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Wastewater coming from both municipal and industrial activities present corrosive properties toward metals and can in certain cases exceed the tolerances of the most often used stainless steels such as 304L and 316L, thus resulting in the need of superior alloys. The main factors influencing the corrosiveness of the fluids in wastewater treatment plants are high concentration of halides (more specifically chlorides), H2S, low pH, temperature and their combined action. Corrosiveness of incoming fluids at a municipal wastewater treatment finds its roots in the municipal collection network.
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Many asset owners struggle to identify the root cause of fluctuating corrosion rates due to unreliable inspection data. Facilities worldwide are tasked with monitoring thousands of Condition Monitoring Locations (CMLs) with established NDE techniques such as manual ultrasonic testing and radiography. While these techniques can provide valuable “snapshots” of the condition of particular locations, limitations and inherent errors can compound leading to ill-advised decision making. Manually taken thickness data can vary greatly and result in unwarranted complacency or excessive and costly inspections.
Electrical potential surveys are typically required to be completed on a periodic basis on cathodically protected structures such as underground pipelines. However, proving that a cathodic protection system is providing the degree of corrosion protection required can often be a time-consuming and error prone endeavor. It is a typical practice, and often required, to interrupt the CP source(s) to carry out these surveys, the accuracy of which is affected by several factors, including the presence and inherent function of DC decouplers.
Irradiation assisted stress corrosion cracking (IASCC) is a phenomenon caused by neutron irradiation of austenitic stainless steels (SSs). The crack growth rates (CGRs) of IASCC for boiling water reactor (BWR) components are needed for assessments to ensure component integrity. The CGR formula has been proposed as a function of the stress intensity factor (K).
The bulk of a pipeline coating is shop applied and those processes are typically automated. Becausethe automation of pipeline coating has so many controls, there is little need to address the inspection on the body of the mainline coatings. As such, this paper will address inspection of pipeline specific coating types and their unique considerations in a field environment. It will address concerns around tie-ing into other coating types and compatibility.
As onshore pipeline rights-of-way become more congested and urban sprawl increases, the number of horizontal directional drills (HDDs) will likely increase. HDD is a trenchless pipeline installation method that requires drilling a larger pilot hole where the mainline pipe can be subsequently pulled through the drilled hole. However, HDDs have an increased probability for coating damage, even when coated with traditional mill or field applied abrasion resistant overcoat (ARO). This coating damage includes abrasion, impact, gouging, denting, tearing, bending, etc. and that damage may exist for the life of the pipeline due to an HDD being inaccessible for future maintenance.
At present, with the increasing in demand for natural gas, all gas production companies are increasing their efforts in natural gas exploration and development. Corrosion is one of the problems during the wet gas transporting, and this can be solved by adding corrosion inhibitor(CI) in most case. However, there are no standards for the Cis performance used in gas gathering and transportation pipelines, which may lead to some gapsbetweentheR&Dscientistsandtheneedsofcorrosioninhibitorusers. Based on the demand of some gas production companies for the CIs, this paper puts forward the performance requirements and corresponding indexes of Cis for natural gas gathering and transportation system, and given some advice on the evaluation method.
Governments and energy companies are increasingly looking at hydrogen as an alternative to fossil fuels, and it is considered that without hydrogen the world cannot aim to be a net zero carbon economy by 2050. Consequently, hydrogen is currently enjoying unprecedented political and business momentum, with the number of policies and projects around the world expanding rapidly. Combustion of hydrogen does not produce greenhouse gases such as carbon dioxide and methane, particulates, sulfur oxides or ground level ozone. Thus, hydrogen offers ways to decarbonize a range of sectors, as well as help improve air quality and strengthen energy security.
Laser cleaning has been an effective tool in manufacturing and industrial applications for over 20 years. Cleaning, as well as cutting and welding, has shown vast improvements in repeatability and precision with the use of laser technology [4]. Previous bonding techniques such as mechanical fixturing and welding can be inconsistent and cause issues like increased structural weight, decreased structural integrity, galvanic corrosion, and many more potential failures [5]. Laser cleaning may propose a viable option for adhering materials to reduce weight and increase repeatability. Welding practices continue to develop to reduce both weld thickness and porosity. Porosity in welds is typically caused from failure to prepare the surface adequately [1]. Failures in both welding applications and adhesive bonding applications can be reduced with the use of laser technology.
Enbridge is proposing to develop a program that utilizes state-of-the-art technologies and proven inspection methods to prescribe interventions related to external corrosion mitigation using a predictive, integrated approach. This new program embraces complex problems by collecting, analyzing, and integrating environmental, pipeline integrity, and corrosion control data to predict external corrosion risk with sound engineering models (mechanistic, reliability and risk) to anticipate, prevent, and contain unexpected events.
Many utilities around the world are pursuing long-term operation (LTO) of their nuclear power plants beyond the initial licensing period. In the United States, the majority of the renewed licenses have allowed the period of operation to be for up to 60 years and a few renewed licenses of up to 80 years of operation, with comparable efforts worldwide. Aging Management Programs (AMPs) are a key element in long-term operation of nuclear power plant and require effective implementation to ensure long-term safety and reliability of vital systems, structures, and components (SSCs). Typically, aging management implementation strategies have been focused on near-term obligations, and these may not be optimal for accomplishing longer-term reliability and sustainability objectives. Therefore, to optimally manage the potential impacts of aging, risk insights can be leveraged using a consistent and sustainable Framework that would focus on high-value actions while reinvesting knowledge and resources. This would allow the implementation of AMPs to enhance and optimize inspection, repair, and mitigation activities.
Very often the life of a corrosion protection paint coating system will not meet the design life of the steel structure it is supposed to protect. Decisions about coating selection are usually focusing on the costs for the initial construction, ignoring the certain future maintenance costs. The total cost of ownership includes the initial cost plus the maintenance, operating and finance costs over the life of a structure. Repeated maintenance operations, and resulting downtime, can add significantly to the total cost of ownership.