Controlling microbiologically influenced corrosion in pipelines

    October 14, 2020 Corrosion CONTROLLED, Corrosion Essentials, MIC

    Microbial action has been identified as a contributor to rapid corrosion of metals and alloys exposed to soils; seawater, distilled water, and freshwater; crude oil, hydrocarbon fuels, and process chemicals; and sewage. Many industries and infrastructure are affected by microbiologically influenced corrosion (MIC), including oil production, power generation, transportation, and water and wastewater.

    Experts Richard Eckert, DNV GL—North America Oil & Gas; Dr. Jason Lee, U.S. Naval Research Laboratory; and Dr. Torben Skovhus, VIA University College share their longtime knowledge and experience in preventing and controlling MIC in pipelines.

    NACE: What types of environments and situations can be prone to MIC in oil pipelines?

    Richard Eckert: MIC occurs when chemical, microbiological, and physical conditions support the active growth of biofilms containing specific types of microorganisms on the pipe surface and the resulting growth aids the electrochemical processes, leading to corrosion. The most important parameter is the presence of water, even if only a small volume is present. In liquid hydrocarbon pipelines, water can accumulate when there is low or no flow, such as in a facilities piping dead leg. Transmission quality crude oil often contains less than 0.5% volume sediment and water; however, if 5,000 barrels of crude are not flowing in a section of the pipeline, 0.5% or 25 barrels of water could still drop out and settle in a low point in the pipeline elevation profile. If the pipeline begins flowing at a velocity high enough to entrain the water, eventually it will be removed. However, if the water is not re-entrained in the hydrocarbon, then the accumulated water could be removed by pigging or treated with a biocide to reduce the potential for MIC.

    It is often believed that low numbers of culturable bacteria in the liquid phase indicate that MIC is not a threat for a particular pipeline; however, the numbers and types of microorganisms that are present in the liquid phase are not always representative of the types and numbers attached to the pipe surface. These attached, or sessile, microorganisms in biofilms are those that have the greatest influence on localized corrosion. The industry is starting to pay more attention to biofilms because of their contribution to the threat of MIC, and a new NACE International task group (TG 586) was just formed to develop methods of testing biocides to control corrosion under biofilms. Another newly formed NACE task group (TG 561) is developing a standard that will help standardize the use of molecular microbiological methods (MMM); for example, DNA-based and enzyme-based test methods that have gained popularity in the last decade in the oil and gas industry. MMMs provide far more information about biofilm communities than traditional culture-based methods and improve operators’ ability to diagnose MIC problems in their assets.

    Dr. Jason Lee: Working for the Navy, my experience in MIC is more in the marine environment, in general, rather than oil pipelines. However, I have been involved with projects that examine the interactions of hydrocarbon fuels under storage conditions in marine environments. Military platforms and facilities store huge amounts of fuel. Some of these systems have seawater intentionally introduced to provide ballast while others have unintentional seawater/freshwater introduction. Microorganisms require water for proliferation and growth. Hydrocarbon fuels provide carbon sources (electron donors) for microbial metabolism. Seawater itself is highly corrosive and can drive abiotic corrosion. The addition of fuel to seawater can cause the microbial components to produce corrosion metabolites such as sulfides and acids, and in combination with the chloride from seawater, produce a highly corrosive environment.

    Dr. Torben Skovhus: If seawater is applied as a secondary recovery strategy to maintain the downhole pressure of the oil reservoir, problems can rapidly develop from hydrogen sulfide (H2S) being produced either in the reservoir, the process pipework, or in the pipeline itself. The problem can develop rapidly if a detailed corrosion management strategy has not been put in place.

    NACE: In your experience, which are the most effective methods to control MIC in pipeline systems?

    Richard Eckert: By far, mechanical cleaning using various types of maintenance pigs to disrupt and remove biofilms is one of the most effective ways to control MIC in pipelines. Even if biocide or other chemical treatments are used, biofilms may not be adequately penetrated by these chemicals and thus their effectiveness is limited unless the biofilm can be broken up or removed by pigging. A combination of chemical treatment and pigging may be used when the threat of MIC is significant. Chemical treatment with biocides and surfactant compounds is sometimes applied continuously at a low dose and/or intermittently as a batch treatment. Facility piping dead legs may be flushed on a regular basis to remove water and solids, and then have biocides added to help control biofilms in between flushing treatments.

    It is nearly impossible to prevent bacteria from entering a pipeline with the gas or liquids being produced or transported, as bacteria are very small (i.e., only a few microns in length) and can reproduce exponentially under the right conditions. Similarly, it is impossible to kill all microorganisms in a pipeline, since they are often protected by the solid deposits and the exopolymers encompassing the biofilm. Small organic and inorganic solid particles that make up pipeline “sludge” deposits provide water films, nutrients, and present an enormous surface area for attachment and protection of microorganisms. So keeping pipelines clean of deposits by controlling flow rates, enforcing product quality requirements, and pigging where possible, are important control measures.

    Dr. Jason Lee: The most effective method to prevent MIC is diligent and proper housekeeping. All systems that I work with are open to the environment and thus can never be sterile. Biocides are useful in some closed systems, but open systems that have frequent water addition are not suitable for biocide treatment. Coatings are often used to prevent microbial access to the underlying metal substrate but coatings can chemically or mechanically degrade over time. Keeping detailed records of systems that are known to be susceptible to MIC is an absolute must; then proper maintenance and cleaning cycles can be implemented to prevent biofilms from becoming corrosive. The interval needed between cleanings is different for each system.

    Dr. Torben Skovhus: Cleaning by pigs and targeted chemical treatment is critical. As each reservoir and oilfield is different when it comes to which microorganisms live there, an individual threat assessment will need to be implemented regarding MIC. The threat assessment will need to take into consideration several parameters such as operational parameters and both biotic and abiotic corrosion mechanisms.

    NACE: Briefly describe a situation where you have installed a successful program to control and prevent MIC.

    Richard Eckert: One of the first projects I worked on was a large offshore gathering system in which both biocide and corrosion inhibitor were injected at nearly every platform, resulting in very high chemical costs but producing few positive results in terms of controlling leaks due to internal corrosion. A new monitoring program was instituted that emphasized analysis of biofilms and corrosion on extended analysis (EA) coupons rather than relying on bacteria culture testing of liquid samples. This approach provided information about the chemical and microbiological conditions that were primarily causing the corrosion (i.e., either MIC or abiotic corrosion) at each platform and ultimately only one type of chemical (inhibitor or biocide) was selected for use based on this information. After less than a year of using this new approach based on biofilms and the resulting corrosion, the internal corrosion leak rate was drastically decreased and continued that declining trend for many years thereafter. For most of my career in the oil and gas industry, I have used a similar approach where mitigative treatments are not implemented until the primary cause of the internal corrosion is understood. As NACE standards for assessment of internal and external MIC state, microorganisms can be found nearly anywhere but their presence alone is not an indicator of the potential for MIC.

    Dr. Jason Lee: As noted previously, proper cleaning procedures and intervals are crucial for MIC prevention. As an example, one project I worked on examined the regrowth of fungi on organic coatings after different cleaning methods. The main result of the study was that very few cleaners completely removed the fungal contaminants. Visually the surfaces looked clean, but fungi remained after microscopic examination. A specialized cleaner was developed to completely remove fungal hyphae and spores.

    Dr. Torben Skovhus: A platform in the North Sea suffered from both increased levels of H2S in the production system and MIC in the topside installations. A detailed mapping of growth hotspots of microorganisms and H2S mapping (all three phases) was carried out by a diverse team of managers, production chemists, microbiologists, and corrosion engineers. With the full overview of where the effort should be focused, we managed to get the problem under control within a few months. It was mainly due to the diverse nature of the team and the high-level focus on multiple lines of evidence approach to corrosion that we managed to bring the production back to a safe stage.

    NACE: What improvements could operators make in their programs for managing MIC?

    Richard Eckert: I think the main areas for improvement include the following;

    • Focus on sampling biofilms on surfaces instead of only collecting liquid samples for microbiological analysis. MIC occurs under deposits and biofilms—the numbers and types of microorganisms in the liquid phase do not always accurately reflect those attached to the surface.

    • Work to include MMMs, such as adenosine triphosphate (ATP) analysis, in monitoring programs rather than using only bacteria culture media, since many microorganisms cannot be cultured in typical media.

    • Apply rigorous forensic analysis of corrosion damage or corrosion failures on pipeline cutouts as a basis for understanding the active corrosion mechanisms in the pipeline and then focus mitigation methods on those mechanisms.

    • When trying to determine if MIC is a problem in a specific asset, assess the potential for MIC along with other abiotic threats to understand potential interactions and which mechanisms play a leading role.

    Dr. Jason Lee: Recording as many observations from known MIC cases is the “lowest-hanging fruit.” The most frustrating part of trying to solve a MIC problem is the lack of background information, historical operating conditions, or component chain of custody. A key to diagnosing MIC is determining the difference in system performance before and after a suspected MIC event. Therefore, even if your system has never shown signs of MIC does not mean it (or a similar system) won’t incur a MIC event. Keeping detailed records on the materials of your system as well as the current operating parameters is of immense value.

    Dr. Torben Skovhus: They should skip the culture-based tests, which in my opinion give a lot of data with limited value. Instead, more sophisticated measures based on methods from biotechnology (MMM) should be implemented. Fewer data points of much higher quality would give the operators a better idea if the infrastructure suffers from MIC and to what degree. In addition, setting a corrosion management team with staff that can interpret data obtained from MMM would be a great step forward for managing MIC more efficiently. Finally, having MIC placed in their corrosion management strategy is crucial to assess, mitigate, and control MIC.

    NACE: Any additional comments?

    Richard Eckert: Managing MIC is like managing any other corrosion threat—It should be a part of a corrosion management system that methodically characterizes threats, applies prevention and mitigation measures, and monitors their continued effectiveness. NACE International published SP21430-2019, “Standard Framework for Establishing Corrosion Management Systems,” that provides guidance on implementing a corrosion management system on any type of asset in any industry. I believe that in order to effectively control MIC and other corrosion mechanisms, a management system approach is essential for success.

    Dr. Jason Lee: MIC is truly multi-disciplinary. MIC includes biological and chemical sciences, as well as metallurgical, materials, and corrosion sciences. I encourage anyone involved with MIC research or prevention to consult experts outside their field of expertise. No one person can understand all the aspects of MIC.

    Dr. Torben Skovhus: If anyone wants to discuss how we jointly can set up strong international alliances for MIC research between academia and industry over the coming decades, I will be more than happy to discuss this with the readers. I have recently observed some unrealized potential in this field that will need more attention in the years to come—both in conventional energy industries, as well as in renewable energy.


    Find microbiologically influenced corrosion resources from NACE International here.

    Source: Materials Performance Corrosion Management Pipeline Integrity Supplement, September 2020, “Controlling Microbiologically Influenced Corrosion in Pipelines,” by Gretchen Jacobson, MP Managing Editor-in-Chief.



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