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Carbon steel is the main construction material in HYDROFLUORIC ACID (HF) alkylation units. Carbon Steel has good corrosion resistance to anhydrous HF (AHF) below 160 degrees fahrenheit (71 C). The corrosion resistance is due to the formation of an inorganic iron fluoride scale on the carbon steel surface that protects the steel from futher corrosion. The presence of an adherent and continuous scale is essential in keeping the corrosion rate at a minimum.
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Residual elements (RE) in carbon steel, not specifically included in the specified steel, appear to influence the corrosion rate under certain conditions, especially in services involving hydrofluoric acid (HF). The relative proportions of RE, specifically %C, %Ni, %Cu, and %Cr in carbon steel base and weld metals used in refineries, especially in alkylation processes with HF as the catalyst, significantly impact corrosion behavior. Studies described in the literature show corrosion damage with high RE (Cu + Ni + Cr >0.20) components as compared to low RE (Cu + Ni + Cr <0.20) components.
In this study, electrochemical corrosion testing was performed on a 3-inch pipe elbow section with high REs that had developed a through-wall leak in service. Test results were compared to those obtained on a similar pipe elbow section with lower REs. The samples were exposed to 50% HF at room temperature and at 65°C. Linear polarization resistance (LPR) corrosion rates were measured at both temperatures. Potentiodynamic (PD) polarization scans were performed on samples of low and high RE steel exposed to 50% HF at room temperature.
Test results indicated that LPR corrosion rates were higher for the high RE carbon steel samples than for low RE carbon steel samples at both temperatures. PD scans showed that the critical current densities were higher for high RE steel than for low RE steel.
Saline Water Conversion Corporation (SWCC) is the largest producer of water by its different water desalination plants distributed around the kingdom. Produced water is transmitted through underground pipelines. These pipelines are more than 8,000 KM in length and varying diameter from 8 thru 75 in.
Biocides are used to control problematic microorganisms in the oil and gas industry. High doses of biocides cause environmental and operational problems. Therefore, using biocide enhancers to make biocides more effective is highly desirable. 2,2-dibromo-3-nitrilopropionamide (DBNPA) is a popular biocide because it is broad-spectrum, effective, kills microorganisms immediately upon addition, and it degrades rapidly. D-amino acids are natural chemicals that have been used in lab tests to enhance biocides to treat biofilms. In this work, D-tyrosine was used to enhance DBNPA against Desulfovibrio vulgaris biofilm on C1018 carbon steel. After 7 days of incubation, the weight loss of coupons without treatment chemicals in culture medium was found to be 3.1 ± 0.1 mg/cm2. With a treatment of 150 ppm (w/w) DBNPA, the weight loss was reduced to 1.9 ± 0.1 mg/cm2 accompanied by a 1-log reduction in the sessile cell count. The combination of 150 ppm DBNPA + 1 ppm D-tyrosine achieved an extra 3-log reduction in sessile cell counts and an additional 30% reduction in weight loss compared with 150 ppm treatment of only DBNPA. The combination also led to a smaller maximum pit depth. Linear polarization resistance (LPR), potentiodynamic polarization and electrochemical impedance spectrometry (EIS) tests corroborated the enhancement effects.
Traditionally, oil recovery operations are subdivided into primary, secondary and tertiary stages. EOR is commonly classified as tertiary recovery, where gases, liquid chemicals and thermal energy can be used to enhance the displacement of reservoir fluids. Different sources divide EOR into two to five categories, one particular method, polymer flooding, is based on increasing the fluid viscosity by adding a polymer to the injected water. Polymer EOR is a mobility-control process using a polymer-augmented waterflood, typically a solution of partially hydrolyzed polyacrylamide (HPAM) or polysaccharides, which is injected to displace oil towards production wells.
The following paper discusses models and procedures for estimating the corrosion-related metal loss and loss patterns on carbon steel exposed in a marine environment. This includes immersion and atmospheric exposure and the impact of coatings.
Microbial influenced corrosion is a type of corrosion caused by microorganisms attached to the metal surface or by their activity. The first one who noted the MIC was Gaines in 1910 [1], followed by research about the graphitization of cast irons in anaerobic soils in 1934 [2]. Nowadays, attention to MIC problems increased significantly.
The Hanford site contains approximately 55 million gallons (2.08 x 108 liters) of radioactive and chemically hazardous wastes arising from weapons production, beginning with World War II and continuing through he Cold War era. The wastes are stored in 177 carbon steel underground storage tanks, of which 149 are single-shell tanks (SSTs) and the remaining are double-shell tanks (DSTs). Historically, tank failures have been associated with the SSTs
Oil & Gas flowlines are paramount for safe and reliable production of hydrocarbons, ensuring their integrity is one of the key tasks for all operators. Petroleum Development of Oman (PDO) manages around 11,000 Km of flowlines and connects to production stations more than 400 wells across more than 50 fields every year. Applications for these flowlines vary from the traditional Oil & Gas transmission to other applications such as water injection, polymer flood and steam injection. All these diverse applications involve multiple operation environments ranging from benign fields with low CO2 < 0.5 mole% and minimum H2S to very aggressive environments with CO2 and H2S concentrations well above 10 mole%, combined with a wide range of salinities and water cuts, with chlorides concentrations ranging from 5,000 to 200,000 ppm and water cuts from almost nil to more than 95%. The challenges encountered in safe and economic development of these assets across such a wide range of conditions are numerous; therefore, the material selection and designed methods to manage flowlines integrity are complex with no single solution approach to address the myriad of different conditions. This paper present two cases of metallic and non-metallic materials installed in PDO flowlines showing their historical field performance and discusses the strategy adopted for the material selection of flowlines.
In aqueous carbon dioxide (CO2)-saturated environments, such as those found in geothermal energy, oil and gas and carbon abatement industries, various naturally occurring layers can be found on the internal surface of carbon steel infrastructure, such as pipelines, as they corrode in the mildly acidic conditions. Amongst the most commonly found layers are iron carbonate (FeCO3), iron carbide (Fe3C) and magnetite (Fe3O4). FeCO3 can offer corrosion protection to the underlying steel when formed under certain conditions, as too can Fe3O4. Fe3C is typically associated with enhancement of electrochemical activity of carbon steel and is revealed due to preferential dissolution of ferrite in the steel microstructure – through the formation of a porous network at the steel surface. Each of these layers play a fundamental role in the uniform and localized corrosion of the underlying carbon steel.