1. Boiler corrosion and the requirement for feed- and boiler-water chemical control in nuclear steam generators

1978 ◽  
pp. 1-10
Author(s):  
R. Garnsey
Keyword(s):  
Chemical Control ◽  
Steam Generators ◽  
Boiler Water

Section 1. Introduction

2022 ◽  
pp. 1-2
Author(s):  
Keyword(s):  
Water Chemistry ◽  
Steam Generators ◽  
Thermal Systems ◽  
Boiler Water ◽  
System Components ◽  
Steam System ◽  
Current Operating

This document has been prepared by the Water Technology Subcommittee of the ASME Research and Technology Committee on Steam and Water in Thermal Systems as a consensus of proper current operating practices for the control of feedwater and boiler water chemistry in the operation of industrial and institutional, high duty, primary fuel fired boilers. These practices are aimed at minimizing corrosion, deposition, cleaning requirements, and unscheduled outages in the steam generators and associated condensate, feedwater and steam systems for boilers, and steam system components which are currently available. This publication is an expansion and revision of the operating practice consensus documents previously issued by the Committee [1-3]. The tabulated values herein update and replace the ones previously published. Titles have been edited and clarified. The text has been reordered and modified where necessary. THE TEXT IS OF PRIME IMPORTANCE AND SHOULD BE CONSIDERED FULLY BEFORE USING THE TABULATED VALUES. One Appendix has been added to provide additional guidance.

Water/Steam Treatment Programs and Chemistry Control for Heat Recovery Steam Generators

2013 ◽  
Author(s):  
Brad Buecker
Keyword(s):  
Heat Recovery ◽  
Power Plants ◽  
High Reliability ◽  
Combined Cycle ◽  
Steam Treatment ◽  
Steam Turbines ◽  
Steam Generators ◽  
Accelerated Corrosion ◽  
Boiler Water ◽  
Water Steam

New power generation in the U.S. is being dominated by installation of combined-cycle power plants, where a significant portion of the power is produced from steam turbines supplied by heat recovery steam generators (HRSG). Proper chemistry control and monitoring of HRSG feedwater, boiler water, and steam are essential for high reliability and availability of these units. However, many plants have minimal staff, most if not all of whom have no formal chemistry training and who may not fully understand the importance of water/steam chemistry and monitoring techniques. This paper provides an outline of the most important chemistry control methods and also examines the phenomenon of flow-accelerated corrosion (FAC). FAC is the leading cause of corrosion in HRSGs,[1] and is often the result of the outdated belief that oxygen scavengers are a requirement for feedwater treatment. Since 1986, FAC-induced failures at several coal-fired power plants have killed or injured a number of U.S. utility workers.

Experiences With Hydrogen Embrittlement in the Consolidated Edison System

1964 ◽  
Vol 86 (3) ◽  
pp. 327-340
Author(s):  
I. B. Dick
Keyword(s):  
Water Treatment ◽  
Hydrogen Embrittlement ◽  
Chemical Control ◽  
Oxygen Scavenger ◽  
Cleaning Operation ◽  
Boiler Water ◽  
East River ◽  
Years Of Service ◽  
Phosphate Treatment ◽  
Phosphate Control

Boiler 40 at Astoria developed brittle failures in about 3-months operation. Feedwater was pH-adjusted and deaerating condenser and heater were in operation, but no oxygen scavenger was used. Boiler water was maintained on no-solids basis. Some condenser leakage occurred. After six months, the boiler was put on coordinated phosphate control and a pronounced hideout condition was disclosed. After about nine months of operation, brittle failures occurred in the nose tubes to the extent that replacement of the entire nose section was made. Boiler 70 at East River developed brittle failures after about 8 years of service. Feedwater pH was adjusted by cyclohexylamine. Boiler water treatment for the first 5 years was low NaOH + Na3PO4, and the last 3 years coordinated phosphate. A hideout condition also exists in this boiler. Factors of chemical control, cleaning, operation, and design are discussed. Many variables can be eliminated by comparison with other units in the system. Some factors remain unanswered. Consideration is given the fact that both boilers disclosed a considerable hideout condition when operating on coordinated phosphate treatment.

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