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ASTM Grade 29 titanium alloy (UNS R56404) has been traditionally used for oil and gas stress joints (TSJ). However, given the general difficulty of processing this type of alloy in the beta quenched condition and more recently the exorbitant increase in alloying costs due to the ruthenium, a new solution is required if titanium is to be considered for future applications. This 475 alloy was developed to meet geothermal requirements to replace Grade 29 seamless casing. The essential material properties of Grade 29 in bulk and welded condition as used for titanium stress joints were reported by Shutz et al.
A new titanium alloy, TIMETAL® 475 (Ti-475), which was developed for use in aggressive geothermal fields as a casing material, has been tested for use in typical oil and gas environments. The alloy composition, Ti-0.4Ni-3.75Mo-0.75Zr, provides excellent corrosion resistance in geothermal brines which are low pH and high in chlorides. For oil and gas applications, the additional effects of H2S and CO2 on the alloy must be considered. To this end, the alloy was subjected to the NACE TM-0177 Level VII exposure test. For the geothermal application, the alloy is prepared in the Solution Treated and Aged (STA) condition with a typical titanium bimodal microstructure. For use in oil and gas, the alloy is prepared in the Beta Annealed condition. The beta annealed condition is required for large components such as titanium stress joints where superior fatigue properties are required. This paper reviews the mechanical properties and corrosion evaluation of the Ti-475 alloy in the beta annealed condition as compared to the STA condition.
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.