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The current approach to corrosion severity prediction is to use long-term averages of environmental parameters (such as relative humidity, temperature, and pollutants), geographic features (such as coastal proximity), and witness coupon corrosion rates of indicator materials to classify an environment into one of a small number of severity categories. However, recent work has revealed that brief changes in environmental conditions—even those lasting only a few hours—can significantly affect total corrosion damage, and long-term averages of environmental conditions are not sufficient to accurately predict cumulative corrosion damage. To more accurately measure the corrosion damage from these short-term events, corrosion sensors are becoming increasingly popular. The frequent acquisition of data and increased measurement sensitivity are attractive features, however the data from these corrosion sensors is still difficult to interpret in many cases.
This work examines data from a multi-year, large deployment of corrosion sensors in a variety of locations representing a range of corrosivity severities. The corrosion sensors used in this work measure atmospheric parameters such as relative humidity and temperature in addition to electrochemical parameters such as the conductivity of the electrolyte formed by salt deposition and possible deliquescence, and the polarization resistance measured on a variety of structural materials including 7075 aluminum, 2024 aluminum, and 4310 steel. Comparisons between sheltered and unsheltered sensor exposures show the difference precipitation and other rinsing events have on sensor measurements. In particular, the interplay of relative humidity and electrolyte conductivity is discussed in the context of using conductance sensors as a proxy for salt loading. The tendency for protective corrosion product films to form on the sensing materials, resulting in high initial corrosion rates and subsequent lower corrosion rates is demonstrated and the implications for accurately measuring corrosion rates is discussed. A comparison between representative conductance values from the field to values from lab testing is presented to provide context for salt loadings in accelerated laboratory corrosion testing. These discussions can be used to guide the development of models used to predict atmospheric corrosion rates from sensor data.
Uncontrolled growth of microorganisms in the oil field production systems have a major negative impact on the productivity and asset integrity in oil and gas industry. Sulphate-reducing bacteria (SRB) have been found as the most troublesome group of microorganisms among all organisms involved in MIC of carbon steel and other metals used in the oil industry (Abdullah et al 2014). The formation of SRB biofilm on steel surface can affect the kinetics of anodic and cathodic reactions, leading to an acceleration of steel corrosion (Beech and Sunner, 2004: Zuo,2007). In addition to that, SRB contributes to hydrogen sulfide-driven reservoir souring, increased suspended solids, reservoir plugging, etc., in oil field sites.
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Martensitic stainless steels for OCTG materials are widely used in sweet and mild sour conditions. Environmentally-assisted cracking (EAC) is a major corrosion-related issue when using stainless steels as OCTG materials. The EAC in specific oil/gas well conditions with sour environments is defined as sulfide stress cracking (SSC) and stress corrosion cracking (SCC). The SSC is a type of cracking caused by hydrogen embrittlement, which is attributed to a cathodic reaction under acidic conditions, while SCC is associated with an anodic reaction. SSC testing for martensitic stainless steels for OCTG material is often carried out at or near ambient temperature under conditions simulating condensed water, and SCC tests are conducted at higher temperatures under conditions simulating formation water and/or the brine availability test.
The power plant is a natural gas-fired, combined cycle plant with three combustion turbines and a single steam turbine. A large stainless steel surface condenser is used to condense steam off of the turbine, and provide high purity steam condensate return to the boiler system. The steam condenser was put into service approximately 15 years ago. This plant takes makeup water for its open recirculating cooling tower water system from a river location that is inland from an ocean coastal area.