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This report explains different types of corrosion phenomena and contributing factors of corrosion that can occur in fire protection systems (FPS), such as water corrosivity, MIC, trapped air (wet systems), residual water (dry systems), and pipe weld corrosion. The basis for selection of corrosion mitigation strategies for corrosion mitigation and management of FPS are also discussed.
Corrosion that results in pipe leakage or obstruction is the most significant issue for owners of water-based FPS or fire sprinkler systems, in terms of both cost and system reliability. Corrosion damage/products and mineral deposits can impair the effectiveness of sprinkler systems, leaving facilities vulnerable to uncontrolled fire loss even though they are equipped with fire protection systems. This report describes practices that have been successful in mitigating FPS corrosion.
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2009 EDITION - HISTORICAL DOCUMENT.
Selection and qualification of carbon and low-alloy steels, corrosion-resistant alloys, and other alloys for service in oil and natural gas production and treatment plants with H2S-containing environments.
Metallic material requirements for resistance to sulfide stress cracking (SSC) for petroleum production, drilling, gathering and flowline equipment, and field processing facilities to be used in hydrogen sulfide (H2S)-bearing hydrocarbon service. Historical Document 1995
Metallic material requirements for resistance to sulfide stress cracking (SSC) for petroleum production, drilling, gathering and flowline equipment & field processing facilities to be used in H2S-bearing hydrocarbon service. Historical Document 1996
Metallic material requirements for resistance to sulfide stress cracking (SSC) for petroleum production, drilling, gathering and flowline equipment in H2S-bearing hydrocarbon service. Historical Document 1997
Metallic material requirements for resistance to sulfide stress cracking (SSC) for petroleum production, drilling, gathering and flowline equipment and field processing facilities to be used in H2S-bearing hydrocarbon service. Historical Documents 1998
Metallic material requirements for resistance to sulfide stress cracking (SSC) for petroleum production, drilling, gathering and flowline equipment and field processing facilities to be used in hydrogen sulfide (H2S)-bearing hydrocarbon service. Historical Document 2000
Metallic material requirements for resistance to sulfide stress cracking (SSC) for petroleum production, drilling, gathering and flowline equipment in hydrogen sulfide (H2S)-bearing hydrocarbon service. Historical Document 2002
Metallic material requirements to provide resistance to sulfide stress cracking (SSC) and/or stress corrosion cracking (SCC) for petroleum production, drilling, gathering and flow line equipment in H2S service. Historical document 2003
HISTORICAL DOCUMENT. External corrosion direct assessment (ECDA) is a structured process that is intended to improve safety by assessing and reducing the impact of external corrosion on pipeline integrity. By identifying and addressing corrosion activitiy and repairing corrosion defects and remediating the cause, ECDA proactively seeks to prevent external corrosion defects from growing to a size that is large enough to impact structural integrity.
HISTORICAL DOCUMENT. Specification, selection & use of sensors for monitoring atmospheric corrosion. These sensors - based on electrochemical techniques - provide continuous records of contaminants, corrosion rates, or coating condition.
HISTORICAL DOCUMENT. This NACE Standard establishes material requirements for resistance to sulfide stress cracking (SSC) in sour refinery process environments, i.e., environments that contain wet hydrogen sulfide (H2S). It is intended to be used by refineries, equipment manufacturers, engineering contractors, and construction contractors.