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This manuscript provides case study data from subsea crude oil pipelines that addresses the questions of how to obtain the best quality samples from pig returns for microbiological testing, and what are the relative merits of different test methodologies.
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A risk assessment model developed as part of a holistic study conducted to evaluate the condition of subsea pipelines. A systematic semi-quantitative risk-based model was developed to identify, analyze and evaluate risk associated with each subsea pipeline.
A new field gradient (FG) measurement tool has been developed for cathodic protection (CP) inspection of subsea facilities. The paper presents a case where FG data and CP modelling have been used to optimize CP retrofit design, cutting costs by 50%.
Corrosion in Mooring systems for permanently moored floating production units has been identified as a problem area by authorities as well as industry. A Joint Industry Project (JIP) initiated by the Bureau of Safety and Environmental Enforcement (BSEE) with participation from major global oil and gas operators as well as equipment suppliers was established in 2014 to review the problem area. 1 Studies performed as a part of this program have shown that especially mooring chains located in tropical waters have shown signs of rapid corrosion, both general and localized with corrosion rates significantly larger than those specified in design standards. Increased corrosion allowance, as well as increased inspection requirements, have been recommended and corrosion has been reported as the leading cause for pre-emptive replacement of mooring.
In the oil and gas industry, the major standard for material selection today is ANSI1/NACE2 MR0175/ISO 15156 Parts 1-3. [1] While this standard deals extensively with environment cracking and its prevention for materials under exposure to production environments containing H2S, CO2, chlorides, and sulfur, it does not include any guidance or material requirements for resistance to environmental cracking (such as hydrogen stress cracking – HSC, or otherwise) under variable subsea conditions that involve exposure to seawater with varying levels of cathodic protection (CP). ISO 21457 [2] provides further guidance for materials selection and corrosion control for oil and gas production systems but does not provide adequate coverage of the issue of environmental cracking in subsea applications with CP.
Mineral scale deposition is one of the major flow assurance issues for the oil and gas industry. When an oil or gas well produces water, there is the possibility that scale could form either by the mixing of incompatible waters forming oversaturated brine or by direct precipitation of the water that occurs naturally in reservoirs due to the changes in pressure, temperature, or pH. Scale inhibitors are commonly used to prevent mineral scale formation during oil and gas production and mitigate this flow assurance issue.
Aluminum alloys have high strength to weight ratio, and during the years they have been used successfully in the maritime industry, due to their good corrosion resistance when correctly applied (e.g., properly selected). In the subsea environment, the oil and gas industry currently uses aluminum alloys for Remotely Operated Vehicle (ROV), but due to its limited information regarding long-term application in seawater, these alloys are not generally selected for subsea structural purposes. The aim of the current paper is to compare the performance of three different aluminum alloys through electrochemical tests in artificial seawater and under accelerated intergranular corrosion (IGC) tests. Samples were tested through potentiodynamic polarization (ASTM(1) G61), under aerated and de-aerated environments, and in order to compare their IGC resistance, they were tested following ISO(2) 11846 (method B). The polarization curves revealed that the open circuit potential (OCP) increased when the solution moved from de-aerated to aerated. Additionally, no improved performance was seen from any alloy tested concerning pitting and repassivation potential, even when subjected to different aeration conditions. Finally, the IGC testing was satisfactory to distinguish the alloys’ IGC resistance.
The hydrocarbon exploration in the ocean and deep sea was started as early as early as the 1850s, when the first drilling was carried out in California, USA. Other early oil explorations activities were later recorded in Pakistan (1886), Peru (1869), India (1890) and Dutch East Indies (1893).1 In 1930s, the development of the Gulf of Mexico as an offshore area started with oil first being produced in 1938.1 The production from the North Sea brought more technical challenges to the offshore industry.