Content Tagged: "corrosion"

In this SPE Tech Talk, SLB dives into some of the application challenges and potential solutions that leverage digital innovation to enable continuous, high-sensitivity detection of corrosion, leaks, and third-party damage to pipelines.

Watch Jonathan Wylde provide a preview of paper 210140 being presented at

Michael Van Spankeren, digital solutions manager for Schlumberger Production Chemistry discusses an innovative approach to controlling corrosion and s

Michael Van Spankeren, digital solutions manager for Schlumberger Production Chemistry will discuss an innovative approach to controlling corrosion an

Learn more about carbon dioxide corrosion prediction in this presentation from the 2021 SPE Virtual International Oilfield Corrosion Conference and Ex

The paper presentation shows the application of a holistic approach to corrosion prediction that overcomes classical pitfalls in corrosion testing and

Sand production is an important flow assurance concern encountered in existing as well as new oil and gas pipelines. In spite of the sand control/management techniques implemented down-hole, fine sand (less than 50-75 microns) often may find its way into the piping components of onshore, offshore, and subsea facilities. This presentation will focus on discussing Tridiagonal teams research on sand transport, erosion and erosion-corrosion in field scale test facilities.

This webinar will look at the peculiarities of CO2, from the Joule-Thomson effect to the injectivity gap, and how the injected stream reacts with well materials (steel, cement, rock) in the long and short term. Must I use CO2-resistant cement? Is wet CO2 corrosion so bad? (Spoiler: no and yes).

Water-in-crude oil emulsions are practically unavoidable during crude oil production and transportation. Mechanical energy imposed by pumps, elbows and pipe reductions facilitates dispersions of water (brine) in liquid hydrocarbons. The presence of natural emulsifiers (e.g., asphaltenes, acids, inorganic solids, waxes) significantly increases the stability of the formed emulsions and thus the associated problems, such as high viscosity, corrosion of pipes/equipment, and quality reduction of the produced crude oil.

Geologic storage of CO2 has gained significance, largely due to it being a green-house gas (GHG) and concerns related to impacts on climate from GHG emissions. The literature and experience from industrial analogs indicate that wellbores (both active/inactive or abandoned) may represent the most likely route for escape of the injected CO2 from the storage reservoirs. Therefore, sound injection well design and life cycle well integrity of all wells is of critical importance in such projects, particularly from a storage perspective of 1000 years or more.

This presentation will review the potential sources of contamination during drilling and hydraulic fracturing, including optimal microbial sampling points and analyzation techniques for a comprehensive field audit plan. Furthermore, it will highlight the risks of microbial contamination to the reservoir, initial production and asset integrity by providing field and laboratory evidence on the detrimental effects of unmitigated microbial growth. Ultimately, this work will review the strengths and limitations of currently applied microbial control technologies and provide recommendations on how to develop a cost-effective biocide program to mitigate risk, maximize production, and deliver high-quality hydrocarbons.

This presentation will focus on a new framework that enables expert users to implement new models over a base 1D multiphase flow solver through its dedicated plug-in architecture. As an example of this framework, the implementation of hydrate formation, transport and agglomeration models and how other flow assurance problems such corrosion, erosion, wax deposition can be tackled using its current modeling capabilities, will be presented.

As wellbores age, the potential for loss of wellbore integrity due to challenges such as, corrosion, stress, fatigue and other factors increase. Stimulation and tertiary recovery methods such as CO2 floods, as well as the introduction of disposal into depleted zones can negatively affect the wellbore by introducing conditions outside of the initial well design criteria. In a given field, many if not all wells will experience similar issues because the well design and life-of-well conditions are similar. Restoring wellbore integrity is a viable alternative to plugging and abandoning these compromised wellbores. Both current and potential issues in production casing and tubing strings can be identified through a number of methods ranging from abnormal annular pressures to cased-hole logging techniques designed to measure the in situ casing dimension, cement presence and bond quality. Once the wellbore condition has been identified, decisions can be made on the best method to restore that wellbore’s integrity. These solutions range from cement squeezes to seal the leak, to patches of various configurations to repair leaking connections, or long sections of the affected casing, to cementing a new string of casing or tubing into the wellbore. This presentation will focus on identification of wellbore conditions and methods you can employ to restore wellbore integrity, thereby restoring production, maximizing recoverable reserves and preventing potential damage to people or the environment. Presented by Greg Galloway

The Butler-Volmer equation for surface electrochemistry potential and Laplace equation for electrolyte solutions have been available in CFD code for a while, but the challenge remains to find a numerically affordable way to model the mass-transfer-limited corrosion rates.

In this webinar, MIC is explained in engineering terms. In addition, existing methods for recognition and treatment of MIC with their limitations and intrinsic drawbacks will be explained.