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Inorganic fouling in oilfields has resulted in millions of dollars of operating expenditure every year since the inception of offshore oil and gas drilling, where mineral scale deposition in tubing, flowlines and downhole equipment leads to significant production downtime. Calcium carbonate (CaCO3) fouling is endemic in oilfield systems, as produced water containing both bicarbonate and calcium ions is prone to form precipitates as a result of pressure changes during production.The release of carbon dioxide gas from the aqueous phase prompts the evolution of carbonate resulting in a rise in pH and consequent precipitation.
Calcium carbonate (CaCO3) scale formation is recognized as a major problem affecting production and transportation in the oil and gas industry. The phenomenon is extensively studied however; very limited work has been carried out to evaluate it in multiphase environments. This work aims to study calcium carbonate surface deposition in a multiphase environment that can replicate more accurately conditions encountered during secondary and ternary oil production. Multiphase conditions induced by introduction of a light distillate within the system were used to create oil in water (o/w) emulsions in order to reflect more accurately the scaling process in oil pipeline transportation. Using a set of bulk and surface analysis techniques such as Inductively Coupled Plasma (ICP) spectroscopy, X-ray powder diffraction (XRD), or Scanning Electron Microscopy (SEM), the results showed that the presence of an oil phase within the system retard the nucleation as well as the dissolution of vaterite, the metastable phase of calcium carbonate. This affect the growth kinetic of calcite and contribute overall to hinder mineral surface fouling. When lead sulfide (PbS) co-precipitates alongside calcium carbonate, the experimental observations show that PbS crystals provides additional seeding point for the nucleation of CaCO3 to take place. In such conditions, the mechanism of surface fouling build-up is altered and proceed via the impact and adhesion of PbS/CaCO3 particles onto the stainless-steel surfaces which result in higher mass gain.
A substation is a place where the power system converts voltage and current and receives and distributes electric energy. When a phase line is abnormally connected to another phase line or ground, a large amount of current will flow into the ground through the grounding bed of the substation. In such case, if metal structures exist such as buried pipelines near the substation, the pipelines often withstand serious electrical interference 1, which causes stray current corrosion of the pipelines 2 and other safety problems.
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Aboveground storage tanks (ASTs) are assets that contain valuable goods for the oil and gas industry. Consequently, monitoring and preventing loss of containment and extending the service life of those assets is a priority for the abovementioned industries. To monitor the degradation process of the tanks, ER probes are typically used to determine the corrosion rates. Corrosion rates can be used to forecast the service life of an asset by estimating the time at which the degradation reaches a critical thickness of the tank. If the corrosion rate is such that the critical thickness is expected to reach below the expected service life of the asset, the lifespan can be extended by corrosion mitigation methods.
Organic corrosion inhibitors (CI) have widespread use in the crude oil refining industry for corrosion protection and mitigation.1 An effective corrosion inhibitor is a chemical substance that is applied in low concentration into a stream which suppresses or mitigates a corrosion mechanism.,2,3,4 Inhibitors can be classified into two classes: adsorption or film-forming with organic inhibitors falling under the adsorption class. In this type of inhibitor a self-assembled structure is formed, where an array of hydrocarbon tails extend away from the metal surface and the polar groups (e.g., N in amines) chemisorb onto the metal surface.2 Over the years, certain classes of inhibitors have been established as industry standards to confront specific corrosion mechanisms encountered throughout the refinery process. Examples include, filming and neutralizing amines used in crude units to combat aqueous corrosion; polysulfides used in FCCU to combat hydrogen blistering, cracking and embrittlement; P-based chemistries to combat naphthenic acid corrosion.5