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The exploration and development of oil and gas resources towards the direction of ultra-deep, low permeability, and unconventional in China. In addition, some oil and gas fields have developed into the middle or late stage, the application of various EOR technologies, such as acid fracturing, CO2 flooding, air foam flooding and polymer flooding, resulting in the service environment of oil and gas gathering pipelines becoming more and more complex and harsh, such as high temperature, high pressure, high H2S/CO2, Cl- and bacteria, corrosion failures became one of the biggest challenges of oil and gas gathering pipelines.
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At present, there were ten common crossing modes in long-distance oil and gas pipelines[1,2]. There were six ways of tunneling, such as large excavation, horizontal directional drilling, shield tunnel, drilling and blasting tunnel, ramming pipe and pipe jacking. There were four ways of spanning methods, such as truss crossing, arch bridge crossing, suspension cable crossing and cable-stayed bridge crossing. Crossing by shield tunneling, as a pipeline laying method with high mechanization and automation, extensive applicable strata and high safety, has been widely used in recent years.
With growing concern for global warming resulting from fossil fuel usage, the use of nuclear energy has provided a cleaner alternative to power generation. Radioactive fuel such as Uranium Oxide has gained significant usage today. Almost 20% of the electricity generated in the US comes from nuclear energy.
When WIT Inc. was asked to rehabilitate the Alta Vista Standpipe, the first order of business would be to conduct a comprehensive tank evaluation in order to determine the overall condition, and also, to compile an inventory of deficiencies, repairs and upgrade objectives so that the project manual for the bid phase would include all necessary work to bring the tank to current AWWA standards.
The heart of any safety commitment from an organization must come from the leadership. The leadership must create a culture that places an enduring value and priority on safety by everyone at every level of the organization.
Remote monitoring of corrosion and cathodic protection using various methods have matured for decades with the onshore pipeline industry. With increasing activity offshore, and the highly corrosive and inaccessible environment taken into consideration, it is only natural that remote monitoring technology will find its way into this field. Offshore structures of steel are protected against corrosion with protective coatings and/or cathodic protection.
Computerized maintenance painting management programs are used to inventory painted items, maintain historical coating data, optimize the scheduling of painting activities, and develop budget estimates for the work. While the sophisticated programs are quite effective, their true benefit is not realized unless someone takes ownership of the program, updates the data every few years, and uses the wealth of planning information that is available.
Corrosion control of buried assets usually involves a double shield: a coating system as a physical insulation barrier, and a cathodic protection system as an additional ad hoc defense. Detection of a corrosion spot at the coating defect stage is the only way to identify the threat before significant metal loss occurs. Furthermore, detection of defects in the coatings of such assets is especially important, since large defects, if left unrepaired, will not only leave the asset locally prone to corrosion, but also drain and weaken the cathodic protection effectiveness for the entire structure. Therefore, identification and characterization of coating anomalies is critical for the integrity of buried assets.
Overtime, chromium has traditionally been used as a surface coating in numerous industrial application such as automotive and general engineering products because of its excellent wear resistance, low coefficient of friction, high resistance to hear and corrosion. Owing to its advantages, several deposition methods have been developed to coat Cr on different surfaces such as plasma nitriding, vapor deposition, physical coating spray, electrodeposition and others. Among these techniques, electrodeposition stands out because of its simple and versatile approach to producing Cr deposit under ambient temperature and normal pressure, with benefits of low cost, high deposition rate, good homogeneity of coating thickness, and intriguing ability to coat substrates of complicated geometrical forms.
Components utilized in oil field operations are often exposed to harsh environments. Corrosion and wear of components and piping can be considered one of the main causes of failure. These components are exposed to high flow rates, high pressures, and other environmental conditions.
Testing cured coatings for flaws and defects is often a crucial part of the acceptance process for a coating assessed against its specification. This is particularly the case for pipeline and storage tank coatings and for coatings applied for corrosion protection, where discontinuities in the coating can lead to premature failure.