Temperature Atmospheric Pressure Ambient Wind Velocity Fan Power at Switchgear kg/h (lb/h) m (ft) kPa (in.01) 0.Performance and Acceptance Testing The inlet dry-bulb temperature shall not vary by more than 3°C (6°F).4 Frequency of Readings Readings shall be taken at regular intervals and recorded in the units and to the number of significant digits shown in Table 6-1.2 (0.1% 0. 6. Longer test intervals are acceptable provided the constancy of test conditions is observed. the requirements for the test duration shall be at least one hour. 6.01) 0. The condenser capability shall be the average of the tests conducted where test conditions were within the limits specified in this guideline. Hg) m/s (mph) kW (HP) Even when tested under the guidelines specified. the apparent performance of ACCs may vary with the following environmental conditions: Wind speed Wind direction Atmospheric stability To decrease the possibility of an anomalous test result. at least six tests shall be performed over a two-day period. 6-5 .2) 0.01 (0.3 Duration of the Test After reaching steady-state conditions.05 (0.01 (0. For ACCs with multiple steam inlets. unless the flow in a given inlet is less than 5% of the total steam flow. the mass weighted average absolute pressure of the instrumented inlets shall be used as the condenser pressure on lookup charts. which allow a single pressure device to make measurements on each port sequentially. Scanning valves. Steam inlets with less than 1% of the total steam flow need not be instrumented. are also acceptable. Four measurement points per inlet are required. The pressure measurement points shall be located at positions 90° apart around the steam inlet. one pressure measurement is required. tables.1 Condenser Pressure Condenser pressure shall be measured at the boundary of supply of the condenser manufacturer unless parties to the test agree upon another location. a bad transmitter should not compromise the test. as illustrated in Figures 6-1 and 6-2. 6-6 . For inlets with flows that are less than 5% of the total steam flow. The primary parameters to be measured or calculated are: Condenser pressure Steam quality (content) Condensate flow rate Condensate tank water level Inlet air dry-bulb temperature Barometric pressure Fan motor input power Wind speed It is recommended that the following parameters be acquired for reference purposes: Exhaust steam temperature Condensate temperature Air removal rate Wind direction 6. Pressure ports shall be bored holes in the wall of the steam inlet connected to basket tips or baffle plates. Separate pressure sensors shall be connected to each port. With this approach.5.Performance and Acceptance Testing 6. and performance curves. It is preferable to have at least two instruments. Provisions should be made for purging all pressure connections to keep them free of condensate.5 Test Measurements The objective of the parameter measurements is to accurately and reproducibly measure ACC thermal performance for comparison against the manufacturer guarantee. Steam temperature measurements should be taken in the thermal wells in the vicinity of the pressure measurements. At present.Performance and Acceptance Testing Pressure sensors shall have a calibrated accuracy of 35 Pa (0. Some suggested methods include the following: 6-7 . Figure 6-1 Schematic of Basket Tip Figure 6-2 Schematic of Guide (Baffle) Plate 6.2 Steam Quality (Steam Content) Since the steam at the condenser inlet will be in the wet steam range. thus the parties to the test must agree on a method for calculating this value.5.005 psia) or less. there is no acceptable method for measuring the quality directly. measurement of the temperature and pressure is insufficient to determine its enthalpy. The pressure transmitter reading the differential pressure shall be calibrated prior to the test to an accuracy of not more than 0. flow nozzles. 6-8 . the values of the steam flows should be verified by performing a mass balance around the condenser. Expansion Line – The expansion for the low-pressure turbine is calculated from the unit heat balances or data from a previous steam turbine test. The quality of the turbine exhaust (condenser inlet) steam is calculated based on the calculated expansion line and measurement of the inlet temperature and pressure to the low-pressure turbine. Such a cycle model should be verified using the steam turbine manufacturer’s thermal kit. If this method is used.11. and flow rate of all steam flows into the steam turbine are measured.3 Condensate Flow The condensate flow shall be measured downstream of the condensate pumps. venturis). it is possible to construct a cycle model for the steam turbine. If the high and low readings differ by more than 2%. the ultrasonic flow meter shall be calibrated in a pipe corresponding to the diameter and wall thickness of the pipe on which it will be installed. A time-of-flight ultrasonic flow meter may be used by agreement between parties to the test. Design values may be used for flow streams representing less than 3% of the design steam flow. The installation of the flow element shall conform to the specifications of ASME PTC 19. These readings shall be averaged to obtain the condensate flow. The installation location shall have at least 16 pipe diameters of undisturbed length upstream of the meter and 4 pipe diameters of undisturbed length downstream of the meter.5. If used. The calibration records and construction details of the flow element shall be made available to all parties to the test. with consideration of any liquid flow streams upstream of the measurement point and the change in level of the tank during test.5 – 2004 Flow Measurement [e]. the cause shall be investigated. A cycle model can then be used to construct correction curves for steam quality based on measured cycle variables.25% of the expected differential at the design flow. The calibration range shall cover the Reynolds number expected for the pipe at the design flow. 6. Cycle Model – With sufficient information from the steam turbine manufacturer. The recommended devices for measuring the condensate flow are differential pressure producers (orifice plates. Steam flow to the condenser shall be calculated by a mass balance around the condenser. A detailed procedure for the calculation is included in Section 6. pressure. 30º apart. and the power output is also measured. This method requires many measurements that are unlikely to be available unless a concurrent steam turbine test is being performed. Use of an ultrasonic flow meter will result in a higher uncertainty for the condensate flow measurement than if an in-line flow element is used. Readings shall be taken at six positions.Performance and Acceptance Testing Energy Balance – If the temperature. it is possible to determine the enthalpy of the exhaust steam by an energy balance. around the circumference of the pipe. 03 psia). the sensor is protected from solar radiation and exposed to a velocity of approximately 1000 ft/min.5 Barometric Pressure Barometric pressure will be measured at least once during each test period with a calibrated accuracy of 200 Pa (0. 6. Following are key considerations: The results tend to be much more reproducible when the inlet air temperature is measured. Measurement of the total input to all fan motors is acceptable if a measurement location isolated from other equipment can be established.1ºF).5.1985 Guidance for Evaluation of Measurement Uncertainty in Performance Tests of Steam Turbines [f].5. current. Temperature measurements at these locations alone should not be used to characterize ACC performance. with a minimum of 12 sensors for the entire condenser. Other structures or uneven topography in the vicinity can influence the amount of recirculation. not necessary to place the sensor in a psychrometer.Performance and Acceptance Testing 6. Inlet temperatures to other equipment such as turbines or boilers are greatly influenced by heat sources in their surroundings. The air inlet temperature will be measured at the discharge location for each fan.6 Fan Motor Input Power The fan motor input power shall be determined by direct measurement of kilowatt input or by measurement of voltage.5. The test result tends to be a fairer representation of ACC performance. and power factor as described in American Society of Mechanical Engineers PTC 6 REPORT . It is. The fan power measurement device shall have a maximum uncertainty of ±2% of reading. At this location. therefore.5. The air temperature will be measured with a four-wire resistance temperature detector or thermistor with a calibrated accuracy of 0.05ºC (0. At least one temperature sensor will be used for each cell.7 Wind Speed Wind speed shall be measured with a calibrated anemometer in an unobstructed location at a height relative to grade corresponding to the smaller of: 6-9 .4 Inlet Air Temperature This guideline recommends ACC performance characterization based on the inlet air temperature as opposed to the ambient air temperature. Slight changes in the wind speed or direction can greatly affect the amount of recirculation and interference. While the amount of recirculation is influenced by the condenser design chosen by the manufacturer. It is difficult to find a location that is not influenced by other heat sources. 6. 6. it is also governed by the condenser siting. which in turn greatly increases the scatter in the test results if based on ambient temperature. Ambient temperature in a power plant can be difficult to measure. ACCs are subject to recirculation (the re-entrainment of the exhaust air into the air inlet) and interference from other heat sources in the area. 6. The design conditions – including steam mass flow rate. 6. 110.).Performance and Acceptance Testing 33 ft (10 m) Half the air inlet height If the wind speed is measured at a height lower than half the air inlet height.5°F) and 0.2 Manufacturer’s Data The manufacturer shall submit a family of performance curves. 100.5 cm (1. representing condenser pressure as function of dry-bulb temperature for steam flow rates of 80. One curve shall be provided for each design steam flow rate. HgA) and a maximum resolution of 3000 Pa/2. A table of values defining the curves shall also be provided.6. An example performance curve is presented in Figure 6-3. Each curve shall be presented with dry-bulb temperature as the abscissa versus condensing steam pressure as the ordinate.2°C (0.0 in. and either form of manufacturer-provided data is acceptable as the basis for capability calculations. fan motor input power.1 Purpose Section 6 develops a method for evaluation of the performance of an ACC from test data based on performance curves provided by the manufacturer. HgA). and 120% of design steam flow rate. steam quality.1°C/mm (5°F/in. The table of values shall be sufficient to allow for the development of interpolation and curve fit equations that can be used in place of reading values off the curves during the performance test. the measured wind speed shall be corrected to the midpoint of the air inlet height using the equation: u c = u( where uc u zm zt zt 0. The curves shall be based on constant fan pitch. steam pressure. consisting of a minimum of five curves. 6-10 . Use of either the curve or the table of values should provide the same result.6 Evaluation of Test Data 6.1 in. and inlet dry-bulb temperature – shall be printed on the curves.2 ) zm wind speed corrected to the midpoint of the air inlet measured wind speed vertical height of the wind speed station vertical height of the midpoint of the air inlet Equation 6-1 = = = = 6. 90. Dry-bulb temperature should be in the range of 0. barometric pressure. Graphical scaling for pressure shall be incremented with a minimum resolution of 300 Pa (0. 0 80 85 90 95 100 105 %Design Flow 80 90 100 110 120 110 Dry Bulb Temperature (F) Figure 6-3 Example Performance Curve 6. Performance Curve 9. The curve so generated is used to read 6-11 .T = m & s.3 Calculation of Condenser Capability The condenser capability will be calculated by: C= c &s m .0 3.4 Predicted Steam Mass Flow Rate The predicted condensing steam pressure at the measured inlet dry-bulb temperature shall be read from each of the performance curves.0 5.Performance and Acceptance Testing The effective area of the condenser and the volumetric airflow at design conditions shall also be included.6. kg/s (lbm/hr) 6.P = m condenser capability.T & s.0 4.P m x 100 Equation 6-2 where C = c & s .0 6. The resulting values shall be used to generate a plot of condensing steam pressure versus steam mass flow rate.0 Condenser Pressure (inHg) 8. percent corrected test mass flow of steam.0 7. kg/s (lbm/hr) predicted mass flow rate of steam at test conditions.6. 0 5.T m Fc Condenser Steam Pressure (inHg) = measured steam mass flow rate at test. pred .Performance and Acceptance Testing the steam flow at the actual condensing steam pressure. This is the predicted steam mass flow & s.T = m & s .0 6.6. dimensionless correction for fan power. m Cross Plot at Test Dry Bulb 7.5 Corrected Test Steam Mass Flow Rate The corrected test steam mass flow rate is calculated by & sc. dimensionless correction factor for barometric pressure.5 6. dimensionless The correction factor for steam quality is calculated by: fx = XT XG Equation 6-5 6-12 . rate. illustrated in Figure 6-4. kg/s (lbm/hr) = correction factor computed by Fc = f x f p f fp where fx = fp = ffp = Equation 6-4 correction factor steam quality.0 80 85 90 95 100 105 110 115 120 Predicted Steam Mass Flow Rate (% Design) Figure 6-4 Cross Plot of Test Data 6.5 5.T Fc m Equation 6-3 where & s .5 7. 45. when the same size wire is used between the MCC and the boundary of supply of the ACC manufacturer. 6-13 . kW guarantee fan motor input power. unless otherwise specified by the manufacturer The correction factor for fan power. ffp.Performance and Acceptance Testing where XT = XG = steam quality at test conditions.9 0. can be calculated by: ⎞ ⎟ ⎟ ⎨(1 − Γ) + Γ f fp = ⎜ ⎜W ⎟ ⎟ W ⎝ G⎠ ⎝ G⎠ ⎪ ⎩ ⎛ WTc ⎜ ⎛ WTc ⎜ −1 ⎧ ⎞3 ⎪ m k −1 ⎫ −1 3 ⎪ ⎬ ⎪ ⎭ Equation 6-7 WTc WG = = test fan motor input power corrected for inlet air conditions. this factor can be calculated based on design information specified in Section 6. This is because the line loss will be proportional to the length of the wire between the MCC and the fan motor. kg/m3(lbm/ft3) density of inlet air at guarantee conditions. kg/kg (lbm/lbm) The correction factor for barometric pressure. kg/kg (lbm/lbm) steam quality at guarantee conditions. kg/m3 (lbm/ft3) The average fan motor input power shall be corrected for any line losses between the measurement point and the boundary of supply for the condenser manufacturer. The line loss can be calculated to one fan motor and applied to the other fan motors. fp. kW The corrected fan motor power can be calculated by ⎧ρ ⎫ WTc = ⎨ G ⎬ ⎩ ρT ⎭ Equation 6-8 where ρT = ρG = density of inlet air at test conditions. shall be calculated by: ⎧P P mk ⎫ f p = ⎨ T (1 − Γ) + Γ( T ) ⎬ PG ⎭ ⎩ PG −1 Equation 6-6 where = PT = PG Γ = mk = test barometric pressure. kPa (psia) design barometric pressure. kPa (psia) constant factor based on design information. Spatial uncertainties are calculated from the average of local measurements in space. Systematic uncertainties are estimated from review and analysis of the instrument manufacturer’s specifications. independent parameter measurement by additional means. These errors are also called bias errors. Spatial Systematic Uncertainty – Spatial systematic uncertainty errors occur during the measurement of a spatially diverse sample. For example. and examination of typical calibration data. Precision errors can be reduced by increasing the number of measurement repetitions or by selecting data intervals with greater stability. the variability in a dry-bulb temperature reading at a specific location). Although it is possible to evaluate random uncertainty for a given test interval for each measured parameter.Performance and Acceptance Testing 6. Spatial error is defined as the difference between the true average value of a parameter and the average produced by an array of instruments used to measure the parameter. Random errors are evident by the scatter of data that results from repeated measurements of transient data (e. 6-14 . These uncertainties are primarily a result of the intrinsic accuracy of the instruments and the calibration procedures employed. which in turn causes changes in recirculation and interference.1 – 1998 Test Uncertainty [g] test code: Systematic uncertainty Random uncertainty Spatial uncertainty Sensitivity coefficients An overview of the uncertainty components is provided below. The pretest uncertainty analysis should be documented in the test plan. They are treated as constants for a given test period but may vary from one test period to another.g.7 Test Uncertainty The purpose of the pretest uncertainty is to predict the uncertainty of the test results and to aid in the specification of test instrumentation that will achieve the test objective.. Systematic Uncertainty – Systematic uncertainties are approximations of the fixed errors inherent in a measurement. Spatial errors also occur during the measurement of condensate flow if an ultrasonic flow meter is used to measure the condensate flow. a more meaningful result is obtained by basing the random uncertainty on the variation of the condenser capability for the test periods. The following major uncertainty components are addressed in the ASME PTC 19. Spatial errors for a condenser performance test occur during the measurement of the inlet dry-bulb temperature. Random Uncertainty – Random uncertainty is also referred to as precision uncertainty. the spatial variation of the dry-bulb temperature may change from test to test due to changes in wind speed and direction. Systematic errors are typically the largest source of error in a condenser performance test. The purpose of a posttest uncertainty analysis is to determine the accuracy or validity of the test result. a (Ta . ∆Tlm.8 Basic Equations (A) Q = UA∆T1m where Q U A ∆Tlm A-1 = = = = heat duty overall heat transfer coefficient air-side heat transfer area for the condenser log mean temperature difference The log mean temperature difference. is defined as: ∆Tlm = (Ts − Ta.i ⎞ ⎟ ln⎜ ⎜T −T ⎟ s a.i − hc .i ⎛ Ts − Ta. it is usually more convenient to calculate the sensitivity factor numerically as the ratio of the change in the test result to the change in the test parameter. However. o ) Q=m where &s m hs.i hc.Performance and Acceptance Testing Sensitivity Factors – Sensitivity factors relate a change in an independent measured parameter to the resulting change in the test result. o − Ta . Sensitivity factors are used to combine the uncertainties for each test parameter into the uncertainty in the overall test result. The heat duty for the condenser is: & s (hs .o A-3 = = = mass flow rate of steam enthalpy of inlet steam enthalpy of liquid condensate 6-15 . o ⎝ ⎠ A-2 where Ts Ta. o ) = m & a c p .i Ta.o ) ⎛ Ts − Ta. The true condensing temperature is not the same as the saturation temperature corresponding to the turbine backpressure and it can be as much as a few degrees higher than the actual condensing temperature in the ACC because of the pressure drop in the steam ducting.o = = = condensing steam temperature inlet dry-bulb temperature outlet dry-bulb temperature Note: Equation A-2 will generally give you a very different answer than Equation A-1 because of the difficulty in determining the exact condensing steam temperature. 6.i ) − (Ts − Ta.i ⎞ ⎟ ln⎜ ⎜T −T ⎟ s a.o − Ta. These sensitivities may be calculated as the partial derivative of the test result with respect to the parameter of interest. o ⎝ ⎠ = Ta. a m A-9 6-16 .i = = volumetric airflow air density at inlet conditions For constant pitch performance curves.i hs + (1 − X s .a m & a c p . the volumetric airflow rate is independent of air temperature and pressure.a = = mass flow rate of air heat capacity of air The enthalpy of the inlet steam can be calculated by: hs .i ) Q=m UA ) e( & a c p .Performance and Acceptance Testing &a m cp.a (Ts − Ta . A-2. and A-7: UA ) −1 & a c p .i )hl A-4 where Xs.a m A-6 From equation A-1 U= Q A∆Tlm A-7 and from equations A-1.i A-5 where & V a .i ρa.i a . o = Ta .i = X s . The outlet air temperature is calculated by: Ta .i + Q & ac p.i hs hl = = = quality of inlet steam enthalpy of saturated steam at the condenser inlet pressure enthalpy of condensate at the condenser inlet pressure The mass flow rate of the inlet air can be calculated by: & ρ &a =V m a .a m e( A-8 The number of heat transfer units is defined as: NTU = UA & ac p. A-16 NTU T − NTU G NTU NTU T NTU ΦT = 1 + NTU G G − NTU G G =1+ NTU G e −1 e − 1 NTU G e −1 ΦG Defining A-17 6-17 .i ∆Tlm A-10 Therefore & a c p .i ) Q=m e NTU − 1 e NTU A-11 The effectiveness of the condenser is defined as: Φ= Ta . o − Ta . a (Ts − Ta .Performance and Acceptance Testing and is equivalent to: NTU = Ta .i A-13 For the case of isothermal condensation: Φ = 1 − e − NTU The ratio of the test to guarantee effectiveness is: A-14 ΦT ⎛ 1 − e − NTU T =⎜ − NTU G ΦG ⎜ ⎝1− e ⎞ 1 − e − ( NTU T − NTU G ) ⎟ ⎟ =1+ e NTU G − 1 ⎠ A-15 For small values of δ(-0.15<δ<0.i A-12 and is equivalent to Φ = NTU ∆Tlm Ts − Ta .15) e −δ ≈ 1 − δ Therefore.i Ts − Ta . o − Ta . G NTU T U T m = & a .T QT ΦT m = & a .i . i . i .i . i .TVa .i . mk & ⎞mk ⎛V ⎜ a . . A-19 & a . is a function of Reynolds number & ) α a ∝ Re mk ∝ (ρ qV a mk A-24 Since the overall heat transfer resistance is dominated by the air-side resistance ρ a .i .T NTU G U G m Since A-21 & & a = ρ aV m a where & = V a ρa = A-22 volumetric flow rate of air density of air A-23 & NTU T U T ρ a .GV a .G ⎠ A-25 ρ a .T ⎠ 1− m k A-26 .T The air-side heat transfer coefficient. αa.G ⎞ NTU T ⎛ ⎟ =⎜ ⎟ NTU G ⎜ ρ ⎝ a . a i G ⎠ ⎝ Therefore.G QG Φ G m From equation A-10 A-20 & a .i .i . i .i .G = & NTU G U G ρ a .Performance and Acceptance Testing Γ= NTU G e NTU G − 1 A-18 ΦT NTU T =1+ Γ −Γ ΦG NTU G From equations A-4 and A-13.T ⎠ 6-18 1− m k & ⎞ ⎛V ⎜ a .T ⎞ UT αT ⎛ ⎟ ≈ ≈⎜ ⎟ UG αG ⎜ ρ .T ⎟ ⎜V & ⎟ ⎝ a .G ⎟ ⎟ ⎜V ⎝ a . G V a .T ⎠ ⎢ ⎣ From fan affinity laws: & ⎛ W c ⎞3 V T T =⎜ ⎜W ⎟ ⎟ & V G ⎝ G⎠ where = WG c = WT 1 ⎡ 1− mk & ⎛V ⎞ ⎜ a .T QT ⎜ m ⎝ WG ⎠ c T −1 3 m k −1 ⎡ ⎤ c ⎞ ⎛ W ⎢1 − Γ + Γ⎜ T ⎟ 3 ⎥ ⎜W ⎟ ⎢ ⎥ ⎝ G⎠ ⎢ ⎥ ⎣ ⎦ −1 f fp = A-30 From the ideal gas law: ρ= PM RTA A-31 where P M R TA = = = = absolute pressure.G ⎟ ⎜V ⎟ & ⎝ a .i .i .T ⎠ 1− m k ⎤ ⎥ ⎥ ⎥ ⎦ A-27 A-28 fan power at guarantee conditions test fan power corrected to design temperature and pressure Substituting in equation A-27 yields: ⎛ ρ a .3143x10 kg − mole K (10.i . A-20.T WT ⎢ ⎟ ⎜ 1− m k m k −1 ⎤ ⎛ WTc ⎞ 3 ⎥ ⎟ ⎜ ⎜W ⎟ ⎝ G⎠ ⎥ ⎥ ⎦ A-29 The correction factor for fan power is: & s . 28.G QG ⎛ W ⎞ m ⎟ = =⎜ ⎟ & s .G ⎟ = ⎜ρ ⎟ & ⎢ QG ρ a .G ⎞ QT ⎜ ⎟ 1 − Γ + Γ = ⎟ ⎢ ⎜ρ ⎟ QG ρ a .945 kg/kg-mole (lbm/lbm-mole) Pa m3 psi ft 3 3 ) universal gas constant.Performance and Acceptance Testing From equations A-19.i .G ⎜ W ⎝ G⎠ ⎢ ⎝ a .i .T V a .73 lbm − mole o R absolute temperature.i .T ⎢ 1 − Γ + Γ⎜ a .i .i . Pa (psia) molecular weight of gas.i .i . 8. K (°R) 6-19 .i .G ⎝ a .i .T ⎠ ⎣ 1⎡ c ⎞3 ⎛ ρ a . and A-26: & ⎛ρ ⎞ QT ρ a . G ⎞ & s .i + Q & ac p. ⎝ ⎠ ⎦ ⎣ −1 A-32 where Pa. o − Ta .i B-3 Calculate outlet air temperature using equation A-7 Ta .o − Ta .i ⎞ ⎟ ln⎜ ⎜T −T ⎟ s a .i ∆Tlm B-6 6-20 .T QT Pa . o = Ta .i − hc .Performance and Acceptance Testing The change in volumetric flow with inlet temperature is included in the performance curves.T = = atmospheric pressure at guarantee conditions atmospheric pressure at test conditions 6.i ⎛ Ts − Ta .G Pa.G ⎡ m ⎟ ⎥ ⎢1 − Γ + Γ⎜ = = fp = ⎜P ⎟ & s .a m B-4 Calculate log mean temperature difference using equation A-2 ∆Tlm = Ta .T ⎢ m ⎥ a T .G QG Pa .i a . the correction factor for barometric pressure is 1− m k ⎤ ⎛ Pa . Therefore. o ) Q=m Calculate the inlet air density at guarantee conditions using equation A-30 B-1 ρ= PM RTA B-2 Calculate the air mass flow rate using equation A-5 & ρ &a =V m a . o ⎠ ⎝ B-5 Calculate NTU using equation A-11 NTU = Ta .9 Calculation of Condenser Characteristics (B) Calculate guarantee heat transfer rate using equation A-4 & s (hs . HgA hp mph ºF acfm Design 1.775x10 7 Test 1.6 3.8 81.0 89.1 1114. HgA ºF in.2 ---- Condensing steam temperature and specific enthalpy values for steam and liquid water were calculated by using steam properties software.0 113.0 28. HgA) 6-21 .1 Design and Test Data ACC design and test conditions are presented in Table 6-2.0 1049. Table 6-2 Air-Cooled Condenser Test Data Parameter Steam flow Steam quality Condenser pressure Inlet air temperature Atmospheric pressure Fan power Wind speed Condensate outlet temperature Volumetric airflow Calculated Values Condensing steam temperature Enthalpy of vapor at condenser pressure Enthalpy of liquid at condenser pressure Enthalpy of condensing steam Enthalpy of condensate at outlet temperature ºF Btu/lbm Btu/lbm Btu/lbm Btu/lbm 115.250.56 5634 8.49 28. 6.0 124.1 1060.10.250.00 65.9 92.85 6115 10.1 83.10 Example Air-Cooled Condenser Capability Calculations 6. Table 6-3 Performance Curves Condensing Pressure (in.2 Performance Curves The performance curves supplied by the manufacturer are presented in Figure 6-5 and Table 6-3.10.0 1111.86 75.0 3.Performance and Acceptance Testing Calculate the heat transfer characteristic using equation A-18 Γ= NTU G e NTU G − 1 B-7 6.2 Units lbm/hr % in.6 121.000 94 3.834 94. 01 1.00 2. The predicted condenser pressure at the test inlet air temperature of 75.53 3.0 80.75 1.5 120% Flow 6.03 2.0 45.48 3.02 4.74 1.63 2.39 5.30 2.Performance and Acceptance Testing Air Temp 85.90 3.99 2.62 2.0 55.44 3.0 65.30 2.0 75.48 3.0 75.31 2.62 2.96 3.51 1.02 2.42 3.44 3.98 4.32 3.65 4.41 2.31 5.02 1. 6-22 .48 100% Flow 5.05 110% Flow 5.0 70.63 2.39 3.30 2.05 4.01 1.40 2.49 80% Flow 3.95 90% Flow 4.0 50.02 4.68 5.92 3.0 60.87 3.07 Design data for condenser pressure as function of dry-bulb temperature for steam flow rates between 80% and 120% of the design flow rate were provided by the manufacturer.89 3.42 3.63 2.98 2.5ºF was calculated by nonlinear interpolation for each flow rate.77 3. 00 4.00 1.3 Predicted Steam Flow at Test Conditions The data required for calculation of the predicted flow at test conditions are summarized in Table 6-4.00 5.50 1.50 2.Performance and Acceptance Testing 6.10.00 45 120% Flow 50 55 110% Flow 60 65 70 75 80 80% Flow 85 Inlet Air Dry Bulb Temperature (F) 100% Flow 90% Flow Figure 6-5 Air-Cooled Condenser Performance Curves 6.00 3.00 2.50 3.50 4.50 ACC Condensing Pressure ("HgA) 5. 6-23 . 86 in.225.P = (0.491)(28.85)(0.05 3.i = 3. The predicted steam flow rate at test conditions is m s.25x106 (1049.8 − 83.01% The predicted percentage steam flow rate at test pressure of 3.208x109 Btu / hr 2.250. Calculate guarantee heat transfer rate using equation B-1 & s (h s.0729lbm / ft 3 (10.9801) x (1.86 Steam Flow % of Guarantee 80% 90% 100% 110% 120% 98.95 4. Calculate the inlet air density at guarantee conditions using equation B-2 ρ= PM RTA ( 28.10.i 6-24 .i a .73)(65.o ) Q=m Q = 1.945) = 0.7) ρ G = ρ a .Performance and Acceptance Testing Table 6-4 Condenser Pressure at Test Conditions Condenser Pressure in.48 5.07 3.0 + 459. Calculate the air mass flow rate using equation B-3 & ρ &a =V m a .i − h c. HgA 3.000) = 1. HgA was calculated by nonlinear interpolation from the data in Table 6-4.49 3.069lbm / hr 6.4 Calculation of Condenser Characteristics 1.0) = 1. 0729)(60) = 1.24) = 95.5 = 0. a m Ta .65x108 (0.i ∆Tlm NTU = 95. Calculate the heat transfer characteristic using equation B-7 Γ= NTU G e NTU G − 1 Γ= 0.0 + 1.5 ⎠ 6.5 − 65.i ⎞ ⎟ ln⎜ s ⎜T −T ⎟ a .i ⎛ T − Ta . Calculate log mean temperature difference using equation B-5 ∆Tlm = Ta .4 7.o ⎠ ⎝ s ∆Tlm = 95. Calculate correction for steam quality using equation 6-5 fx = XT XG 6-25 .i + Q & a c p. o − Ta .Performance and Acceptance Testing & a = (3.6508x108 lbm / hr m 4. o − Ta .942 = 0.5 Correction to Guarantee Conditions 1.942 32.o = 65.5 5. o = Ta .0 − 65.4 ⎛ 115.0 − 95.208x109 1.602 e 0.5 − 65.942 − 1 6.0 = 32.775x107 ) ( 0. Calculate outlet air temperature using equation B-4 Ta . Calculate NTU using equation B-6 NTU = Ta .10.0 ⎞ ln⎜ ⎟ ⎝ 115. 602 ) 0 .012 6115 ⎝ ⎠ ⎪ ⎪ ⎩ ⎭ −1 6.007 94.0729 5.012) = 1.0707 5634 = 5464 hp 0. Calculate fan power correction using equation 6-7 ⎛W ⎞ f fp = ⎜ ⎟ ⎜W ⎟ ⎝ G⎠ c T −1 3 m k −1 ⎫ ⎧ c ⎛ WT ⎞ 3 ⎪ ⎪ ⎬ ⎨(1 − Γ) + Γ⎜ ⎟ ⎜W ⎟ ⎝ G⎠ ⎪ ⎪ ⎭ ⎩ −1 ⎛ 5464 ⎞ 3 f fp = ⎜ ⎟ ⎝ 6115 ⎠ −1 0.602( fp = ⎨ 28.0 2.491)(28.56 ) ⎬ = 1.85 3.025 6-26 .6 = 1.5 + 459. Calculate corrected fan power using equation 6-8 c = WT ρT WT ρG c WT = 0.007)(1. Calculate test steam flow correction factor using equation 6-4 Fc = f x f p f fp Fc = (1. 602 ⎜ ⎟ ⎨ ⎬ = 1.45 ⎫ ⎧ 28.56)(0. Calculate correction for barometric pressure using equation 6-6 ⎧P P m ⎫ f p = ⎨ T (1 − Γ) + Γ( T ) k ⎬ PG ⎩ PG ⎭ −1 28.85 ⎭ ⎩ 28.45 −1 ⎧ ⎫ 5464 ⎪ ⎛ ⎞ 3 ⎪ − + ( 1 0 .56 0.602) + 0.7) 4.0707lbm / ft 3 (10.945) = 0.007)(1. Calculate air inlet density at test conditions using ρ = −1 PM RTA ρT = (28.73)(75.007 (1 − 0.Performance and Acceptance Testing fx = 94. d he.d = = = = moisture fraction of the turbine exhaust at the heat balance conditions specific enthalpy of saturated vapor at the exhaust pressure specific enthalpy of the exhaust steam specific enthalpy of saturated liquid at the exhaust pressure 6-27 . d − h l. Using steam tables or equivalent software look up (or calculate) the specific enthalpy and specific entropy of the low-pressure turbine inlet steam.T = (1.931 (100) = 103.025) = 1.d hl. From the turbine heat balance diagram corresponding to the ACC design conditions.d h e . d − h l.2% 1. inlet temperature. T Fc & sc. 2. d h v.069 6.263.10. and flow.931lbm / hr m 6. This is equivalent to assuming a constant isentropic efficiency for the low-pressure turbine. Calculate corrected condenser steam flow using equation 6-3 c &s & m .Performance and Acceptance Testing 7.6 Calculation of Condenser Capability Calculate condenser capability using equation 6-2 c &s m C = . P m C= 1. T (100) & s. Studies using cycle models have indicated that the error involved with calculating the steam quality based on this assumption is less than 1%. T = m s .834)(1.263. pressure. 3. Calculate the quality of the turbine exhaust steam by: Xd = where Xd hv.225.250. obtain the inlet temperature and pressure for the low-pressure turbine as well as the turbine exhaust enthalpy and pressure. 1.11 Calculation of Steam Quality Procedure for Calculation of Steam Quality at Turbine Exhaust The procedure that follows assumes that the slope of the enthalpy versus entropy line for the low-pressure steam turbine is independent of the exhaust pressure. d = = = specific entropy of turbine exhaust steam specific entropy of saturated vapor at the turbine exhaust pressure specific entropy of saturated liquid at the turbine exhaust pressure 5. d − h e.i si hl (h i − h l ) + m e (si − s l ) (h v − h l ) + m e (s v − s l ) = = = = steam quality at the turbine exhaust at test conditions specific enthalpy of the inlet steam for the low-pressure turbine specific entropy of the inlet steam for the low-pressure turbine specific enthalpy of liquid water at the turbine exhaust pressure 6-28 . Calculate the entropy of the turbine exhaust steam by: s e . d = (1 − X d )s v . 4.d sl. d − se. 6. From the temperature and pressure of the turbine inlet steam at test conditions.Performance and Acceptance Testing This value should correspond to the guarantee condition for the condenser. rather than the expansion line end point (ELEP). Calculate the quality of the steam at the test condition by: XT = where XT ht. 7. hi and entropy.d h i. determine the enthalpy. d + X ds l.d = = = slope of the expansion line enthalpy of the low-pressure turbine inlet steam entropy of the low-pressure inlet steam Note 1: The termination point of this expansion line is the used energy end point (UEEP). d where se sv.d si. of the exhaust steam at test conditions. Note 2: If a turbine test on the unit has been performed. d si. Calculate the slope of the expansion line by: me = where me hi. The ELEP is a constructed quantity to allow for calculation of the enthalpy value for the extraction steam to the low-pressure condensate heaters (if any). si. The UEEP represents the actual enthalpy of the exhaust steam. the slope of the expansion line may be calculated by substituting actual values from the turbine test for the design values in steps 1 through 5. which may be saturated. Texas: CTI. reaffirmed 1997. New York: ASME. New York. c) Cooling Technology Institute. Der Grosskraftwerksbetreiber E. 2004. Essen. d) American Society of Mechanical Engineers. Revised February 2000. New York. e) American Society of Mechanical Engineers. 1998. VGB-R 131 M e. Acceptance Test Code.1985 Guidance for Evaluation of Measurement Uncertainty in Performance Tests of Steam Turbines. PTC 19. Germany: VGB Technische Vereinigung. New York. PTC 6 REPORT . Houston. f) American Society of Mechanical Engineers. ATC-105 (00). New York: ASME.1 – 1998 Test Uncertainty. New York.5 – 2004 Flow Measurement. g) American Society of Mechanical Engineers. New York: ASME. reaffirmed 2004. b) American Society of Mechanical Engineers.. 6-29 . PTC 12. PTC 23 – 2003 Atmospheric Water Cooling Equipment.V.12 References a) VGB.Performance and Acceptance Testing hv Se = = specific enthalpy of vapor at the turbine exhaust pressure specific entropy of liquid water at the turbine exhaust pressure 6. VGB Guideline: Acceptance Test Measurements and Operation Monitoring of AirCooled Condensers under Vacuum. 1985. 2003. New York: ASME. New York.2 – 1998 Steam Surface Condensers. New York: ASME. 1997. 1998. PTC 19. . 1 Overview This chapter is intended to summarize major ACC installation and commissioning issues. Perhaps the most vulnerable ACC components are the finned-tube sections. they should note unusual transfer of weights. It assumes that a free on board (FOB) job site protocol characterizes the contractual relationship between the purchaser and the supplier. It can be the case that rail. or in rare cases. 7.7 AIR-COOLED CONDENSER INSTALLATION AND COMMISSIONING ISSUES 7. or other contaminants. temporary storage.2 Unloading of Air-Cooled Condenser Components The purchaser should solicit specific unloading procedures from the ACC supplier. However. any evidence of separation of finned tubes from collection headers should be noted and reported to the shipper and supplier.1 Shipping and Receiving ACC components are typically manufactured and preassembled in sizes and weights to facilitate shipment via truck from point of manufacture to the job site. etc. the responsible party or parties (which may be dictated by ownership of record and attendant insurance coverage) should receive the shipments. 7. Finally. in most cases. construction. At that time. and the erection and initial check out of the ACC. damaged packaging. Particular scrutiny of these sections should be made to assess whether damage to them has occurred prior to unloading.. In any event. it is common that the ACC supplier would provide guidance. It is based on the assumption that.2. Signs of damage to protected or galvanized surfaces should be noted. storage. dirt.2. cargo ships and trucking are used in combination. In addition. surfaces should be inspected for evidence of grease. both written and via on-site technical and commissioning assistance. documenting any aberrations via photographs and written correspondence. This would include such areas as: Tie down and bolting arrangements and removal of the same 7-1 . protection of components. to promote proper offloading. and commissioning. the ACC supplier is not responsible for unloading of ACC components.2 Unloading and Storage 7. Air-Cooled Condenser Installation and Commissioning Issues Component lists, including descriptions, weights, etc. Location of lifting lugs Recommendations for support or spreader beams, jigs, straps, etc. for lifting Precautions on lifting procedures Notations of unique supporting requirements (e.g., spreader bars) for specific components, etc. 7.2.3 Storage of Air-Cooled Condenser Components Depending on plant construction and shipping sequencing schedules, ACC components may be placed in lay down and/or storage areas for an extended period. If this is anticipated, specific instructions from the supplier for storage and protection of ACC components should be solicited. 7.3 Erection of the Air-Cooled Condenser ACC erection should be performed in strict accordance with instructions and procedures provided by the supplier. Therefore, the ACC specification should solicit the following: A list of all components to be installed (e.g., structural steel, A-frames, finned-tubes, steam and condensate headers, wind walls and division walls, steam ducting, ejector skids, condensate tanking, interconnecting piping, gearboxes, motors, fans, fan rings, walkways, ladders, cleaning systems, instrumentation and control sensors and systems, etc. A reiteration of foundation requirements, connections, etc. Documentation on the sequence of erection, noting individual and cumulative tolerances Special tools, jigs, spreader bars, etc. that might be required or would prove valuable in construction Welding and fitting procedures, including torque settings, etc. 7.4 Startup and Commissioning Tests 7.4.1 Pressure Testing Pressure testing of the assembled ACC system(s), is an essential part of commissioning and startup . This testing verifies the integrity of the total ACC system, including finned-tube bundles, steam headers, dephlegmator sections, and connecting piping. Pressure and integrity testing should also extend to the condensate system, including piping, drains, valving, etc. The ACC should be equipped with a blanking plate spool piece that can be used to isolate the system for pressure testing. To conduct pressure testing, a compressor capable of pressurizing the total ACC system to 15 psig should be provided along with pressure relief valving. Once the system is fully pressurized, leak-test fluid can be administered to weld joints, fittings, and other connections that may be suspect, based on supplier insights from previous installations. 7-2 Air-Cooled Condenser Installation and Commissioning Issues 7.4.2 In-leakage Testing Air in-leakage testing can also be performed, obviously after the ACC is in service and sufficient vacuum exists on the ACC system. In performing such tests, a tracer gas is typically administered around welded connections, valving, fittings, etc. Monitoring for that same gas at the exhaust of the air ejector system reveals the presence of leaks and the need for remedial action. Helium injection, a procedure used in the 1970s and 1980s has been replaced with the more common and sensitive sulfur hexafluoride (SF6), which requires lower concentration limits for detection. Testing contractors specializing in such services can typically offer insights and experience for efficient administration of leak-test gases. Areas where leaks typically occur – such as around weld joints, valves, and test ports – should be well known to testing services suppliers. 7.4.3 Internal Cleaning and System Inspections Experience indicates that the ACC can be a collection or disposal point for debris, including carryover of trace metals and contaminants from the steam system. For this reason, it is recommended that inspections and internal purging of the ACC be performed during outages and prior to performance and acceptance testing of the equipment. The ACC manufacturer should spearhead those efforts as part of the commissioning, startup, and acceptance testing. 7.4.4 Rotating Equipment and Vibration Assessments Before the fans, motors, and gearboxes are operated, the gearboxes should be filled with the proper type and level of lubricant. In addition, all bolts and connections should be checked for proper torque. Fans and fan shafts can be rotated by hand to ensure proper clearance and to confirm that there are no obstructions in the path of the fan blades. During initial startup of the rotating equipment, vibration switches can be set to their minimum sensitivity to assess the vibration behavior of the rotating equipment. Fan tip clearance, tracking, and blade pitch settings should be verified for each fan assembly and blade. This information should be recorded to ensure that these assessments were made and to reference during future outages and verifications. Once the fans, motors and gearboxes are energized, the following areas should be assessed: Motor voltage and current along with ambient air temperatures Gearbox lube oil temperatures, which should remain at ~190–210ºF (~90–100ºC) Motor bearing temperatures to determine if they remain within specified limits With the fans still in operation, the vibration switch sensitivities can be increased to a trip point and then backed off slightly. 7-3 Air-Cooled Condenser Installation and Commissioning Issues 7.4.5 Walk-Through Inspection With the ACC in its initial operation, a walk-through inspection should be performed with the following areas in mind: Is each bay free of debris, grease, or other contaminants? Are the bays and doorways properly installed and providing cell-to-cell isolation? Are there any signs of finned-tube bundle corrosion in this early post-construction stage? Are the walkways, fan bridge, ladders, inlet screens and supports, and access platforms properly installed and plumb? Are there any obvious signs of excessive or differential vibrations from cell to cell? Is all hardware, valving, and instrumentation installed per the specification and supplier’s proposal? Is the equipment operating properly and supplying reasonable outputs and functionality? Is the condensate tank system installed properly, and are the condensate pumps operating properly? Has the rupture disc been installed properly and the blind plate been removed following pressure testing? Is the air ejector system operating properly? 7-4 Benicia.A.0 97 1984 Combined Cycle Cogeneration (Supplied & Erected) Combined Cycle Cogeneration (Supplied & Erected) Waste Wood 7. 8 Chugach Electric Assoc. Gillette.1: GEA Power Cooling.5 100 1975 330 1.S.6 35 1979 Combined Cycle 3.) NAS North Island Cogen Plant Sithe Energies. Inc.884.A AIR-COOLED CONDENSER INSTALLATIONS Appendix A.000 5.) Dutchess County RRF Poughkeepsie.6 40. MA (R.950 9. WY (Stearns Roger) Norton P.. and Pacific Power & Light Co. CA Wyodak Station Black Hills Power & Light Co. Inc. Direct Air-Cooled Condenser Installations STATION OWNER (A/E) Neil Simpson I Station Black Hills Power & Light Co. CA (Mechanical Technology Inc.0 66 1977 Coal-Fired Plant 65 478.03 48 1981 Combined Cycle Cogeneration 4. CA NTC Cogen Plant Sithe Energies.5 50.0 70 1984 22. NY (Pennsylvania Engineering) SIZE MWe (1) 20 STEAM FLOW [Lb/Hr] 167. Braintree.0 70 1984 2.0 79 1985 WTE A-1 .030 2.7 52.4 181.5 50 1975 Combined Cycle NA 48. [Deg.340 4. Potter Generating Station Braintree Electric Light Dept. Beluga.880 6. AK (Burns & Roe) Gerber Cogeneration Plant Pacific Gas & Electric Gerber. HgA] 4. Inc.W. F] 75 YEAR REMARKS 1968 Coal-Fired Plant 20 190.5 DESIGN TEMP.000 3. CA (Ultrasystems Eng.. Beck) Benicia Refinery Exxon Company. & Const.0 65. Inc.800 6. CA Chinese Station Pacific Ultrapower China Camp. WY (Stone & Webster) Beluga Unit No. U.550 TURBINE Back Pressure [In. San Diego.400 5. Gillette.000 5. Coronado. MA (Stone & Webster) Hazelton Cogeneration Facility Continental Energy Associates Hazelton. PA (Brown Boveri Energy Systems) Grumman TBG Cogen Bethpage.700 5.0 47 1989 WTE (Supplied & Erected) A-2 .5 420.Air-Cooled Condenser Installations STATION OWNER (A/E) SIZE MWe (1) 20 STEAM FLOW [Lb/Hr] 125.000 3.450 2. Facility Ogden Martin Sys.5 59 1986 WTE (Converted to PAC SYSTEM®.0 Sherman Station Wheelabrator Sherman Energy Co.0 59 1989 Combined Cycle Cogeneration 26 153.0 59 1989 Combined Cycle Cogeneration 100 714. Bellingham. of Haverhill Haverhill. Inc. Canada (Volcano.000 7. MA (Westinghouse Electric Corp. Facility Wheelabrator Spokane Inc. Inc.) TURBINE Back Pressure [In. MN (HDR Techserv) Chicago Northwest WTE Facility City of Chicago Chicago.0 60 1988 Combined Cycle Cogeneration (Converted to PAC SYSTEM®. MA (Bechtel. Sherman Station.5 80 1985 WTE 1 42. WA (Clark-Kenith.900 3. 1999) WTE 46.) Haverhill Resource Rec. WV (Fru-Con Construction Corp. ME (Atlantic Gulf) Olmsted County WTE Facility Rochester. 1997) Combined Cycle Cogeneration 80 622.830 5.) North Branch Power Station Energy America Southeast North Branch.7 47 1987 Combined Cycle Cogeneration (Supplied & Erected) 13 105.0 90 1989 Coal-Fired Plant 100 714. HgA] 43 DESIGN TEMP. [Deg.500 3. F] 1985 YEAR REMARKS Waste Wood 4 42.0 85 1987 67.) Sayreville Cogen Project Intercontinental Energy Co.000 5. Spokane.9 351. Sayreville.000 3.5 90.900 3.4 59 1988 10. NJ (Westinghouse Electric Corp. IL SEMASS WTE Facility American Ref-Fuel Rochester.000 15 PSIG 90 1986 WTE 54 407.) Bellingham Cogen Project Intercontinental Energy Co. Ontario.) Spokane Resource Rec. Inc. NY (General Electric) Cochrane Station Northland Power Cochrane.950 2. ) Linden Cogeneration Project Cogen Technologies. NY (Westinghouse Electric / RESD) SIZE MWe (1) 30 STEAM FLOW [Lb/Hr] 196.Air-Cooled Condenser Installations STATION OWNER (A/E) Exeter Energy L.800 5.250 6.0 90 1992 Combined Cycle Cogeneration 50 258.0 94 1991 80 736.) Dutchess County RRF Expansion Poughkeepsie. Project Oxford Energy Sterling. NY (Stone & Webster) Neil Simpson II Station Black Hills Power & Light Co. of Union County Union. Linden. Inc. PA (Zurn/Nepco.000 8.660 5. Ontario. NJ (Ebasco Constructors. Canada (SNC Services.0 82 1991 Combined Cycle Cogeneration WTE (Supplied & Erected) 50 357. Inc.000 TURBINE Back Pressure [In.0 66 1992 Coal-Fired Plant (Supplied & Erected) 2x 50 2x 349.750 4. Inc. F] 75 1989 YEAR REMARKS PAC SYSTEM® 10 88.0 95 1990 Combined Cycle 20 150. Ontario.P. NY (Zurn/Nepco.000 2.911.150 6.) University of Alaska University of Alaska. [Deg.) Onondaga County RRF Ogden Martins Sys.0 90 1993 Combined Cycle 15 + 49.000 3. of Onondaga Co.5 68 1990 WTE 15 169.000 6. AK Union County RRF Ogden Martins Sys. Inc. Nipigon. WY (Black & Veatch) Gordonsville Plant Mission Energy Gordonsville. Fairbanks Fairbanks. HgA] 2. Hawaii (Stone & Webster) Norcon .Welsh Plant Falcon Seaboard North East. VA (Ebasco Constructors.0 59 1990 Combined Cycle Cogeneration 285 1.5 55 1990 Combined Cycle Cogeneration 10 46. Ltd. Ltd. Inc.200 6. NJ (Stone & Webster) Saranac Energy Plant Falcon Seaboard Saranac. CT Peel Energy from Waste Peel Resources Recovery.0 70 1992 WTE (Supplied & Erected) 80 548.000 3. Brampton.000 2. Canada (SNC Services.9 DESIGN TEMP.) Nipigon Power Plant TransCanada Pipelines Ltd.0 79 1993 WTE A-3 . Maui. Inc. Gillette.44 54 1990 Combined Cycle Cogeneration 20 158. Onondaga.) Maalaea Unit #15 Maui Electric Company. Ltd. 300 3.0 DESIGN TEMP. Australia (Davy John Brown Pty. Mexico (Bechtel Corporation) Potter Station Potter Station Power Limited Potter.) Pine Creek Power Station Energy Developments Ltd.0 50 1994 Combined Cycle 10 95.0 50 1994 6 58.0 53.900 7.0 53. Iowa Cedar Falls. Kapuskasing. MA Arbor Hills Landfill Gas Facility Browning-Ferris Gas Services Inc.63 77 1994 Combined Cycle 6 74. Northern Territory.0 85 1994 WTE (Supplied & Erected) Combined Cycle 9 87.296.000 2.540 4. MI (European Gas Turbines Inc. Canada Haverhill RRF Expansion Ogden Martin Sys.880 3.8 66 1993 Combined Cycle 40 246.000 4. Ontario.) Pine Bend Landfill Gas Facility Browning-Ferris Gas Services Inc.9 +44.) Cabo Negro Plant Methanex Chile Limited Punta Arenas. Canada Kapuskasing Plant TransCanada Pipelines Ltd. Ontario (Monenco/Bluebird) Streeter Generating Station Municipal Electric Utility City of Cedar Falls. Iowa (Stanley Consultants) MacArthur Resource Recovery Facility Islip Resource Recovery Agency Ronkonkoma.6 1994 Combined Cycle 30 245.000 3.000 2.6 1994 Combined Cycle 46. Chile (John Brown) SIZE MWe (1) 210 STEAM FLOW [Lb/Hr] TURBINE Back Pressure [In.500 5.) North Bay Plant TransCanada Pipelines Ltd.8 79 1993 WTE (Supplied & Erected) 30 245.5 50 1993 PAC SYSTEM® (Supplied & Erected) 11 40. F] 99 YEAR REMARKS 1993 Combined Cycle 20 181. HgA] 1. Eden Prairie. Pine Creek.390 3. Northville. [Deg.260 3. Ontario.Air-Cooled Condenser Installations STATION OWNER (A/E) Samalayuca II Power Station Comisión Federal de Electricidad Samalayuca. North Bay. Ltd. New York (Montenay Islip Inc. MN (European Gas Turbines Inc.0 63 1995 Methanol Plant A-4 . of Haverhill Haverhill. ) 9 101. UK (TBV Power Ltd.0 90 1998 Rumford Power Project Rumford Power Associates. Tucuman. South Wales.0 90 1998 Tiverton Power Project Tiverton Power Associates.) 100 596.215 4.) 150 1.) 10 83.999 5.5 59 1997 Zorlu Enerji Project KORTEKS Bursa. Ltd..0 49 1996 Mallard Lake Landfill Gas Facility Browning-Ferris Gas Services Inc.5 90 1997 Dighton Power Project Dighton Power Associates. Ltd. Saudi Arabia (Raytheon Engrs. Rumford.) 250 1.5 122 1996 Riyadh Power Plant #9 SCECO Riyadh. NV (Kiewit/Sargent & Lundy) 80 549. MA (Parsons Power Group. Dighton .637.800 5.0 50 1996 Barry CHP Project AES Electric Ltd.312 2. IL (Bibb & Associates Inc.) 4 x 107 4 x 966. Inc.065.A.0 99 1997 Tucuman Power Station Pluspetrol Energy. A. Turkey (Stewart & Stevenson International) 150 1.3 1995 Esmeraldas Refinery Petro Industrial Esmeraldas.5 50 1998 Coryton Energy Project InterGen Corringham. Ecuador (Tecnicas Reunidas.Air-Cooled Condenser Installations STATION SIZE STEAM TURBINE DESIGN OWNER MWe FLOW Back Pressure TEMP.150. S. Hanover Park.429 2.5 67 1998 El Dorado Energy El Dorado LLC Boulder. Inc. HgA] [Deg. & Const.750 16. (A/E) (1) [Lb/Hr] [In. ME (Stone & Webster Engineering Corp) YEAR REMARKS Combined Cycle Combined Cycle Combined Cycle (1200 MW Total) Combined Cycle (Supplied & Erected) Combined Cycle PAC SYSTEM® Combined Cycle (Supplied & Erected) Combined Cycle Combined Cycle Combined Cycle (Supplied & Erected) Combined Cycle A-5 . Tiverton. El Bracho.141 5.775 3.000 5. F] 15 123. S. RI (Stone & Webster Engineering Corp. England (Bechtel Power Corporation) 80 545. Barry. Argentina (Black & Veatch International) 60 442.900 3.400 3.5 87. Ltd. Inc.54 71.200 6.0 66 2001 350 1. Unit 3 Power Project Black Hills Generation. New York (Bechtel Power) Moapa Energy Facility Duke Energy Moapa. Gillette.000 TURBINE Back Pressure [In.000 4. Nevada (Duke/Fluor Daniel) Wygen 1.970 5.000 4.25 103 2001 Combined Cycle (1200 MW Total) (Supplied & Erected) Coal-Fired Plant 80 548. Goldendale. Washington (NEPCO) Athens Power Station PG&E Generating Athens.4 1999 Combined Cycle 25 277. Wyoming (Babcock & Wilcox) Hunterstown Power Project Reliant Energy Hunterstown.6 2000 Combined Cycle Cogeneration 150 1. Malaysia (Kawasaki Heavy Industry) Front Range Power Project Front Range Power Company Fountain. Mexico (Kawasaki Heavy Industries) Gelugor Power Station Tenaga Nasional Berhad (TNB) Penang. Colorado (TIC/UE Front Range JV) Goldendale Energy Project Goldendale Energy Inc.780 9.Air-Cooled Condenser Installations STATION SIZE OWNER MWe (A/E) (1) Millmerran Power Project InterGen / Shell Coal Toowoomba. Queensland.43 DESIGN TEMP. LLC Clark County.57 80 2000 Combined Cycle 110 678. Mexico (Bechtel International) University of Alberta Edmonton.690.718.000 3.477 3.266.790 6. Alberta.050. [Deg. Canada (Sandwell) Monterrey Cogeneration Project Enron Energía Industrial de México Monterrey. Guanajuato.183 5 90 2000 Combined Cycle (Supplied & Erected) 2x 200 2x 1.5 90 2000 Combined Cycle PAC SYSTEM® 3x 120 3 x 749.600 6. Australia (Bechtel International) Bajio Power Project InterGen Querétaro.6 90 2001 Combined Cycle (890 MW Total) A-6 . F] 88 1999 YEAR REMARKS Coal-Fired Plant 150 1. Pennsylvania (Black & Veatch) STEAM FLOW [Lb/Hr] 2x 420 2x 2.8 89.307. HgA] 5.15 59 1999 Gas-Fired Plant Cogeneration Combined Cycle Cogeneration 80 671.8 102 2000 120 946. 998.0 2004 Combined Cycle Cogeneration 350.000 4. F] 1. California (Utility Engineering) 358 Spalding Energy Center InterGen Spalding. HgA] [Deg.0 95 2004 WTE ( Wood-Fired Plant) 84. Alaska (Haskell) 55 Fibrominn Biomass Power Plant Fibrowatt LLC Benson. Minnesota (SNC-Lavalin) STEAM TURBINE DESIGN YEAR REMARKS FLOW Back Pressure TEMP.332 3. Mexico (Dragados) 3x5 Ft Wainwright CHP Plant U.000 3. California (University Mechanical) 72 El Encino CFE Chihuahua.100 6.52 87 2004 Combined Cycle 36.0 80 2004 Cogeneration 437.Air-Cooled Condenser Installations STATION SIZE OWNER MWe (A/E) (1) 350 Choctaw County Power Project Reliant Energy French Camp.000 4. Army Ft Wainwright. Utah (Shaw Stone & Webster) 3 Snowflake Pinnacle West Snowflake.690.12 49 2002 Combined Cycle 833.165 4.093 3.94 96.650 3. United Kingdom (Bechtel Power Corporation) 100 Jordan Rehab Power Station CEGCO Amman.552.500 5.S. Arizona (REM Engineering) 5 32nd Street Naval Station NORESCO.6 90 2001 Combined Cycle (890 MW Total) 1. San Diego. [Lb/Hr] [In.43 98.8 2003 Combined Cycle 1.422 8.0 72 2004 WTE NOTES: (1) Steam side of cycle only A-7 . LLC.501. Mississippi (Black & Veatch) 277 Otay Mesa Energy Center Calpine San Diego. Jordan (Doosan Heavy Industries) 200 Currant Creek Project PacifiCorp Mona.6 2004 Combined Cycle 3 x 68.47 74 2001 Combined Cycle 1.0 82. . Air-Cooled Condenser Installations Appendix A.2: SPX Cooling Technologies Reference List A-9 . . G ABB Baden Switzerland Afghanistan 101. G VEW / Schmehausen Germany 438 1977 MR. A AIR COOLED CONDENSERS Client Location Steam Load t/h Year Install. Type ESKOM / Grootvlei 6 South Africa 335 1978 MR.3 1995/1996 MR. G ISCOR Vanderbijlpark South Africa 150 1985 MR. Offenbach / Rye House Power Station Great Britain 852 1993 MR. G Indeck Energy. A = Multiple row condenser with aluminium fins page 1 of 8–DECEMBER 2004 See also our references lists for: Waste to Energy.SPX Cooling Technologies REFERENCE LIST POWER PLANTS AIR COOLED CONDENSERS INDIRECT COOLING SYSTEMS INDIRECT COOLING SYSTEMS Client Location Thermal Load MW Year Install. G ABB / PPC / Chania Greece 160 1993 SR.5 1987 MR. Type BBC Mannheim / TOUSS Power Station Iran 4 x 360 1984 MR. A = Single row condenser with aluminium fins MR. A Code : SR. A ESKOM / Kendal South Africa 6 x 895 1986/1992 MR. A Siemens KWU. Lowell USA 73 1991 MR. Industry. . G = Multiple row condenser with galvanised steel fins MR. G CRS Sirrine. G ENEL / Trino Vercellese Italy 2 x 266. Silversprings USA 55 1990 MR. G ABB Stal / Gas Edon Erica Netherlands 85 1995 SR. 5 1998 SR. . A Billings Generation / Montana USA 210 1995 MR. A Anaconda / ABB Power / Murrin Murrin Australia 98. A Electrabel / Gec Alsthom / Baudour Belgium 343 1998 SR. A Kepco / Halim Korea 132 1997 SR. Type ABB Stal / Gas Edon Klazienaveen Netherlands 85 1995 SR. G Edison / San Quirico Italy 180 1995 SR. A Fiat Avio / Coastal Habibullah / Quetta Pakistan 145 1997 SR. A = Multiple row condenser with aluminium fins page 2 of 8 – DECEMBER 2004 See also our reference list :Waste to Energy. G Centro Energia / FWI / Comunanza Italy 195 1996 SR. Elect. A ABB Stal / Pgem / Borculo Netherlands 38 1995 SR. G = Multiple row condenser with galvanised steel fins MR. A SR. A Centro Energia / Fwi / Teverola Italy 203 1997 SR. Industry. A Siemens / East. Crocket USA 275 1996 MR. A Bechtel. A Electrabel-Spe / TBL / Gent Belgium 351 1997 SR. A Electrabel-Spe / TBL / Brugge Belgium 572 1997 SR. A = Single row condenser with aluminium fins MR.SPX Cooling Technologies REFERENCE LIST POWER PLANTS AIR COOLED CONDENSERS INDIRECT COOLING SYSTEMS Client Location Steam Load t/h Year Install. A Sondel / Celano Code : Italy 185 1998 SR. / King's Lynn United Kingdom 330 1996 SR. A Mitsubishi Takasago / MHI Japan 325 1997 SR. A Mitsubishi / Jandar Syria 2 x 432 1995 SR. Mass.4 1999 MR. G EDF / Rio Bravo Mexico 516 2000 MR. G ABB Baden. Texas USA 4 x 255 2000 MR. G ABB Baden. USA 2 x 256 2000 MR. A = Multiple row condenser with aluminium fins page 3 of 8 – DECEMBER 2004 See also our reference list :Waste to Energy. CT USA 3 x 256 2000 MR. G ABB Baden / Enfield Great Britain 346 1999 MR. Japan / Chihuahua Mexico 450 1999 MR.SPX Cooling Technologies REFERENCE LIST POWER PLANTS AIR COOLED CONDENSERS INDIRECT COOLING SYSTEMS Client Location Steam Load t/h Year Install. G = Multiple row condenser with galvanised steel fins MR.A Kanagawa / Samukawa Pst Japan 75. Schweiz / Midlothian.1 1999 SR. G Babcock Borsig Power.2 Pst Japan 75. TX USA 2 x 256 2000 MR. G ABB Baden / Monterrey Mexico 2 x 244. A Kanagawa / Fujisawa No. Schweiz / Blackstone. Schweiz / Hays. .6 1999 SR. Type Thomassen Power Systems NL / Esenyurt Turkey 177 1998 MR. Oberhausen / Debrecen Hungary 127 2000 MR. G ABB Baden. A = Single row condenser with aluminium fins MR. G Enron / Stone&Webster / Sutton Bridge Great Britain 2 x 350 1999 SR. G Entergy / Mitsubishi / Damhead Creek Great Britain 2 x 370 2000 SR. G ABB Baden. A Code : SR.A Mitsubishi. Schweiz / Lake Road. Industry. Houston / Chehalis. A Calpine / Bechtel / Sutter USA 573 2001 SR. A Nevada Power Services.SPX Cooling Technologies REFERENCE LIST POWER PLANTS AIR COOLED CONDENSERS INDIRECT COOLING SYSTEMS Client Location Steam Load t/h Year Install. Nevada USA 657 2001 MR. Mass. A Electrabel / Alstom / Esch-s-Alzette Luxembourg 360 2001 SR. A Hyundai E. . Industry. G Parsons Energy. G Code : SR. A = Single row condenser with aluminium fins MR. Texas USA 2 x 255 2001 MR. USA 2 x 256 2001 MR.C. A = Multiple row condenser with aluminium fins page 4 of 8 – DECEMBER 2004 See also our reference list :Waste to Energy. G = Multiple row condenser with galvanised steel fins MR. Denmark / Elean Great Britain 100 2000 MR. A Edison / Jesi Italy 200 2001 SR. A EDF / Saltillo Mexico 230 2001 SR. APEX. UK / Shotton Great Britain 250 2001 MR. WA USA 490 2001 MR. Type FLS. G Babcock Borsig / Al Taweelah Abu Dhabi 1. G Zorlu Enerji / Bursa II Turkey 60 2000 SR. Switzerland / Bellingham. Schweiz / Midlothian.8 2001 MR. / Baria Vietnam 220 2001 SR. G ABB Baden. G Bechtel / Hsin Tao Taiwan 635 2001 SR. G ABB Alstom.000. A ABB Alstom. Industry. A Siemens Offenbach / Hagit Israel 350 2003 MR.3 2002 SR. A Utashinai / Hokkaido Japan 34. G KeySpan / Ravenswood.A.3 2003 MR. / Hermosillo Mexico 251.3 2004 MR.2 2002 MR. A = Multiple row condenser with aluminium fins page 5 of 8 – DECEMBER 2004 See also our reference list :Waste to Energy. G Zorlu Enerji / Bursa III Turkey 63 2003 SR. A Reliant / Sargent & Lundy / Big Horn USA 464 2003 SR. G = Multiple row condenser with galvanised steel fins MR. Type Babcock Borsig Power / Tarragona Spain 247. NY USA 278 2002 MR. G Sithe / Raytheon / Fore River USA 1 x 658 2002 SR.8 2002 SR. G Hydro / Sluiskil Netherlands 117 2003 SR. A Toshiba / Sanix Japan 298. A Sithe / Raytheon / Mystic USA 2 x 658 2002 SR. A Abener Energia S. G EDF / Rio Bravo III Mexico 515 2003 MR. A Abener / El Sauz Mexico 390 2003 MR. . A = Single row condenser with aluminium fins MR. G Code : SR.SPX Cooling Technologies REFERENCE LIST POWER PLANTS AIR COOLED CONDENSERS INDIRECT COOLING SYSTEMS Client Location Steam Load t/h Year Install. G CWEME / Zhangshan Unit 1 + 2 China 2 x 669. G Siemens. G = Multiple row condenser with galvanised steel fins MR. A Fisia Italimpianti / Accerra Italy 325 2004 MR. A Enipower / Snamprogetti / Mantova Italy 2 x 360 2004 SR. Industry.5 2004 MR. A EDF / Rio Bravo IV Mexico 515 2004 MR. G Genwest LLC / Silverhawk USA 742 2004 SR. NL / Mymensingh Bangladesh 297 2004 MR. A Nypa / GE / Sargent & Lundy / Poletti USA 490 2004 SR. A Aluminium Bahrain / Alstom / Alba Bahrain 2 x 525 2004 SR. G Endesa / Duro Felguera / Son Reus Spain 262 2004 SR. A Shanxi Pingshuo Meiganshi Power Generation / Shou Zhou China 2 x 157. A Enipower / Snamprogetti / Ferrera Italy 2 x 360 1 x 264 2004 SR. . Type Altek / Kirklarreli Turkey 97 2004 SR. A Shanxi / Yushe Unit 1 + 2 China 2 x 669. G Code : SR. A ICA / Fluor Daniel / La Laguna 2 Mexico 470 2004 SR. A = Single row condenser with aluminium fins MR. G Shanxi Huaze Aluminum / Hejin China 2 x 671 2004 SR.SPX Cooling Technologies REFERENCE LIST POWER PLANTS AIR COOLED CONDENSERS INDIRECT COOLING SYSTEMS Client Location Steam Load t/h Year Install.5 2004 MR. A = Multiple row condenser with aluminium fins page 6 of 8 – DECEMBER 2004 See also our reference list :Waste to Energy. G Shanxi / Xishan China 3 x 167 2006 MR. A Shanxi / Datong China 4 x 164 2006 MR. G Foster Wheeler / Teverola Italy 363 2005 SR. G Code : SR. A Shanxi Zhaoguang Electric Power / Huozhou 2 China 2 x 678 2005 SR.. / Zhenglan China 2 x 1321 2006 SR. A = Multiple row condenser with aluminium fins page 7 of 8 – DECEMBER 2004 See also our reference list :Waste to Energy. Industry. A Mitsubishi / Castelnou Spain 720 2005 SR. A Sun Ba / Toshiba / TCIC / Chang Bin Taiwan 502 2004 SR. A Astoria Energy / Shaw Group / Astoria USA 460 2005 SR. A Inner Mongolia Shangdu Power Co. Type Star Energy / Toshiba / TCIC / Fong Der Taiwan 2 x 502 2004 SR. A CWEME / Guijao Unit 1 + 2 China 2 x 678 2005 MR.SPX Cooling Technologies REFERENCE LIST POWER PLANTS AIR COOLED CONDENSERS INDIRECT COOLING SYSTEMS Client Location Steam Load t/h Year Install. A M Project Japan 107. . A Inner Mongolia / Fengzhen China 2 x 1317 2006 SR. A Transalta / Delta Hudson / Chihuaha III Mexico 326 2004 SR. G Shanxi / Wuxiang China 2 x 1332 2006 MR. Ltd.9 2005 SR. G = Multiple row condenser with galvanised steel fins MR. A = Single row condenser with aluminium fins MR. A Inner Mongolia Sangdu Power Co / Zhenglan 2 China 2 x 1321 2006 SR. G Shanxi / Baode China 2 x 330 2006 MR. A Code : SR.SPX Cooling Technologies REFERENCE LIST POWER PLANTS AIR COOLED CONDENSERS INDIRECT COOLING SYSTEMS Client Location Steam Load t/h Year Install. Type Shanxi / Yanggao China 2 x 147 2006 MR. G Hebei Guodian Longshan Power Plant / Longshan China 2 x 1325 2006 SR. G = Multiple row condenser with galvanised steel fins MR. A = Multiple row condenser with aluminium fins page 8 of 8 – DECEMBER 2004 See also our reference list :Waste to Energy. Industry. A = Single row condenser with aluminium fins MR. . A CWEME / Dalate China 2 x 1308 2006 SR. 3: Combined ACC Installations as of September 2003 A-11 .Air-Cooled Condenser Installations Appendix A. . 800 38.12 0.1 2.86 5.000 1.14 1 0.25 5 7 0.8 45 13. TransCanada Pipeline Ltd.067 0.16 44. Antwerpen BASF Antwerpen BASF.83 100.01 102.95 5.31 0.56 36.25 136.43 8.000.68 26.38 118.100 4 x 221.45 0.66 153.2 14.27 3.13 29.000 189.44 149.4 21 27 36 50 86.01 82.700 54.1 0.12 129.85 141.200 110.63 206.2 42. Schweiz GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA GEA Marley/BDT Marley/BDT Hamon GEA Marley/BDT GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA Marley/BDT Hamon Hamon Hamon Hamon Hamon Hamon GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Hamon GEA GEA Blohm & Voss KKK Pluspetrol Energy S.76 139.000 41.840 2 x 2. Austria / AGRO.046.320 22.28 75 Antwerpen Progil Antwerpen BASF Antwerpen 90.600 75.640 92. Abu Marley/BDT Dhabi Marley/BDT ABB Baden.85 Belco Belco Cochabamba Cochabamba Santa Cruz Mmammatsuve Morupule 1-4 Candiota Socamé Sonara Victoria Nipigon Kapuskasing North Bay Potter Edmonton Burnaby 62 4x33 2x160 15 30 30 20 25 10 10 5.200 190.39 2.2 2 x 930 21.53 4.5 4x100.7 8.1 90 8.43 8.85 133.85 139.10 32.4 Valparaiso .8 77 111.400 244.2 0.400 79.960 169. Antwerpen SERT / MVA Harelbeke FABRICOM / MVA Pont de Loup Uhde BASF.15 2.129 0.80 101.300 33.5 0.91 35.99 177.200 2.600 1.3 4 1.5 13 521.17 0.201.5 5.520 18.2 0.169 6 1.000 29.5 195.680.91 3. Hga F 1.I.180 44.48 100.25 0.38 4.29 5.8 6. Canada /Kwinana Western Mining Corp.6 8.91 8.5 2.411 0.86 5.68 114.800 68.8 0.45 139. InterGen / Shell Coal Chemserv.115 0.9 26 1..54 Service Date 2001 1987 1963 1980 1997 1971 1976 1980 2003 1969 1978 1990 1994 2000 1992 1992 1998 1967 1970 1972 1976 1976 1978 1979 1980 1985 1985 1989 1989 1996 1997 1997 1997 1998 2001 1985 1985 1976 1976 1976 1986 1986 1979 1982 1974 1979 1980 1990 1994 1994 1994 2000 2003 1995 1963 1975 Babcock Borsig / Al Taweelah.14 6.9 1.360 99.123 0.165 0.7 64.7 537.07 0.800 24.07 139. Botswana Power Corp.B. Austria / Chemie Linz Anaconda/ABB Power/Murrin Murrin Albatross Refinery Bayer / Shell Serete S. Potter Station Power Partnership University of Alberta Montenay ABB Kesselanlagen/Kezo/Hinwil Las Ventanas Turbinenfabrik J.53 12.200 59.183. TransCanada Pipeline Ltd.3 0.420 181. AKZ CEEE.900 4.1 0.700 18.204 14 10 118 22 1 9 58 6 6 2 1 13 12 29 9 16 348 56 214 42 20 20 18 41 11 127 260 6 494 7 4 4 50 72 72 53 82 35 20 17 1 0.37 126.000 47.2 0.54 4.3 0.15 0.140 4.93 119.67 3.5 8.28 156.300 5.700 140.500 28.200 68.48 123.800 68.221 0.5 150 2.500 277.1 82.2 1.200 14.07 0.86 141. Oschatz Oschatz.020 198.5 64 17. Antwerpen RMZ/Houthalen Electrabel-SPE/TBL/Brugge Electrabel-SPE/TBL/Gent Seghers/Indaver Electabel/GEC Alsthom/Baudour Thumaide/CNIM Ipalle Mc Lellan Mc Lellan Brefcon London Brefcon London Brefcon London Bophuthatswana Power Corp.5 2.960 14.68 112.85 155.000 19.1 0.29 1.9 20 18.480 46. Linz Chemserv.440 2 x 200.400 1.63 5.600 142.02 4. Elliott Energy Development Ltd.2 34.5 15.5 24.067 0.85 156.41 102.8 3.5 126 54 30.91 12. t/h lb/hr MWth MWe barA in.95 1.87 2.07 14.2 0.94 157. Brüssel BASF.E.57 38.2 0.760 223.48 13.07 2.53 121.000 57. Porto Allegre Polimex-Cekop Klöckner INA Procofrance Procofrance TransCanada Pipeline Ltd.85 122.500 430.6 10 764 11 6.40 8.A.28 0. Essen Siemens Siemens Österreich Bechtel.91 147.98 3.411 0.140 19.184 0.7 1.2 2 x 91.8 86.84 133.840 31.05 0.Combined ACC Installations as of September 2003 Vendor Customer Project/Site Country Steam Load Steam Load Condenser Load Turbine Capacity Operating PressurOperating PressureCondensing Temp.147.48 1.14 7.360 8.91 5.29 162. Antwerpen BASF.43 5.44 143.420 244.400 727.45 139.1 111.83 139.5 330.Nadrowski Buenos Aires Rosario Tucuman Abu Dhabi Afghanistan Argentina Argentina Argentina Argentina Argentina Argentina Arnoldstein Australia Australia Australia Australia Australia Austria Austria Austria Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Belgium Bermuda Bermuda Bolivia Bolivia Bolivia Bophuthatswana Botswana Brazil Brazil Cameroon Cameroon Cameroon Canada Canada Canada Canada Canada Canada CH Chile Chile Shell Geelong Pine Creek Millmerran 25.5 5.200 62.81 9.98 1.75 132.9 31 31 28.91 29.420 648 66 2 8 338 6 5 14 17 23 32 56 27 1.200 118.6 10 2x420 114.2 1 8 460 350 25 350 15 0. 85 139.91 885.91 5.07 6.153 0.55 32.20 29.2 0.6 46.023.000 60.152 4.7 30.91 7.640 60. France / Blois ABB Alstom.153 0.2 0.4 17.600 35.54 3.3 42 465 2 x 669.75 129.400 17.400 123. Delitzsch Shell Refinery Shell Refinery Burmeister & Wain Burmeister & Wain von Roll von Roll AEG Widmer u.85 129.57 158.34 15.16 0.7 28 51.800 102.135 0.100 51.6 20 26.3 2x46.2 0.2 0.8 10.85 119.600 32.5 1.28 139.83 124.3 10.85 139.40 47.720 7.94 125.5 2 0.85 130.91 5.91 5.400 37.3 62 8 14.540 67.6 11.98 129.85 139.18 0.53 59.GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT GEA Marley/BDT Marley/BDT GEA GEA Marley/BDT Marley/BDT GEA GEA GEA GEA GEA Hamon Hamon Hamon Hamon Hamon Hamon Hamon GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Methanex Chile Ltd.91 5.24 339. China State Power CWEME / Zhangshan Unit 1 + 2 Alstom.260 26.4 46.280 72.860 92.000 166.5 11.080 45.2 0.84 129.138 0.02 91.000 117.6 1.85 20 75 3 45 8 1 14 15 10 10 22.22 20 0. Nürnberg.1 0.200 33.22 1995 1980 1980 1980 1980 1981 1981 1981 1981 1981 2002 2003 2003 2003 1965 1965 1969 1969 1974 1974 1980 1981 1986 1994 1995 1996 1997 1997 1997 1998 1996 1958 1963 1966 1966 1966 1967 1969 1969 1969 1969 1970 1970 1971 1971 1971 1972 1973 1973 1974 1975 1977 1981 1982 1987 1997 1998 1999 2000 2001 2002 .115 1.61 6.85 139.145 0.6 50 27.38 4.72 10.44 114.4 35 75.15 0.13 0.53 5.52 4.700 160.400 1.5/18.9 30.31 4.4 12.780 67.660 16.120 30.5 23.83 139.13 4.800 49.1 0.800 30.320 25.880 77.2 27 1 2 0.4 21 11 10 13 15 8 113 49 10 23 49 20 32 18 18 33 18 6 160 1.2 0.49 132.4 14.500 22 7 5 7 5 21 8 7 18 11 27 301 866 40 5 9 9 9 15 2 13 17 15 47 30 8 30 11 11 36 26 35 47 33 10 20 7 13 10 14 97 20 2 x 46.400 22.55 139.28 4.600 27.6 3.72 4.62 133.16 0.4 33 12.320 110.15 0.0 17.5 0.22 114.6 23 72. Gobain-Pechiney CFR Haucancourt Stone & Webster CRF La Mede Linde Shell Foster Wheeler Technip Tunzini Technip Raffinerie des Flandres Rhone Progil Stone & Webster Oschatz.2 30 0.100 35.02 5.78 3.3 12 175 76 15.156 0.5 0.53 5.67 140.200 47.940 61.08 131.2 0.28 128.85 139.62 135.43 5.43 4.060 23. 1 Frederica Frederica Nyborg Nyborg Novopan Nyborg Nyborg Esmeraldas Ebange Ebange Port Jerome Port Jerome Port Jerome Port Jerome Toulouse Total Chimie Naphta Chemie Petit Couronne SNPA Gonfreville Ugine Kuhlmann Toulouse Zuid Chemie ATO Chimie Cabot Chile China China China China China China China China China China China China Delitzsch Denmark Denmark Denmark Denmark Denmark Denmark Denmark Denmark Denmark Denmark Denmark Denmark Denmark Denmark Denmark Denmark Ecuador France France France France France France France France France France France France France France France France France France France France France France France France France France France France France France 33.5 15 1.000 58.99 5. France / Maubeuge Alstom Paris.04 2.1 3.91 4.85 131.25 0.6 14 14 22.860 2 x 102.600 112.300 33.520 50.91 797.85 139.4 2x9.91 5.920 44. AEG AEG AEG AEG Borsig AEG AEG AEG AEG Zhenhai.2 0.84 2.87 59. SA GEC Alstom / DINAN CNIM / Monthyon ABB Alstom.400 385.98 129.000 167.7 7 10.91 4.34 0.360 23.460 136. Francaise de Raffinage Esso Refinery Tunzini St.57 124.95 5.17 0.85 120. France / Douchy Cabo Negro Shanghai Shanghai Shanghai Shanghai Nanking Nanking Nanking Nanking Nanking Datong No.95 3.2 0.8 2.2 27.5 16 21.5 15 20.52 4.000 68.1 0.5 150 31.180 36. France / Villers St.540 15.02 5.75 139.48 103.45 29.200 102.2 0.472.204 0.55 139.12 131.200 88.000 2 x 1.000 37.91 5.24 47.600 110.91 5.98 126.33 140.2 0.4 31. Ernst Kommunekemi Blohm & Voss/Schwerin ABB Turbine/Fichtner/Gera-Nord Schworerhaus/Hohenstein ABB Turbinen/Frankfurt-Oder Linde/BASF Ludwigshafen Est-Geko/HKW Meuselwitz Lentjes Energietechnik/Wurzburg Petro Industrial SOLLAC SOLLAC Esso Refinery Esso Refinery Esso Refinery Comp.99 5.72 3.300 330. Essen Technip Raffinerie des Flandres Technip Raffinerie des Flandres Armand Interch.05 3.5 28 16.4 20.5 73 50.100 61.600 159.204 3.05 4.85 149. Marley/BDT Paul Marley/BDT Alstom Paris.91 3.57 129.000 45.000 27.3 7.85 139.5 74.135 0.153 0.55 339.16 0.9 16.880 32.080 70.85 125.0 56 40 53.6 11.47 139.117 1 0.52 4. 16 35. France / Dunkerque Wirus Werke Dynamit Nobel AG Kohlenbergwerke Arenberg-Bergbau Geha-Möbelwerke Vereinigte Papierwerke Berlin Hochhaus Le Corbusier Bochumer Verein Pfaff-Werke Technische Hochschule Horremer Brikettfabrik Vereinigte Glanzstoffwerke Daimler Benz AG Daimler Benz AG Piasten Schokoladenfabrik Portlandzementwerke Kraftwerk Hausham Roser-Feuerbach Volkswagenwerk AG Volkswagenwerk AG Ingenieurschule Duisburg Ingenieurschule Dürrwerke Daimler Benz AG DEW / Werhohl NEAG Röhm & Haas Kübel.000 17.07 5.000 44.46 111.21 2.46 102.77 102.000 22.36 44.42 111.83 99.200 22.5 18 6 22 79.000 12.700 7.586 92.600 3.075 0.43 442.66 2.36 2.000 22.5 1.09 0.77 95.95 129.900 13.800 79.5 12 4.5 6.38 50.400 25.02 2002 2003 2003 1939 1940 1950 1953 1954 1955 1956 1957 1957 1958 1958 1958 1959 1959 1959 1960 1960 1960 1960 1960 1960 1960 1961 1961 1961 1961 1962 1962 1962 1963 1963 1963 1964 1964 1965 1965 1965 1965 1965 1965 1965 1965 1965 1965 1965 1965 1966 1966 1966 1966 1966 1966 1966 1966 1966 1967 1967 1967 Gütersloh Friedland Marienstein Bottrop Hövelhof Heroldsberg Gütersloh Berlin Bochum Kaiserslautern Karlsruhe Köln Kelsterbach Sindelfingen I Sindelfingen I Forchheim Gütersloh Hausham Stuttgart Wolfsburg Wolfsburg Darmstadt Ratingen Sindelfingen Celle Worms Brunsbüttelkoog Darmstadt Ingolstadt KW Ibbenbüren Wesseling Bruchsal Dormagen Kalscheuren Kassel Kassel Ludwigshafen Wesseling Wesseling Wolfsburg Wolfsburg 1 3 x 1. Rosenheim Koppers-Wistra Berliner Stadtreinigung Shell Raffinerie Vereinigte Kesselwerke C.46 99.43 3.065 0.6 40 3.5 0.59 110.34 14.77 106.700 26.1 5.29 10 13 12 8.700 8.8 3.19 40 2x4.5 6 2x110 130 2.1 4.9 0.01 106.21 5.840 26.220 12.7 6 1.075 5 0.960 7.95 44.03 0.5 5 10 20 15.43 2.2 12 11.065 0.8 28 71 84 7 3 6 13 10 2 x 16 6 16 6 5 4 5 8 7 0.02 104. Freudenberg AEG-Kanis / Cabot Holzwerke Bähre Metallwerke Bähre Zeche Friedrich Heinrich Schulte Frisia Raffinerie Rheinische Olefin-Werke AG France France France Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany 19 36. Sodafabrik Union Rheinische Kraftstoff AG Rheinische Olefin-Werke AG Volkswagenwerk AG Volkswagenwerk AG Kübel.08 0.5 4 26 2 3 2 1 2 8 3 13 5 9 12 4 14 51 4 2 x 110 84 2 0 0 12 6 8 8 6 2 6 7 197 3 3 49 13 20 27 26 2 x 4.8 4 75 20 31.075 0.67 177.08 0.66 2.700 39.62 2.117 0.57 2.5 41.77 102.66 2.07 2.77 114.08 1.3 7.000 55.5 0.01 139.000 28.09 0.5 11 0.5 304 4.5 5.055 0.600 26.7 2x16 10 25 10 7 6.800 242.105 0.76 1.818 88.320 88.08 0.36 114.8 5 0.95 1.5 0.77 90.29 73.3 1.63 42.66 20.42 103.5 3.02 111.6 3.85 85.800 165.546 22.76 324.92 2.5 each 7.000 15.48 2.05 11.21 1.21 93.6 2.8 44 110 130 10.36 32.6 11 2.63 2.09 2.900 44.160 770 418 40.860 15.087 0. France / Haguenau Marley/BDT CNIM / France Lasse Marley/BDT GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT GEA GEA GEA Marley/BDT GEA GEA Marley/BDT GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT Marley/BDT GEA GEA GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA CT Environment.02 15 2.2 0.79 104.89 30.6 3.200 2 x 242.2 0. Worms CONDEA Ytong Grube Messel Shell Raffinerie Preussag AG Union Rheinische Kraftstoff AG Daimler Benz AG Erdölchemie Degussa Chemie Volkswagenwerk AG Volkswagenwerk AG Badische Anilin.45 2.35 0.15 0.000 7.36 1.6 2.07 0.47 106.85 104.3 3.82 324.6 40 3.u.66 64.000 25.300 668.07 0.Marley/BDT SMITOM.24 2.53 111.1 0.71 2.96 14.21 147.4 150 106.28 119.5 4 3 1.2 0.5 3 1 28 5.400 18.075 0.200 48.46 104.000 286.000 2 x 10.420 55.29 2.058 0.000 69.387 15 1.24 44.07 0.77 106.91 2.79 59.09 0.400 9.1 1.83 120.000 6.114 0.238 22.5 2.19 18.68 106.93 10.79 2.800 6.000 44.5 0.000 23.1 25.5 11 2 0.000 34.1 2x40 48 104.600 13.560 96.43 10 11.42 104.6 38 2x1.37 2.21 2.2 0.1 0.400 13.8 0.48 2.088 0.02 111.36 1.60 1.10 2.25 9 40 48 Bad Godesberg Berlin Godorf MVA Hagen Weinheim Düsseldorf Emden Godorf .540 2 x 35.5 0. Worms Aicher.08 1.29 3.05 0.46 139.07 2.560 8.36 2.7/10 5.042 0.100 16.600 29.76 2.92 2.54 109.77 116.100 11.5 0.09 0.19 472.36 3.940/22.91 1.076 1.5 20 8 13.3 7.075 0.000 286.01 106.08 0.08 0.400 174.41 22.62 9.7 16 3.44 38.800 10.300 12 23 16 4 5/6. Beeckerswerth Thyssen AG Stadtwerke Solingen Marathon RMV Benze Piasten Schokoladenfabrik WMF Milchzentrale Daimler Benz AG Stadtwerke Kassel CONDEA BBC GHH von Roll Toyo Engineering.53 73.6 0.08 0.53 35.000 286.7 1.660 4.5 2x57 12 137 20.5 1 1.95 5.000 66.000 4.1 0.126 0.5 1.65 44.72 442.04 324.09 158.32 0.6 2x2.32 0.076 0.85 5.324 6 0.3 30 7 34 25. Japan Toyo Engineering.91 44.080 28.8 2x66.880 44.5 0.55 50 29 12 2.7 2x13 2x77.29 29.75 114.24 5.11 114.05 139.000 11.32 0.72 2.11 129.9 5.800 89.600 2 x 170.000 63.16 2.3 1.4 2 x 24 2 x 18.2 58.30 103.05 67.77 114.4 1.126 0.078 3.5 5 0.36 2.09 0.670 11.89 11.32 0.02 2.1 15 0.240 22.500 2 x 125.5 2x11 12 8 40 48 43 2.7 2x3.14 2.5 1 2.72 44.220 2 x 104.5 0.000 25.45 10.200 220.2 10.28 158.83 157.5 31. Japan Toyo Engineering.616 5.1 0. Japan Toyo Engineering.43 10. Uentrop Caliqua Terry GmbH Gebr.400 301.83 123.300 68.2 1. Aicher.29 2.5 67.28 2.53 44.29 295.000 15.6 6.26 29.89 295.29 4.2 0.28 111.34 147.000 7.13 79.4 13 5 2.41 158.95 9.3 6 100 30 3 31.8 23 22 7 36 20 20 11 23 3 3 11 19 5 22 16 1 20 13 3 2 x 47.660 75.79 44.1 2x47.3 17.1 2x15.62 70.2 0.500 77.800 2 x 41.480 660 13.1 0.100 44.17 0.72 3.400 165.29 29.800 35.86 44.GEA Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA GEA GEA GEA GEA Marley/BDT GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA Stadtwerke Darmstadt Stadt Iserlohn Dillinger Hütte Saline Ludwigshafen Papiermühle Stadtwerke Bremen Stadtwerke Bremen Holtkamp Thyssen AG Glanzstoff AG.1 10 2 75 4 40.63 2.320 69. Köln Holzwerke Osterwald Wirus-Werke Caliqua Grüner Bräu Esso Gesellschaft f.1 55.45 9.76 457.580 80.000 8.85 126.040 129.200 7. Japan Toyo Engineering.4 20 16 3.4 0.91 32.93 139.95 3.34 2.000 8.36 0.860 38.000 35.52 4.81 9.5 20 110 130 11.43 103. Kernforschung BASF Ludwigshafen Erdölchemie BASF Ludwigshafen BASF Ludwigshafen BASF Ludwigshafen Rheinstahl Hattingen Thyssen AG.58 620.31 0. Japan Toyo Engineering.800 55. Worms Du Pont.5 1 2 1269.53 88.220 122.5 35 5 4 16.85 123.43 17.86 106.72 3.140 2 x 28.4 0.000 242.32 0.83 133.5 20 3.400 44.48 3.43 2x24 2x18.960 77.300 44.100 43.5 19.9 36.15 3.5 15.000 6.09 158.800 26.290 67.11 123.11 123.95 30.63 9.09 114.03 158. Japan Stadtwerke Frankfurt Stadtwerke Oberhausen Lurgi / BEB GHH / Rottka Stadt Hagen KHD.600 11.6 31.5 2 x 57 8 89 13 13 10 2 38 24 13 71 84 7 32 19 8 2 3 2 4 17 6 2x9. Köln Siemens Werke AG Siemens Werke AG Hoechst Volkswagenwerk AG Volkswagenwerk AG Deutsche Marathon Petr.82 29. GmbH AEG Kanis / Hamburg VKW / MVA Iserlohn Kübel.34 11 1.860 66.53 59.346 2 x 52.126 15 10 20 0.5 1 3 21 2.1 0.7 2 x 13 2 x 77.2 2x4.95 442.72 5.8 35.600 69.720 14.57 177.410 110.3 1.02 104.66 2.09 157.400 74.760 2 x 146.91 4.000 4.45 14.44 129.380 11.29 29.5 10 1 1.3 34.83 158.45 9.84 1967 1967 1967 1967 1968 1968 1968 1968 1968 1968 1968 1968 1969 1969 1969 1969 1969 1969 1969 1969 1969 1969 1969 1969 1969 1970 1970 1970 1970 1970 1970 1970 1970 1971 1971 1971 1971 1971 1971 1971 1971 1971 1971 1971 1971 1971 1971 1971 1971 1972 1972 1972 1972 1972 1972 1972 1972 1972 1972 1973 1973 1973 .26 590. Holzindustrie Inden Darmstadt Fürth Ingolstadt Karlsruhe Ludwigshafen Worringen Burghausen Duisburg Einbeckhausen Forchheim Geislingen Karlsruhe Sindelfingen Brunsbüttelkoog Daimler Benz AG Rheinstahl Henrichshütte Stadtwerke Landshut Brigitta Elverath Brigitta Elverath Münchsmünster Wolfsburg Wolfsburg Industriewerke Hamberger Oberhausen Rosenheim Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany 30.09 158.620 22.45 9.300 20 13 2 0 4 65 19 2 20 8 3 1 6 1 49 3 26 2 x 66.28 105.5 0.400 6.15 0.126 0.400 26.15 9. 760 12.02 5.7 6.29 0.54 3.77 129.77 106.55 80 54 50 10.85 Biebesheim Bielefeld Bodelshausen Herten Landshut Pforzheim Seitz Filter 139.54 1358.91 115.200 5.4 5 50 3.53 73.07 13. Pauli Schmidt'sche Heißdampf.37 156.000 17.9 1.5 7 0.22 3.8 20 5 96.89 29.000 13.31 88.562.83 106.07 0.12 0.900 70.8 58.320 297.000 23.57 679.5 5 0.8 2.23 4.68 9.160 44.67 157.37 121.680 11.34 44.91 191.25 50.76 147.92 5.000 66.12 133. Ernst Stadtwerke Landshut Stadtwerke Pforzheim AEG GHH / Henrichshütte.17 0.000 2.86 2.3 0.5 16.31 103.1 6 2.95 206.7 20.9 3.68 14.000 12.58 14.140 130.25 0.29 50.100 36.580 21.00 109.28 121.19 7.000 11.500 53.100 1.20 14.15 15 1 2.77 5.58 44.63 2.28 135.53 2.200 89.000 154.600 92.100 29.420 211.200 13.5 1.37 EC-Worringen MVA Bamberg MVA Darmstadt MVA Neunkirchen Neag 114.91 8.36 546.6 2 2x74.820 11.400 2 13 4 459 13 63 27 9 2 2 13 3 62 62 4 2 52 35 32 7 38 6 52 39 16 13 11 10 10 5 2 1 96 21 23 19 1 35 5 3 4 9 7 4 4 26 87 6 45 8 39 4 21 16 3 32 2 38 13 0 8 330 12 0.5 24.1 96.000 215.000 110.420 13.920 4.940 45.7 59.6 135 10 70 12. Köln Omnical Thyssen Cabot.000 118.7 1.3 0.7 60 6 32.82 236.2 1.19 114.53 324.85 139.38 3.38 5. Uentrop Linde AG Wester GmbH Südhessische Gas-u.2 0.2 3.83 Gießen Hattingen 149.29 147.200 118.800 17. Worms SSK von Schaewen VKW / Behring Marburg Du Pont.000 22.760 129.5 0.300 33. Hanau Siemens / Globus Dr.5 32 35 30 1 54 8.940 132.000 27.85 155.45 102.08 18.420 13.68 206.29 29.5 0.12 46 0.41 1973 1973 1973 1974 1974 1974 1974 1974 1974 1974 1975 1975 1975 1975 1975 1975 1975 1975 1975 1975 1976 1976 1976 1976 1976 1976 1976 1976 1976 1976 1976 1976 1977 1977 1977 1977 1977 1977 1977 1978 1978 1979 1979 1979 1979 1980 1980 1980 1980 1980 1980 1980 1980 1980 1980 1981 1981 1981 1981 1981 1982 121.000 52.63 88.610 176.820 7.400 30.9 9.5 15.5 5 5 3 1.2 6.386 26.000 8.31 1.400 77.Wasser AG Saarberg Fernwärme GmbH Mobil Oil VKW / MVA Krefeld AKZO.50 103.6 0.7 0.GEA Marley/BDT Marley/BDT GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA GEA GEA Marley/BDT Marley/BDT GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA GEA GEA GEA GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT GEA GEA Marley/BDT Marley/BDT Marley/BDT GEA Stadtwerke Landshut Lurgi / BEB Grefrath Velour HKG Hamm Uentrop Degussa Chemie Babcock / Krupp VKW / MVA Göppingen VKW / MVA Kiel Du Pont.43 53.200 132.67 191.9 81 60 24 20.21 38.92 5.54 8.3 2.5 1 11 1 0.1 5 5.1 7 7 0.780 178.95 44.800 45.76 649.800 110.85 Bremen Karlsruhe 135.15 35.2 15 8.12 0.7 2. Hohner AG Vereinigte Kesselwerke Refuse incinerationsanlage AEG Kanis Glasfabrik Heye Stadt Bremerhaven Borsig / Ruhrgas PWA Stockstadt Preussag Siemens Werke AG Thyssen Rheinstahl Technik Widmer und Ernst / MVA Hamburg Babcock /Mannesmann Stadtwerke Frankfurt Lurgi / BEB Widmer und Ernst / MVA Fürth Borsig / Ruhrgas Kübel.29 3.47 0.580 7.5 13.79 29.000 44.01 143.260 6.08 0.34 206.85 Bad Godesberg .1 3.43 442. Uentrop Degussa Krantz Wärmetechnik Matth.05 3.56 20.5 8 1.5 1.5 1.5 0.8 5.63 12 5.63 147.15 44.920 24.36 2.440 33.1 1.76 31.18 3.88 6.5 22 23 0.5 710 20 98 42 13. Kassel HAVG MVA Bielefeld Schlotterer Widmer u.000 211.6 11.460 44. Hattingen Klingele Goepfert & Reimer / v Stadtwerke Bremen Raschka für Kläranlage BBC Berlin / MVA Krefeld Siemens VEBA-Oel MVA Bonn KKW Schmehausen Werk Kalscheuren Fürstenfeldbruck Trossingen Wuppertal Wuppertal Brigitta Elverath Wupperverband Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany 2.000 1.3 20 0.400 2 X 163.10 5.200 71.18 3 0.1 6 6 40.75 139.15 76.5 0. Marley/BDT Widmer & Ernst / MVA Ingolstadt Marley/BDT Technische Werke Ludwigshafen Babcock Krauss Maffei Imperial / Marley/BDT MPA Burgau Marley/BDT Standard Messo / MVA Stapelfeld GEA Omnical GEA Volz Holzwerke GEA von Roll GEA SW Würzburg GEA Megal Marley/BDT BBC Mannheim / MVA Geiselbullach Marley/BDT BBC Mannheim / MVA Neustadt GEA Zweckverband Hamm Deutsche Babcock Anlagen AG / Marley/BDT MVA Leverkusen Marley/BDT Stadtw. Frankfurt / MVA Frankfurt GEA SW Marktoberdorf GEA SVA Schwabach GEA SVA Schöneiche Marley/BDT Blohm u. Voss / MVA Pinneberg Marley/BDT BASF, Münster GEA von Roll GEA Steinmüller GEA Bremer Wollkämmerei Marley/BDT Märkischer Kreis / AMK Iserlohn Marley/BDT Blohm und Voss / MVA Beselich Marley/BDT Bayer, Uerdingen GEA Heye Glas GEA Stadtwerke Landshut GEA MAN GHH GEA MAN GHH GEA MAB Lentjes Marley/BDT MBA Bremerhaven Marley/BDT Schlotterer Marley/BDT Rütgerswerke Marley/BDT Chemische Fabrik Budenheim Marley/BDT Oberrheinische Mineralölwerke GEA ABB GEA Esso AG GEA Reining Heisskühlung Hoesch GEA Rohrbach Zementwerk Marley/BDT ABB / BASF Marley/BDT Siemens / MHKW Weissenhorn Marley/BDT Pfleiderer Marley/BDT Gnettner Marley/BDT Spillingwerk GEA BASF GEA Heye Glas Marley/BDT Siemens / MVA Schwandorf Marley/BDT Turbon Tunzini / Sophia Jacoba Marley/BDT Blohm und Voss / Hornschuh Marley/BDT Rauschert GEA STEAG AG Marley/BDT ABB Nürnberg / AVA Augsburg Marley/BDT Zell- u. Papierfabrik Rosenthal Marley/BDT B S R, Berlin Marley/BDT ABB Nürnberg / AVA Augsburg GEA ABB/Egger GmbH GEA Siemens. Erlangen GEA Siemens Marley/BDT ABB Nürnberg / AVA Augsburg Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany 26.3 18 12 8 4 3 54 51 50.5 33 26 72.4 70 25 12 21.4 15.8 31 12.6 46 23.5 30 53 6.2 4.5 7.4 13 2x22 2x16 47 42 12 4 2.7 0.42 15.1 75 2.1 28 52.2 38 20 6 3 152.5 17 120 13.2 8 0.56 76.7 100 27.3 21 9 39 27 26 56 57,860 39,600 26,400 17,600 8,800 6,600 118,800 112,200 111,100 72,600 57,200 159,280 154,000 55,000 26,400 47,080 34,760 68,200 27,720 101,200 51,700 66,000 116,600 13,640 9,900 16,280 28,600 2 X 48,400 2 X 35,200 103,400 92,400 26,400 8,800 5,940 924 33,220 165,000 4,620 61,600 114,840 83,600 44,000 13,200 6,600 335,500 37,400 264,000 29,040 17,600 1,232 168,740 220,000 60,060 46,200 19,800 85,800 59,400 57,200 123,200 17 12 8 5 3 2 35 33 33 21 17 47 45 16 8 14 10 20 8 30 15 19 34 4 3 5 8 28 21 30 27 8 3 2 0 10 49 1 18 34 25 13 4 2 99 11 78 9 5 0 50 65 18 14 6 25 17 17 36 0.12 0.1 0.2 0.09 1.5 1.5 2 0.12 0.075 0.13 0.12 0.18 2 0.5 17 1.5 1.8 0.2 11 0.3 0.19 0.21 2.7 0.16 1.05 0.1 0.12 0.137 3.5 0.19 0.47 2.3 0.17 0.06 2 0.2 0.2 1.1 0.123 0.2 0.15 6 1.8 1.4 0.185 0.1 0.12 3.5 5 0.3 0.15 8.2 3.5 29 2.7 0.25 0.117 0.15 0.12 3.54 2.95 5.91 2.66 44.29 44.29 59.05 3.54 2.21 3.84 3.54 5.31 59.05 14.76 501.94 44.29 53.15 5.91 324.79 8.86 5.61 6.20 79.72 4.72 31.00 2.95 3.54 4.05 103.34 5.61 13.88 67.91 5.02 1.77 59.05 5.91 5.91 32.48 3.63 5.91 4.43 177.16 53.15 41.34 5.46 2.95 3.54 103.34 147.63 8.86 4.43 242.11 103.34 856.25 79.72 7.38 3.45 4.43 3.54 121.37 114.83 139.85 111.02 1982 1982 1982 1982 1983 1983 1983 1983 1984 1984 1984 1985 1985 1985 1986 1987 1987 1987 1987 1988 1988 1988 1988 1988 1988 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 1990 1990 1990 1990 1990 1990 1990 1990 1990 1991 1991 1991 1991 1991 1991 1992 1992 1992 1992 1992 1993 1993 1993 1993 Ewersbach Friedenweiler Kempten Waidhaus 121.37 104.46 124.22 121.37 135.85 25 40.74 5 3.8 139.85 156.45 137.87 141.78 131.57 114.83 121.37 126.07 137.87 88.81 133.75 96.68 139.85 139.85 122.25 139.85 129.28 MVA Darmstadt RZR Herten IM-II 18.3 Germersheim MVA Landshut Rostock Rostock RZR Herten SM II Brilon Ingolstadt 1 BASF KW Nord Germersheim 50 11 136.87 114.83 121.37 Kaiserstuhl 47 156.45 129.28 Brilon II Burgkirchen Kempten 12.5 12.7 149.12 120.47 129.28 121.37 Marley/BDT MAN GHH / GSB Ebenhausen Marley/BDT Krupp Stahl, Bochum Rauma, Düsseldorf / BASF Marley/BDT Ludwigs. Hamon ABB/PPC/Chania GEA ABB GEA AMK GEA ABB GEA ABB ESP Heizwerke GmbH/ SulzbachMarley/BDT Rosenberg GEA Hornitex GEA ESP GEKO GmbH GEA ZSVM GEA ABB Marley/BDT ML Ratingen / MVA Offenbach * Marley/BDT GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Blohm + Voss / SAVA Brunsbüttel * Rettenmeier Siemens KWU / AEZ Kreis Wesel EAG Krefeld Siemens KWU / SBA Fürth * Stadtwerke Kiel / MVA Kiel Deutsche Babcock Anlagen, Marley/BDT Oberhausen / VERA, Hamburg * GEA ABB Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA ML Ratingen / MHKW Pirmasens * ESP GEKO / HKW Dresden ESP GEKO / HKW Feldberg Addinol, Osterrode / KRUMPA Rettenmeier Babcock Kraftwerks-technik, Berlin Marley/BDT / Brand-Erbisdorf Marley/BDT Marley/BDT GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA Marley/BDT GEA GEA Marley/BDT GEA Marley/BDT GEA Marley/BDT GEA LEG Lurgi Entsorgung / Neunkirchen ETT Bünde / Günzburg Horn ANO Bremen HKW Glückstadt MVA Stapelfeld EST-EABG / Steinbach Babcock SIK / Eisenberg AE Energietechnik, Wien, Austria / T A. Lauta Alstom, Nürnberg / Zolling Alstom, Nürnberg / Landesbergen Kraftanlagen München / MHKW Mainz Rhone Poulenc Babcock Borsig Power, Oberhausen / Debrecen MSEB/Siemens Hitech Carbon EID Parry, India / Chennai Lurgi for Pertamina Blohm+Voss, Hamburg, Batam, Indonesien Stork Boilers BBC Mannheim / TOUSS Power Station AEG Kanis Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Germany Greece Hungary India India India Indonesia Indonesia Iran Iran Iran 32 16.5 2.92 154.5 72 51 161 71 18.8 25 21 3 41 34 14 24 75 75 47.2 20.5 15 43 65.1 29 20 9.6 2 x 24 33 19.6 2.2 50 40 40 20 6.5 24 68.73 61.5 61.5 17 16 127 2x508 30 16 28.3 26.1 60 4 x 360 9.1 70,400 36,300 6,424 340,000 158,400 112,200 354,200 156,200 41,360 55,000 46,200 6,600 90,200 74,800 30,800 52,800 165,000 165,000 103,840 45,100 33,000 94,600 143,220 63,800 44,000 21,120 2 X 52,800 72,600 43,120 4,840 110,000 88,000 88,000 44,000 14,300 52,800 151,206 135,300 135,300 37,400 35,200 279,400 2 X 1,117,600 66,000 35,200 62,260 57,420 132,000 4 x 792,000 20,020 21 11 2 100 47 33 104 46 12 16 14 2 27 22 9 16 49 49 31 13 10 28 42 19 13 6 31 21 13 1 32 26 26 13 4 16 44 40 40 11 10 82 657 19 10 18 17 39 932 6 0.21 1.3 0.19 130 0.18 0.11 0.116 0.143 0.2 0.1 0.12 0.18 0.143 0.12 0.12 0.2 0.1 0.18 0.138 3.5 0.2 0.175 0.11 1.2 0.2 0.1 0.2 0.19 0.096 1.1 0.1 2.3 5 0.3 1.5 0.25 100 0.1 0.1 0.15 0.2 0.25 0.28 0.226 2.8 0.2 0.45 1 0.27 9.2 6.20 38.38 5.61 5.31 3.25 3.43 4.22 5.91 2.95 3.54 5.31 4.22 3.54 3.54 5.91 2.95 5.31 4.07 103.34 5.91 5.17 3.25 35.43 5.91 2.95 5.91 5.61 2.83 32.48 2.95 67.91 147.63 8.86 44.29 7.38 2952.60 2.95 2.95 4.43 5.91 7.38 8.27 6.67 82.67 5.91 13.29 29.53 7.97 271.64 141.78 1993 1993 1993 1993 1994 1994 1994 1994 1994 1995 1995 1995 1995 1995 1995 1996 1996 1996 1996 1996 1996 1997 1997 1997 1997 1998 1999 1999 1999 1999 2000 2000 2000 2000 2000 2001 2003 2003 2003 2003 1976 2000 1992 1997 2001 1983 1993 1976 1983 1987 137.87 135.85 118.26 120.16 127.59 139.85 114.83 121.37 135.85 127.59 121.37 121.37 139.85 114.83 135.85 126.33 Ingolstadt Iserlohn Köln Velsen 56 Beeskow Hagenow Schwabach Ulm 15 Wilburgstetten Böblingen 12 139.85 134.81 118.26 139.85 114.83 139.85 137.87 113.35 114.83 Ullersreuth/Gaildorf 2 x 10 Hornitex 24.4 156.45 149.12 114.83 114.83 129.28 139.85 149.12 153.93 144.79 139.85 112.07 Petrochemie f. SICNG Uran Hitech Carbon 2x120 6 Sugar Mill 152.43 NPC Shiraz 3 GEA GEA GEA GEA GEA GEA GEA Marley/BDT GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Hamon Hamon Hamon Hamon Hamon Marley/BDT Hamon Hamon Hamon GEA GEA GEA GEA GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT GEA Hamon GEA GEA GEA GEA Marley/BDT Marley/BDT GEA GEA Marley/BDT Marley/BDT GEA Marley/BDT Hamon GEA Marley/BDT Marley/BDT Marley/BDT Tavanir/Siemens Skodaexport/1.Brünner Maschine ABB Siemens Trepel ABB Alstom Siemens, Offenbach, Hagit S.M.T. S.M.T. Prada Philips Carbon Black Philips Carbon Black Cementerie Calabro Pirelli De Nora von Roll von Roll von Roll Cementerie Calabro Columbian Carbon AMOCO Industria Petroli Chemi Foster Wheeler Edison/San Quirico Centro Energia/FWI/Comunanza Centro Energia/FWI/Teverola Sondel/Celano Edison/Jesi Fisia Italimpianti / Italy for Accerra Enipower/Snamprogetti/Ferrera NSC/Iisuka City Mitsubishi/Takasago Jordan Electric Authority Jordan Electric Authority AEG Kanis Fuji Electric Jordan Electric Authority Kellog London Ewbank and Partners Hildebrand UHDE, Dortmund UHDE, Dortmund ARBED Electrabel/Alstom/Esch-S-Alzette Tamatave Refinery JGC Corp./Shell JGC Corp./Shell JGC Corp./Shell Petronas, Malaysia / Kuantan Petronas, Malaysia / Kuantan Tenaga Nasional Berhad Comisión Federal de Electricidad ABB Baden, Schweiz / Monterrey Mitsubishi, Japan / Chihuahua InterGen EdF, France / Rio Bravo EDF/Saltillo Enron Energia / Tractebel EdF, France / Rio Bravo III EdF, France / Rio Bravo IV Abener, Spain for El Sauz Gilan Iranshahr Ghom Huntstown Ramat Hovav Hagit Trasimeno Trasimeno Lucane Bologna Livorno Bologna Lucane Cremona Rho Porcari Breda/Mailand Breda/Mailand Zarqa Refinery Zarqa Hussein 7 Dudelange Tamatave Bintulu Bintulu Bintulu Gelugor Samalayuca II Bajio Monterrey Iran Iran Iran Ireland Israel Israel Israel Israel Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Italy Japan Japan Jordan Jordan Jordan Jordan Jordan Lebanon Lebanon Liberia Libya Libya Luxembourg Luxembourg Madagascar Malaysia Malaysia Malaysia Malaysia Malaysia Malaysia Mexico Mexico Mexico Mexico Mexico Mexico Mexico Mexico Mexico Mexico 3x550 4x180 404 330 18.6 382 2 x 382 350 2x68 86 8.5 17.2 7.9 90 2.5 18.2 2x21 2x11.4 25 90 8.3 18 17.1 90 173.1 188.5 188.5 177.7 177.7 325 9.3 324.5 2x109 113.6 68.18 2x214 211.5 19.5 39 12 21.9 21.9 50 340.0 6.3 309.7 134.9 119.3 54 49 429.4 588.3 2 x 244.4 450 593 516 227.2 304.8 515 515 390 3x1,210,000 4 x 396,000 888,800 726,000 40,920 840,400 2 x 840,400 770,000 2 x 149,600 189,200 18,700 37,840 17,380 198,000 5,500 40,040 2 x 46,200 2 x 25,080 55,000 198,000 18,260 39,600 37,620 198,000 380,800 414,800 414,800 391,000 391,000 715,000 20,400 714,000 2 x 239,800 249,920 149,996 2 x 470,800 465,300 42,900 85,800 26,400 48,180 48,180 110,000 748,000 13,860 681,340 296,780 262,460 118,800 107,800 944,680 1,294,260 2 x 537,680 990,000 1,304,600 1,135,200 499,800 670,560 1,133,000 1,133,000 858,000 1,068 466 261 214 12 247 494 226 2 x 44 56 6 11 5 58 2 12 27 15 16 58 5 12 11 58 112 122 122 115 115 210 6 210 141 74 44 277 137 13 25 8 14 14 32 220 4 200 87 77 35 32 278 381 316 291 384 334 147 197 333 333 252 1170 4x64 2x100 120 110 2 x 110 2x29 36 1.4 30 699 30 30 130 150 150 132 130 1010 1 350 2x33 33 18 2x66 56 8 0.2 0.237 0.245 0.09 2.52 0.18 0.18 0.165 0.06 0.06 0.1 0.35 0.35 0.08 0.069 0.16 19 17 19 0.08 1.04 0.2 0.13 0.18 5.91 7.00 7.23 2.66 74.41 5.31 5.31 4.87 1.77 1.77 2.95 10.33 10.33 2.36 2.04 4.72 560.99 501.94 560.99 2.36 30.71 5.91 3.84 5.31 139.85 146.81 148.24 111.02 135.85 135.85 132.68 96.68 96.68 114.83 157.99 157.99 106.77 101.51 131.57 106.77 139.85 124.22 135.85 0.12 3.54 121.37 13 350 100 60 40 0.27 0.276 0.218 0.276 0.28 0.207 0.242 2.2 3.5 3.5 0.075 0.85 0.4 0.4 0.4 0.256 0.256 0.23 0.237 0.16 0.093 0.12 0.12 0.2 0.126 0.126 0.08 7.97 8.15 6.44 8.15 8.27 6.11 7.15 64.96 103.34 103.34 2.21 25.10 11.81 11.81 11.81 7.56 7.56 6.79 7.00 4.72 2.75 3.54 3.54 5.91 3.72 3.72 2.36 152.43 153.34 143.30 153.34 153.93 141.20 147.71 104.46 120 210 150 220 80 146.63 146.63 146.63 150.15 150.15 145.53 146.81 131.57 112.20 121.37 121.37 139.85 123.11 123.11 106.77 1991 1993 1994 2001 1969 1996 2001 2003 1956 1956 1968 1969 1969 1971 1971 1971 1972 1972 1973 1975 1976 1981 1982 1994 1995 1996 1997 1998 2001 2003 2004 1996 1997 1976 1977 1978 1979 1984 1970 1971 1975 1975 1975 1955 2001 1965 1990 1990 1990 1999 1999 2002 1995 1999 1999 2000 2000 2001 2002 2003 2003 2003 Repesa C.2 0.76 177.200 30.25 0.000 99.225 0.1 0.2 0.83 114.95 5.95 3.75 157.6 17.493.22 129.040 97.91 23.157 0.33 139.63 6.12 0.800 194.83 124.22 0.000 6 x 3.04 442.85 132.74 139.25 122.500 123.17 0.000 50.200 44.1 0. Robur Siemens Siemens Spain Windhoek Windhoek Windhoek Nijmwegen Enschede Alkmaar Eerbeek Helmond Hydrocracker s'Hertogenbosch Bergen op Zoom Eindhoven AVIRA/Arnheim NAK 4 Oslo NRL Pakistan Sines Tosi Lavrados Lavrados Riyadh #9 Sierra Leone Ula Pandan Ula Pandan Iscor Matimba Majuba Encaso I Encaso II Encaso III Utrillas Cadiz Mallorca Almeria Solar Almeria Namibia Namibia Namibia Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Netherlands Niklasdorf Norway Pakistan Pakistan Poland Poland Portugal Portugal Portugal Portugal Portugal Portugal Portugal Saudi Arabia Sierra Leone Singapore Singapore South Africa South Africa South Africa South Africa South Africa South Korea Spain Spain Spain Spain Spain Spain Spain Spain Spain 2x94.08 0. Essen Zimmer.123 0.15 0.17 0.E.57 6x665 29 3x665 105 160 7.135 4 65 21 76 52 6.300 16.62 35.95 3.960 43.1 0.1 0.56 0.400 2 x 33.065 0.54 3.8 80.600 299.700 51.77 114.1 30 41 72 2x67.5 77.99 114.020 38.16 5.67 134.S.7 23.P.91 5.34 2.2 314.83 133.95 32.75 114.GEA GEA GEA GEA GEA GEA Marley/BDT GEA Marley/BDT GEA GEA GEA Marley/BDT GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT Hamon Hamon Hamon GEA Marley/BDT Hamon Marley/BDT GEA Marley/BDT GEA GEA Hamon Marley/BDT Marley/BDT GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT GEA GEA GEA Hamon GEA GEA GEA GEA GEA GEA GEA GEA GEA SWAWEK SWAWEK SWAWEK Esso Rotterdam Neratoom Neratoom Didier AEG Kanis Stork Boilers Ijssel Centrale DSM Geleen DSM Geleen KEMA / Engergiebedrijf Leiden DSM Geleen Royal Schelde Stork ABB Stal Esso.4 80.03 40.75 133.1 0.600 259.2 44.25 139.4 2.7 4x438.300 58.85 133.400 2 x 148.28 121.02 1181.1 17.85 2.20 147.43 2.000 11.000 278.02 2.000 92.140 4 x 964.83 125.800 176.800 51.1 21.800 11.64 7.780 312.720 39.8 94.63 16. Frankfurt Petrochimica Refinery Petrochimica Refinery Petrochimica Refinery Linde AG Uhde Lurgi / Quimigal Lurgi / Quimigal SCECO Heilborn GmbH BBC Deutsche Babcock GHH DB Thermal.91 36.600 154.91 4.75 129.61 149.1 1.0 20 12 26.83 144.12 130.700 14.72 114.21 5 0.5 6 0.02 5.63 3.35 3.280 2 x 167.600 52.960 82 15 15 12 203 11 36 9 3 3 2x30 30 30 18 18 28 28 0.2 0.43 3.02 5.36 2.47 4.84 2.000 26.90 131.000 26.93 14.200 158.28 114.080 220.000 90.25 1.138 0.123 0.2 0.53 5.400 127.15 0.36 2.43 5.48 2.380 69.95 2.165 45 2.84 4.680 4.5 18.2 1.400 88.07 4.61 5.83 70 70 30 0.000 72.8 19.02 4.560 208.560 209.17 0.81 130.5 0.16 2.5 6.25 18 0.51 106.355.040 691.000 170.000 3 x 3.700 40.91 6.620 48.9 142 40 45 12 45 42 58 46.08 0.960 176.07 5.1 0.000 44.1 0.600 176.156 0.4 100 33 118 80 6x1588 70 3x1525 126. Hengelo / Twente ML-Gavi Wijster Siemens KWU / Cuijk * DSM Siemens Österreich Maschinenfabrik Eßlingen Siemens Fiat Avio/Coastal Habibulla/Quetta Krupp.33 103.620 66.4 37.000 260.180 85.1 0.95 6.50 5.92 2.133 0.1 4.8 1.400 99.040 340.13 0.4 2 x 76 42 2x15 23 136.91 5.33 126.38 531.95 2.1 2 x 208.5 7.95 130 133.37 122.85 139.42 114.500 308.77 108.2 154.A.78 143.9 31.17 4.5 26.95 2.89 10.600 102. Johannesburg ESCOM AECI Midland ESCOM KEPCO/Halim Uhde Uhde Uhde Siemens / Union Termica S.91 36.75 133.17 0.5 23.85 4x107 141.5 140 12.138 0.1 0.6 1971 1972 1978 1968 1969 1969 1977 1978 1981 1985 1985 1986 1986 1987 1993 1993 1993 1993 1993 1994 1994 1995 1995 1995 1995 1996 1996 1996 1999 2000 2003 1966 1994 1997 1974 1981 1967 1967 1967 1978 1980 1981 1981 1996 1983 1978 1982 1975 1976 1985 1985 1990 1997 1968 1968 1968 1968 1968 1971 1978 1980 1980 .000 26.95 126.164 0.46 114.800 81.83 99.1 24 88.95 1.83 114.5 56 14 5 5.2 0.8 95 20 118.220 123 61 61 13 76 29 1 19 27 47 87 12 21 13 92 26 29 8 29 27 38 30 52 52 24 16 57 100 50 98 27 2 x 15 15 88 13 8 17 17 5 91 8 14 25 1. Rotterdam ABB Stal ABB Stal Royal Schelde Stork Ketels / Wapenveld ABB Stal/Gas Edon Erica ABB Stal/Gas Edon Klazienaveen ABB Stal/PGEM/Borculo Royal Schelde AVI Twente.9 38.200 92.64 4.17 40 15 0.67 139.175 0.400 58.085 54 2 x 25 0.83 114.83 106.A. 45 156.1 0.83 Cottendart 6 Buchs Winterthur KVA Josefstraße II 17 10 114.800 63.84 139.12 0.19 3.62 2.68 47.000 191.040 88.200 103.95 3.550 64.97 156. Oberhausen / Tarragona ISCOR.800 44.2 26 21 0.326 39.83 114.200 60.37 112.5 2x19 16. Biel BBC Widmer u.5 17.72 206.7 1.480 35.63 247.200 83.43 2.80 8.16 35.14 18. Erlangen / KVA Müra Biel von Roll Blohm & Voss GEKAL / KVA Buchs AWZ Zürich Caliqua Basel / KVA Thurgau Caliqua Basel / KVA Thurgau ABB Enertech AG / KVA Niederurnen Caliqua.2 0.000 44.100 2 x 41.43 149.1 0.18 0.880 58.8 39 37.59 117.8 0.8 670 Hsintien Shulin 20 30 Marley/BDT EPA Taiwan / Chung-Hsin Electric & .95 147.05 2.720 101.1 6 1.99 215.14 0.4 26.13 5.22 114.19 1.19 4.95 2.66 79.400 50.25 0.840 24.77 4.28 3.16 7 0.280 33.600 63.000 17. Ernst Sulzer AG Ciba-Geigy Müra Martin /KVA Bazenheid BBC.68 2.143 0.2 21 0.7 6 5.680 81.5 772. Kopp & Kausch / MVA Bazenheid Wehrle / KVA Buchs SW St. Baden Müra.84 2.85 139.65 0.586 543.86 5.15 4.85 124.12 1984 1987 1988 2001 2001 2001 2003 1985 1971 1972 1975 1982 1967 1969 1969 1970 1972 1973 1973 1974 1974 1975 1975 1977 1978 1979 1982 1983 1983 1984 1985 1986 1987 1989 1989 1990 1990 1991 1991 1993 1993 1993 1994 1994 1994 1996 1996 1999 2002 1960 1995 1978 1981 1991 1991 1997 Göteborg Norrtorp 4.16 153.83 Winterthur Schaffhausen Stadtwerke Zürich Werdenberg Lichtenstein 111.02 Biel KVA Winterthur Stadtwerke Zürich Werdenberg 127.2 40 279 56.84 138.000 2 x 23.54 767.658 95. Basel / KVA Gamsen Caliqua.63 3.45 135.586 124.22 129.59 124.508 40.43 147.1 5 0.6 21 0.740 44.15 0.4 15 2x10.2 5 0.54 2.4 16 27.91 3.600 132.83 114.31 5.25 29.860 22. Gallen Lonza.22 131.7 20 30 21 24.13 4.95 177.380 137.500 158.72 177.4 37.3 0.24 620.800 37.400 308. Ernst Kringelen / KVA Linthgebiet Wehrle Werke / MVA Buchs Kühnle.37 114.15 35.300 38.91 4.57 114.09 2.86 8.77 7. Basel / KVA Basel III Caliqua. Basel KVA Werdenberg Lurgi / KVA Bazenheid SAIOD Caliqua ABB / KVA Oftringen Siemens.12 0.9 25.7 0.68 2.095 0.84 50.63 7.7 0.85 129.05 2.60 96.13 0.39 43.95 4.100 1.108 0.95 206.3 10.7 16 38 28.28 114.1 0.12 118.9 62.840 330.13 1.111 0.000 46.5 72 23 26.05 4.6 46 47 50.2 11 35 20.360 85.600 17.000 18.3 114.600 58.84 206.06 0.180 55.800 26.660 24.83 121.25 19 7.000 66.95 138.000 9 28 26 181 37 37 160 97 85 19 19 13 5 12 40 10 14 14 11 16 7 7 19 24 7 23 13 17 13 19 14 16 3 8 1 12 10 18 10 25 19 25 24 47 15 17 11 30 30 33 500 5 5 39 56 91 75 1.400 2.GEA GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA Marley/BDT Marley/BDT GEA GEA GEA Marley/BDT GEA GEA GEA GEA Marley/BDT Marley/BDT GEA Marley/BDT GEA Marley/BDT GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA Marley/BDT GEA Marley/BDT GEA Marley/BDT Marley/BDT Marley/BDT GEA GEA Marley/BDT GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT Marley/BDT GEA Hamon GEA GEA GEA GEA Montcada Saica RESA Alstom Ghesa ESP / La Loma Ghesa ESP / Enemansa Babcock Borsig Power.95 23.7 4 12 1.63 56.200 54.000 3 x 96.68 620.19 3.400 111.54 2.28 Aleppo 13.22 19.3 11.60 117. Vanderbijlpark von Roll Oschatz Oschatz von Roll Stadtwerke Biehl Stadtwerke Neuenburg von Roll.83 121.38 560.800 82.77 33. Schweiz / KVA Thun Kraftwerk Aleppo Mitsubishi/Jandar Siemens Werke AG Lurgi MHI MHI Zaragoza MVA Tarragona Son Reus Spain Spain Spain Spain Spain Spain Spain Südafrika Sweden Sweden Sweden Sweden Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Switzerland Syria Syria Taiwan Taiwan Taiwan Taiwan Taiwan 14.700.1 7 0.940 35.800 63.43 620.2 0.7 8 8 60 87 140 31.340 8.68 149.200 77. Zürich KVA Winterthur von Roll von Roll Widmer u.800 124.31 7 1.83 124.2 150 3x44 29 29 20 8.000 613.95 3.108 0.83 126.3 0.38 3.1 0.1 0.33 17. 28 116. Offenbach / Rye Marley/BDT House Power Station GEA Aalborg Ciserv GEA NNC Hamon Siemens/East.820 77. Marley/BDT Gummersbach / Yungkang Hamon Star Energy/Toshiba/TCIC/Fong Der Hamon Sun Ba/Toshiba/TCIC/Chang Bin GEA Stone & Webster Marley/BDT NEMA.2 0.51 1.66 2.15 0.28 129.14 49.600 1. Allen Sons. Denmark / Elean.91 2. British Steel Kellog Kellog Kellog Kellog Caloric Aalborg Ciserv Hawker Siddeley Pow.28 118.506.900 74.5 21 18.000 85.1 100 38.95 2.340 6.15 0.51 3.2 86 855 217 206.61 138.3 270.91 118.15 20 35 600 160 0.176.112 0.400 1.000 33.081 0. Elect. Netzschkau / Izmit * GEA Siemens GEA Zorlu Enerji Thomassen Power Systems NL / Marley/BDT Esenyurt Hamon Zorlu Enerji/Bursa GEA Edison Mission Energy GEA Shell Refinery GEA Foster Wheeler GEA Mobil Oil GEA Foster Wheeler Foster Wheeler W.15 0.63 149.14 60.000 1.000 1.H.400 119.840 189.06 0.91 139.400 1.520 77.8 360 100 Coryton Energy Spalding Energy Neil Simpson I Benicia Norton P. Eng.91 2.43 5.85 107.092 0.6 5.308 132.83 121.800 83.540 135.Marley/BDT Hamon GEA Hamon GEA EPA Taiwan / Chung-Hsin Electric & Tuntex Lurgi AG Bechtel/Hsin Tao Siemens Babcock Borsig Power. Eng.400 106.380 28.09 107.91 5.800 187.6 35 30 137 684.253 55 75 0.08 780 0.86 114.7 2.87 Esenyurt Haven Killingholme Shell Stanlow Shell Stanlow 8 1 Eye Power Corby Eye Power Peterborough 14 120 28 120 Glanford Sheffield Barry CHP 28 6.22 111.0 141.42 2.152 0.42 129.6 743 250 57 906.66 5.47 7.9 410 852 48.080 1.860 167.85 135.09 0.51 7. Black Hills Power/Pacific Power Chugach Electric GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Taoyuan Kuo Kuang Taiwan Taiwan Taiwan Taiwan Taiwan Taiwan Taiwan Taiwan Turkey Turkey Turkey Turkey Turkey Turkey Turkey UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK UK USA USA USA USA USA 94 85.31 3.600 595.600 902. UK / Coventry Waste InterGen Black Hills Power & Light Co.81 111.92 2.177 980 490 0.02 106.43 4.081 10 0.36 2.43 4.3 76 22.07 105.77 111.39 5.19 4.12 126.2 0.25 0.4 608.191 0.1 35 5.77 108.83 106.31 5.200 48.H.000 12. British Steel W.43 3. UK EPR Scotland/Abengoa/Westfield InterGen ABB Alstom.28 129.1 494.7 61.900 46.61 4.08 0.112 0.634.000 311.126 0.65 23.39 295.26 2.77 108.77 4.000 693.5 34 38 177 54.48 5.1 78 19.400 61 55 91 394 303 63 640 320 10 13 22 25 115 35 50 13 14 12 23 4 15 4 39 39 32 32 2 8 265 31 265 551 31 32 204 175 40 23 19 89 443 224 453 65 25 481 162 37 586 49 14 56 553 140 0. UK / Shotton CEL Intern. Potter Wyodak Beluga 358 20 20 330 65 .600 42.000 171.7 49.85 114.38 4.224 0.49 60.23 129.085 780 0.920 12.000 1.082 0.59 129.09 0.881.30 2.600 2.203 0.08 149.000 477.600 550.380 902. Allen Sons.51 1.91 2.078 132. Schweiz / Enfield Entergy/Mitsubishi/Damhead Creek FLS.49 9.340 109.5 15 19.540.75 158.72 6.09 0.23 1997 1997 2000 2001 2002 2002 2004 2004 1979 1995 1996 1997 1998 2000 2001 1965 1968 1968 1971 1971 1971 1971 1979 1979 1979 1979 1981 1991 1992 1992 1992 1992 1993 1996 1996 1997 1997 1997 1997 1998 1999 1999 2000 2000 2000 2001 2001 2001 2003 1968 1975 1975 1977 1979 Aliaga Sise Cam Bursa 10 10 5.065 12 250 0.78 140.600 389.339.66 2.02 106.08 0.22 139.77 111.45 2.105 0.10 4. Aalborg Ciserv Hawker Siddeley Pow.200 761.42 108.95 3.15 0.4 50 315.9 13 410 47.95 99.000 66.11 144.000 125.800 215.874.088.19 120.078 0.000 301.200 220.43 3.085 0.72 2.083 0. Exxon Braintree Electric Light Dept. Siemens KWU.36 2.07 3.200 1.200 1.000 42.36 2.322 0.430 51.66 106.9 469 98 989.200 39.031.000 105.308 109.64 2.1 0.28 139.138 0.993.119 0.95 96.118 0.85 107. CNIM / Stoke-on-Trent Municipal Marley/BDT Waste Plant CNIM / Wolverhampton Municipal Marley/BDT Waste Plant Marley/BDT Marley/BDT Hamon Marley/BDT Hamon Marley/BDT Hamon GEA Marley/BDT Marley/BDT GEA GEA GEA GEA GEA GEA CNIM / Dudley Municipal Waste Plant Taymel / Thetford Biomass Plant Enron/Stone&Webster/Sutton Bridge ABB Baden.43 137.08 0.6 346 700.2 0.33 123.68 129.2 0.02 139./King's Lynn GEA AES Electric Ltd.99 5.1 0.36 2.480 110. 3 247. Rochester Browning Ferris Gas Serv.180 160.2 0.8 159.83 100. TX Calpine/Bechtel/Sutter Front Range Power ABB Alstom.900 4 x 561. Falcon Seaboard Energy America Southeast Intercontinental Energy Indeck Energy Ogden/Martin/Huntington University of Alaska Odgen Martin Systems CRS Sirrine.169 0.25 3.800 1.05 0. Airport Pacific Ultrapower Energy Factors / Sithe Energies Energy Factors / Sithe Energies Dutchess County Olmsted County Wheelabrator Sherman Energy Chicago Northwest American Ref-Fuel Ogden Martin Systems ABB TBG Cogen RAM Enterprises Oxford Energy Wheelabrator Environ.9 21 161.95 1.125 0.1 26.37 80 50 80 15 2x50 9 40 46.37 121.37 133.9 19 184. Schweiz / Bellingham.5 2x158.5 29.12 0.960 181.12 1600 800 .17 0.5 18.1 22. Schweiz / Midlothian. Schweiz / Blackstone. Crockett Energy Management Inc.180 41.37 121.4 100 39.2 0.11 0.480 220.99 3.400 712. MT Browning Ferris Gas Serv. Inc. Schweiz / Hays.54 5.48 121.900 2 x 563. Extension Gordonsville Arbor Hill Cedar Falls Haverhill Extension Islip Pine Bend Landfill Mallard Lake Landfill Dighton El Dorado Rumford Tiverton USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA USA 0.02 4.48 114.51 7.600 620. TX ABB Baden.54 3.02 5.75 133.6 7.75 122.17 0.49 1.820 58.6 111.95 2. Billings Generation / Billings.83 100.000 101.135 0.1 0.600 127.186 0.07 10.5 574.822.240 49.5 13 30 26 100 285 20 80 100 35 10 50 1 0.75 133. MA ABB Baden.37 121.91 3.6 20.7 117 334.48 137.91 2.54 5.43 118.98 5.02 3.7 641. MA ABB Alstom.4 484 51.140 257.5 0.69 5.49 2.47 2.600 547.07 100.83 108.253 0.2 18.1 0.97 3.085 0.54 3.000 712.200 1.02 5.085 0. Municipal Electric Utility Ogden Martin Systems of Haverhill MacArthur Res.57 114.54 5.000 3 x 563.500 548.020 198.99 5.07 310.12 0.17 0.83 108.09 108.1 90 70 324 867 68 282 324 55 98. Intercontinental Energy Cogen Technologies.1 0.900 39.237 0.54 121.45 2.02 5. Schweiz / Midlothian.000 154.560 351. Sys.54 2.083 0.98 31.7 22.500 2 x 348.54 133.1 0.12 0.169 0.186 0.1 0.908 125.12 0. Inc.067 0.54 102.000 217.43 133.400 149.98 2.200 2 x 563.01 140.200 605.800 121.5 4 20 1 54 47 67.440 39.75 139.12 0.GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT Hamon GEA GEA Marley/BDT Marley/BDT GEA GEA GEA GEA GEA Marley/BDT GEA GEA GEA GEA GEA Marley/BDT GEA Marley/BDT GEA GEA GEA GEA Marley/BDT Marley/BDT Marley/BDT Marley/BDT Hamon GEA Marley/BDT Marley/BDT Hamon Hamon BBC Pacific Gas & Electric Miami Intl.000 0 15 4 53 19 12 15 12 37 12 120 103 123 31 3 58 45 210 561 44 182 210 36 64 14 105 47 38 161 76 216 15 205 65 26 72 13 12 17 136 30 178 129 313 160 161 660 497 331 331 331 372 331 330 830 415 3.500 64.22 23.000 87.085 0.411.72 2.183 0.2 0.91 7.600 46.125.37 139.95 7.6 6.4 4 2.54 3.907.17 0.1 0.67 2.16 0.85 152.83 121.120 245.95 146.400 735.51 5.5 2 x 256 2 x 255 1282.63 114.85 114.54 3.46 114.55 137.8 82.7 0.160 39.95 3.83 133.000 1.12 29.14 56. Recovery Agency Browning Ferris Gas Serv.9 11 6 9 60 150 80 80 1979 1981 1982 1984 1984 1984 1985 1985 1985 1986 1986 1987 1987 1988 1988 1989 1989 1990 1990 1990 1990 1990 1990 1991 1991 1991 1991 1991 1992 1992 1992 1993 1993 1993 1994 1994 1994 1994 1994 1995 1996 1996 1998 1999 1999 1999 2000 2000 2000 2000 2001 2001 2001 2001 2002 2002 Front Range 500 150 0.1 0. Lowell CNF Constructors Black Hills Power & Light Odgen Martin Systems Falcon Seaboard Dutchess County Mission Energy Bechtel.080 462.5 4 x 255 3 x 256 2 x 256 2 x 256 511.27 0.12 0.12 0.203 0. Bechtel.6 190.37 121.400 1.02 3.83 136.12 0.263.40 20. Inc.820 50.260 544.17 0.17 0.200 2 x 561.95 5.000 440. Inc.067 1. TX Sithe/Raytheon/Mystic Sithe/Raytheon/Fore River Beluga Gerber Miami Chinese Station North Island NAS NTC Dutchess County RRF Olmsted County RRF Sherman Chicago SEMASS Haverhill Hazleton Grumman National City Exeter Spokane Bellingham Linden Norcon-Welsh North Branch Sayreville Fairbanks Union County Neil Simpson II Onondaga County Saranac Dutchess Co.95 133.000 2.07 108.12 0.37 121.95 2. Schweiz / Lake Road.26 121.95 139.99 4.600 9.063.53 2.920 14.99 5.120 419.067 0.800 406.000 1.4 210 46 275 200 483.85 121.37 114.8 18.54 3.5 48 4.81 114.75 131.75 125. Sempra Energy / Reliant Energy Rumford Power Associates Tiverton Power Associates ABB Baden. CT ABB Baden.95 1.200 2 x 563.83 149.5 249.37 133.200 356.100 105.54 3.51 4.02 5.2 22.9 73 58 248.00 3.00 2.520 44.37 121. 178 0.567. Japan Technimont Technimont Technimont Davy Powergas Davy Powergas Davy Powergas Davy Powergas Davy Powergas Davy Powergas Salzgitter KSB Machinoimport Oxidor Linde AG Hyundai E.5 120 217.080 2 x 1.85 139.68 6.15 0.660 66.85 153.000 176.400 1.5 Gubaha Gubaha Gubaha Tomsk Tomsk Tomsk Moskau El Tablazo Ba Ria Lendava Banja Luka 0./Baria TDK / Mitsui Lurgi Paris Siemens Werke AG Pancero Refinery Shanxi.09 158.20 5.000 1.5 2.9 0.5 488.28 0.160 9.2 0. Japan Toyo Engineering.900 14.45 9. Houston / Chehalis WA KeySpan NY.32 0.32 0.28 0.345 5.45 9.680 116.8 55.42 3 x 748.40 133.45 9.35 0.400 42.5 6.45 9.000 547.26 9.32 0.686.445.6 307.78 139. Japan Toyo Engineering.000 66.120 3 x 120.5 54. Japan Toyo Engineering.183 Maalaea.660 66.28 1.520 2 x 1.09 158.500 119.45 9.5 10.27 39.32 0.960 122. Japan Toyo Engineering.6 54.09 158.2 3.156 0.000 611.C.140 1.85 158.93 153.45 9.32 7 0.09 158.074.716.09 158.6 3.09 158.520 676.2 0.32 0.9 217 19.28 0.6 3. Japan Toyo Engineering.6 52.6 10.85 158.27 8.8 4.6 10.6 10.09 158.20 5.27 8.45 9.34 0.32 0.97 158.5 10 26.45 9.120 115.21 0.4 80 54.45 206.99 4. Japan Toyo Engineering.7 18 13 3x72.32 0.09 158.03 144.27 8.6 2x780 248.6 680.54 130.48 136.120 3 x 115.09 139.93 153.45 9.32 0.680 116.45 9.1 14.7 657 463.85 139.91 5.020.6 10.100 5 x 171.61 4.980 1.000 120.2 0.32 0.09 158.09 158.4 53 21.44 158.32 0.156 0.497.3 57.28 0. Yushe Foster Wheeler Athens Choctaw County Goldendale Energy Hunterstown Moapa Wygen 1 USA USA USA USA USA USA USA USA USA USA USA USA USA USA USAS USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR USSR Venezuela Venezuela Venezuela Vietnam Yugoslavia Yugoslavia Yugoslavia Yushe 3x340 766.09 158.67 129. Japan Toyo Engineering.68 6.28 0.47 100.940 41.400 697.91 9. Japan Toyo Engineering.91 9.211 0.32 0. USA / Ravenswood.472.27 8.09 158.4 316.6 8.900 264.6 3x52.6 54.45 5.124 660 496 199 496 1.32 0. Japan Toyo Engineering.48 120.306 4. NY Genwest LLC/Silverhawk NYPA/GE/Sargent & Lundy/Poletti Transalta/Delta Hudson/Chihuaha III Maui Electric Toyo Engineering.5 10.940 39. Japan Toyo Engineering.93 153.45 9.6 10.05 141.4 53 57.400 159.720 120.27 8.2 0.45 9.09 158.46 2002 2002 2002 2002 2002 2002 2002 2003 2003 2003 2003 2004 2004 2004 1990 1970 1970 1970 1970 1970 1972 1972 1972 1972 1972 1972 1972 1973 1973 1973 1973 1973 1973 1976 1978 1978 1979 1979 1979 1979 1979 1979 1979 1981 1982 1974 1990 2001 1997 1977 1978 1981 2004 1976 Otay Mesa 650 277 0.660 126.009 161 425 300 441 317 180 461 316 205 47 47 35 34 12 8 141 35 106 102 12 36 52 35 35 12 12 52 52 20 20 20 37 35 34 37 35 34 14 36 252 3 78 141 140 13 6 17 866 4 2x120 350 110 350 2x200 80 0.43 4.86 9.32 0.600 47.43 157.900 22. Nevada Reliant/Sargent & Lundy/Big Horn Calpine Parsons Energy.140 41. Japan Toyo Engineering.2 3.067 0.600 1.45 9. Japan Toyo Engineering.720 120.6 3.480 176.32 0.338 4.000 158.000 1.45 1.078.140 176.600 126.117 0.9 490 278 712.21 0.5 54.5 766.91 8. Unit 15 500 450 350 30 14.45 9.09 158.400 477. Japan Toyo Engineering.93 153.45 9.09 158.120 120.93 153.45 9.98 5. Japan Toyo Engineering.7 80 80 30.32 0.6 54.2 0.32 0.000 58.09 158.61 6.28 130.3 30.400 1.Nevada Power Services.32 0.78 135.500 1.09 141.45 9. Japan Toyo Engineering.23 10.09 158.4 2 x 669.3 30. USA / APEX.8 72 72.686. Japan Toyo Engineering.5 5x77.7 3x18.6 18.09 158.500 119.600 28.000 479.169 0.91 5.93 158.32 0. Japan Toyo Engineering.32 0.98 3.120 41.7 18.27 160 60 Conoco .7 18.04 10.45 9.6 3x54.GEA GEA GEA GEA GEA GEA Marley/BDT Hamon GEA Marley/BDT Marley/BDT Hamon Hamon Hamon GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA GEA Marley/BDT GEA GEA Marley/BDT GEA Hamon GEA GEA GEA GEA Marley/BDT GEA PG & E Generating Reliant Energy Calpine Reliant Energy Duke Energy Moapa LLC Black Hills Generation Mirant .140 3 x 40.600 3 x 159.19 139.67 141. . B EXAMPLE OF AIR-COOLED CONDENSER DESIGN CHECK B-1 . Example of Air-Cooled Condenser Design Check B-2 . Example of Air-Cooled Condenser Design Check B-3 . Example of Air-Cooled Condenser Design Check B-4 . Example of Air-Cooled Condenser Design Check B-5 . Example of Air-Cooled Condenser Design Check B-6 . Steam Distribution Manifolds – These manifolds distribute steam to the primary bundles. Main Duct – This circular piping transports steam from turbine exhaust to the ACC. Hinged Expansion Bellows – These connective systems absorb the movement in the manifolds due to thermal expansion. Balance Line – This connecting line between main steam duct and condensate receiver tank equalizes pressure during startup and provides steam for reheat and deaeration during normal operation. Transition Piece . Drain Pot – This system collects water from the steam duct. distribution line. this piece transitions to a circular shape. Gimbal Expansion Bellows – This connective system is used to absorb the movement in the main duct. Rupture Disc/s Assembly – This pressure relief system is mounted on the main steam duct to protect the unit from over pressure.Located below the dogbone joint (which is rectangular). with water from the drain pot pumped to the condensate receiver tank. and riser due to thermal expansion. Risers – These individual vertical ducts transport steam from the steam distribution line to the top of the tube bundles.C TERMINOLOGY Glossary of Air-Cooled Condenser Components C. Steam Distribution Line – This piping is placed across the width of the ACC to distribute steam to the A-frame streets.1 Steam Side Dogbone Expansion Joint – This rectangular connection is welded to the turbine exhaust to minimize forces from steam duct to turbine. C-1 . a hogging ejector is used for air evacuation during startup and a holding ejector is used for removal of air during normal operation. Deaerator – The deaerator is located on top of the CRT to reheat and release oxygen from the condensate and makeup water. makeup water required for the plant operation.6 Mechanical Equipment Fans – Axial induced draft fans deliver cooling airflow.3 Steam/Condensate Carryover Lines The carryover lines are located at the bottom of the tube bundles and transport steam from the primary bundles to the secondary bundles. and other drains flow into the tank. The tube bundle consists of finned tubes arranged in single or multiple rows. Second Stage or “Dephlegmator” – Steam not condensed in the primary stage is condensed in the second-stage tube bundles. C. C. Air Removal Equipment – Steam jet air ejectors or liquid ring vacuum pumps are used to remove noncondensables from the ACC and release them to the atmosphere.4 Condensate Side Drain Line – The drain line drains the condensate from the carryover lines to the condensate receiver tank (CRT). normally located underneath or adjacent to the ACC. These bundles are typically the same configuration as primary stage bundles except the tube length is often shorter. C.2 Tube Bundles Primary Stage or “Kondensator” – This heat exchange tube bundle system first receives steam from the turbine exhaust.Terminology C. C-2 . Condensate Receiver Tank – The CRT is a cylindrical vessel. The tubes are welded to the tubesheet at the top and bottom. They also collect the condensate from all tube bundles. In the case of steam jet ejectors. Condensate from the ACC.5 Air Take Off Side Air Take Off Line – These connecting lines convey noncondensables (mainly air) leaking into the turbine exhaust steam from the top portion of the secondary bundles to the air removal equipment. C. NEMA4 enclosure for outdoor installation. ladders.8 Drain Pot System The drain pot pump circulates water from the steam duct to the CRT. Vibration Switches – Cut off switches are used to shut a motor off in case of excess vibration of mechanical equipment. spiral bevel type gearboxes are used as speed reducers.Terminology Electric Motors – Fans are driven by electric motors. windwall bracings.7 Structural Steel Structural steel is used in columns. fan bells. Normally. are intentionally designed to be the first failure point in the event of a drive system failure. Motors normally are built to the following specifications: totally enclosed fan-cooled (TEFC). with the speed dependent on the ambient temperature range of operation and noise level criteria. Class B temperature rise. Speed Reducers – Typically parallel shaft. 2 x 100% pumps are provided. used to connect motors to gearboxes. walkways and platforms. with one in operation and one in standby mode. and sheeting. fan rings. bracings. Couplings – Flexible couplings. stairs. beams. and Class F insulation. fan decks. C-3 . C. module partition plates. motor bridges. C. . . export classification and ensure compliance accordingly. and demonstration program. California 94304-1395 • PO Box 10412.S. The Electric Power Research Institute (EPRI) The Electric Power Research Institute (EPRI).S. Inc.855.S. Palo Alto. with major locations in Palo Alto. citizen or permanent U.S. participants. 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