Corrosion Engineering

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  • Pipeline corrosion mitigation

    InnoTech Alberta's ongoing efforts to improve pipeline integrity and manage corrosion...



The Corrosion Engineering team assesses materials performance in corrosive environments and evaluates integrity management solutions for the energy industry. Specialized sour service laboratories and pilot scale flow loops provide unique facilities for industry testing, research and development.

The Corrosion Engineering team operates under the Oil and Gas sector.

Program Capabilities

  • Flow loops for evaluating corrosion-monitoring technologies and corrosion-mitigation strategies
  • Under deposit corrosion (UDC) in aqueous and hydrocarbon environments
  • Microbiologically influenced corrosion (MIC)
  • Evaluation of systems using electrochemical approaches to determine corrosion susceptibility
  • Assessing corrosion under mechanical stress to simulate environmental cracking
  • Chemical mitigation testing (e.g. inhibitors, biocides, wax dispersants, asphaltene dissolvers, etc.) for oil and aqueous systems
  • Corrosion resistance, anti-fouling properties and integrity of coatings
  • Testing according to various NACE, ISO, ASTM and CSA standards

Pilot Scale Oil Flow Loop

  • Pipeline operation simulation with controlled flow rate and temperature
  • Pipeline inspection gauge (Pig) design evaluation
  • Chemical inhibitor evaluation
  • Real time corrosion rate monitoring
  • Simulation of localized corrosion (pitting and MIC)

Sour Service Testing Facilities

  • Proof ring testing (NACE TM0177, Method A) with stresses up to 200,000 psi (based 0.252" diameter specimen) and 110ºC
  • Stirred autoclaves for sour exposure testing up to 350ºC, 345 bar (5,000 psi)
  • Autoclaves for mechanical loading in environments up to 320ºC, 200 bar (2,900 psi)
  • Rotating cage capabilities for corrosion inhibitor evaluations (ASTM G184)
  • Hydrogen permeation measurements under mechanical loading sour environmental conditions

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Pilot Scale Slurry Flow Loop

  • 8-inch diameter flow loop for assessing erosion-corrosion for aggressive systems (e.g. oil sands tailing lines)
  • Solid concentrations up to 30%
  • Flow velocities and temperature limits of 7 m/s and 80ºC, respectively

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Impingement Slurry Jet

  • Lab-scale wear testing using abrasive slurry
  • Coupled with electrochemical techniques to analyze erosion-corrosion synergy
  • Control over slurry composition, temperature, impingement angle and test material

Corrosion and Chemical Services Laboratory

  • Full service chemical laboratory equipped with Differential scanning calorimetry (DSC), Pressure DSC, Differential Thermal Analysis (DTA), Thermogravimetric analysis (TGA), x-ray diffraction (XRD) and Thermomechanical analysis (TMA)
  • Scanning Electron Microscope (SEM) with energy dispersive x-ray (EDX) spectroscopy for elemental analysis
  • Crude oil sludge deposit analysis of the hydrocarbon, aqueous, solids and microbial components
  • Failure/root-cause analysis on corroded materials employing state-of-the-art characterization techniques
  • Field corrosion evaluation as per NACE-ICDA

Electrochemical Analysis Techniques

  • Rotating Cylinder Electrode (RCE) - Inhibitor evaluation according to ASTM G185
  • Linear Polarization Resistance (ASTM G59)
  • Cyclic Potentiodynamic Polarization (ASTM G61)
  • Critical Pitting and Crevice Temperature (ASTM G48 and G150)


Key program activities include:

  • Pipeline Integrity and Corrosion Monitoring (PiCoM) – Industry working group to address pipeline corrosion and integrity issues with a current focus on internal corrosion monitoring and mitigation
  • Materials and Reliability in Thermal (MARIOS-T) Recovery Processes – assessment of materials performance in oil sands thermal recovery operations
  • Analytical and Corrosion Services – Standardized and customized testing services for industry and small-medium enterprises (SMEs)
  • Research and Development – Customized testing methodologies to mimic real-world conditions, technology development, qualification and deployment to the field

For more information, contact:

Tamer Crosby, PhD, PEng
Team Lead
Corrosion Engineering