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The carbon steel lines carrying brackish water associated with a heavy oil SAGD (Steam Assisted Gravity Drainage) operation in Northern Alberta experienced severe localized corrosion. This is a continuation of a previous study of similar failures at a similar facility.
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The model was evaluated and effects of various parameters on corrosion rates are described. Corrosion rates obtained from the model are compared with actual field and lab testing data as a basis to quantify accuracy and efficacy.
In the oil and gas industry, sand production can lead to blockage of pipelines, corrosion and erosion, which may cause the failure of the fluid transport system, pipeline leakage, and consequently environmental contamination. In the process of fluid transportation, the pipe walls are always impacted by particles entrained in flowing fluid. As a result, the corresponding erosive wear may be detrimental to pipe wall structural integrity. Although sand screens and gravel packs are frequently used to minimize sand production, technical and economic challenges or limitations with these practices are still present in the industry1.
This paper presents preliminary computational fluid dynamics and experimental results from a systematic study designed to show how the above mentioned empirical “rotating cage” equation correlates with the average or maximum wall shear stress on the rotating coupons, at different conditions.
Erosion, a mechanical process during which material is removed from the pipelines and other flow-containing equipment, can occur when solid particles such as sand are carried by the flow. Erosion is more critical when there is a change in the flow direction, such as particle-laden flows in elbows and tees.
While experimentation is a possible approach to obtain erosion rates, the conditions under which tests could be performed are limited in some respects.
HISTORICAL DOCUMENT. Methodology for applying the internal corrosion direct assessment (ICDA) process for multiphase flow onshore and offshore pipeline systems.
This standard practice outlines a methodology to assess pipeline integrity because of the threat internal corrosion in on- shore and offshore pipelines and other piping systems that normally carry multiphase fluids (gas, water, and oil) termed multiphase flow internal corrosion direct assessment (MP-ICDA). Liquid separators (drips), compressing stations, vessels, and other equipment not related to pipelines are not included in this standard. This standard applies to pipelines, and piping systems both onshore and offshore, containing carbon dioxide (CO2), hydrogen sulfide (H2S), oxygen (O2), and other corrosive species. Additionally, this standard applies to pipelines that continuously contain a liquid phase (water and condensate and/or oil and/or petroleum compounds), a possible solids content of various mineral scales, biofilms, or corrosion product compounds, and a continuous gas phase with fluid conditions that are not specifically covered by NACE SP0110 for wet gas internal corrosion direct assessment (WG-ICDA). Additionally, solids may be included as a phase by itself and may also be included in multiphase flow analysis of fluid streams
In the oil and gas industry sand production is a major cause of erosion which can badly affect production rates because of damage to surface and subsurface facilities and equipment such as pumps, valves, elbows and pipelines. In past few years, research work on sand production has been conducted in different ways including erosion prediction, and control and sand monitoring to prevent sand production and its damages to facilities. The continuous monitoring of sand in the flow stream is extremely useful to minimize erosion damage to the production facilities.