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The Wafra Joint Operation (WJO) Oilfield is located in the central-west part of the Kuwait-Saudi Arabia Neutral Zone. The Wafra oilfield reserves were first discovered and wells drilled in 1954. This field produces two types of crude oil, Ratawi (light oil) and Eocene (heavy oil), with average water cut of 8085%. During operation, the production wells produce the oil emulsion through mostly coated flowlines to sub-centres (SC) where the sour oil, water and gas are separated. The facility has two gathering fields; Eocene and Ratawi. Eocene has 2 phase separation, whilst Ratawi has 3 phase separation. The sour gas is either flared or flows to the Main Power Generation Plant, whilst the oil is processed to the Main Gathering Center (MGC). The produced waters (PW) are routed to the Pressure Maintenance Plant (PMP).
The abrupt shutdown of the Joint Operations (JO) production facilities led to a deviation from normal shutdown standard operating procedures such as draining and purging of the corrosive production fluids. Consequently, the ensuing deterioration, as a result of corrosion and other associated damage mechanisms, is bound to increase the integrity threats to JO equipment and therefore, negatively impact the restart of operation. The main anticipated damage mechanisms such as microbiologically influenced corrosion (MIC) and under deposit corrosion (UDC) are likely to manifest in the form of pinhole leaks, leading to increased incidence of loss of containment and subsequent negative Environmental, Health and Safety (EHS) consequences. This paper explores different mitigations that were utilized in maintaining the integrity of the JO equipment, including chemical preservation, the use of risk based assessment for the optimization of the chemical preservation methodology and subsequently, the use of enhanced preservation as a long-term preservation approach.
The crude oil produced by fracking or hydraulic fracturing method are high in sulfur content (0.5%)1. The vast majority of vessels that are used in the petrochemical industry to store and transport materials are constructed using Carbon steel. Coating linings used for corrosion protection inside of vessels and tanks must perform under severe conditions such as an exposure to corrosive gasses ( H2S) and carbon dioxide as well as high temperatures, high pressures and often must withstand the cold wall effect and rapid decompression.
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Robust integrity management plans are critical for ensuring the lifespan and preventing failures of manmade infrastructure, including the metal (carbon steel) infrastructure that dominates the oil and gas industry. In this sector and others, many types of corrosion can occur on metal infrastructure, including corrosion that involves the participation of microorganisms, commonly referred to as microbiologically influenced corrosion, or MIC. MIC can be difficult to diagnose as the cause of a given infrastructure failure because it is not a stand-alone mechanism – the physical and chemical properties of a system can influence the types of microorganisms that are present and active, while the metabolisms of these microorganisms can influence the surrounding chemistry and physical properties of a system.
External corrosion on buried pipelines can result in gradual and usually localized metal loss on the exterior surface of failure coating, resulting in reduction of the wall thickness of the metallic structure. Indirect technologies, such as DC basis (i.e. DCVG, CIPS) have been able to detect and pinpoint two conditions in the pipeline, intact and holiday (active surface or coating anomaly) with good confidence. Classic DC methodologies monitor and characterize the state of the coating and effectiveness of cathodic protection by using transfer function principle (i.e. resistance). The formation of an electrochemical cell, such as buried coated pipeline with cathodic protection (steel in electrolyte) is formed at macro scale conditions [1-2]. The expected damage evolution of the coated pipeline includes the electrolyte (soil+water) uptake within the coating