Technical Expertise

Technical Expertise

Providing Technical Services to the Oil and Gas Industry and Green Energy

Our experimental facilities and modelling capabilities will allow us to simulate real reservoir and pipeline conditions, providing clear operational recommendations for our clients.


Hydrate measurement for multicomponent systems
  • Gas (natural gas, CO2…) and liquid hydrocarbons (oil, gas condensate…)
  • Condensed water and formation brines
  • Organic inhibitors (alcohols, glycols…)
  • Drilling muds and completion fluids
  • Wax (e.g., solids co-precipitation studies) and inhibitors
  • Corrosion inhibitors
  • Hydraulic fluids
  • Process/product gases/liquids and chemicals
Phases compositional analyses
  • Amount and composition of hydrates
  • Aqueous and hydrocarbon phase compositions
  • Inhibitor (e.g., methanol) loss to the vapour phase
  • Water content of natural gases
  • Simulation of various production scenarios (e.g. subsea separation)
Kinetic Hydrate Inhibitor
  • Kinetic Inhibitor (KHI) induction times
  • KHI Crystal Growth Inhibition tests
  • Hydrate formation and dissociation rates
  • Simulation of various operating scenarios (e.g., shut-in, start-up)
  • Compatibility of other production chemicals (e.g., corrosion inhibitors)
Anti-Agglomerant Performance andcold Flow /HydraFLOW studies
  • Viscosity of hydrate/water/oil slurries
  • Effect of water cut, salt, natural inhibitors
  • Simulation of various operating scenarios
Flow loop studies
  • LDHI assessment
  • AA performance
  • Cold Flow/HydraFLOW development
  • Hydrate monitoring and early warning systems
Hydrate blockage removal and other studies
  • Removal of hydrate blockages in wells and flowlines
  • Hydrate formation, prevention and plug removal during shut-down and start-up
  • Hydrate formation/prevention in chokes and control valves
  • Hydrate formation risks in HIPPS impulse lines


Wax deposition in pipelines and risers is an ongoing challenge for operators, and can have a significant effect on oil production efficiency.

Build-up in pipelines can cause increased pressure drops, resulting in reduced throughput and thus reduced revenue. In more extreme cases, pipelines/processing facilities can plug, halting production and leading to potentially huge losses in earnings.

As a result of increasing understanding of the problems of wax deposition, there are now successful preventative solutions, including chemical treatments and hot oiling. As well as this, Hydrafact have developed a number of reliable in-house methods for studies of heavy hydrocarbon solids deposition in crude oils, including novel QCM and cold finger techniques.

Wax technical services we offer include
  • Wax appearance and disappearance temperatures (WAT/WDT)
  • Wax formation/dissolution rates
  • High-pressure studies
  • Wax inhibitor performance assessment
  • Co-Axial Cold Finger with Shear and temperature gradient through flowline (2,000 psi)
  • High pressure QCM cell with temperature gradient & shear (10,000 psi, -20 up to 250 °C)
  • Wax Early Warning System


Asphaltene deposition can present a major flow assurance challenge.

Deposition can occur in various parts of the production system including well tubing, surface flow lines and even near the wellbore. The conditions of asphaltene deposition are controlled by factors such as pressure, temperature, composition and flow regime. Asphaltene deposition and fouling of flowlines/facilities can greatly reduce productivity and increase operational costs through the requirement for frequent chemical treatment and removal of deposits.

Asphaltene technical services we offer include:
  • Asphaltene content determination (ASTM D 6560)
  • Asphaltene deposition at high-pressure conditions
  • Asphaltene Onset Point (Upper and/or Lower)
  • Asphaltene Inhibitor Evaluation, etc.


Hydrafact and Heriot-Watt University have acquired extensive experience relating to phase behaviour and properties of CO₂- Rich systems in the presence or absence of water and oil.

Our experimental facilities include:

  • Test facilities, including low temperature bath (-80°C)
  • Anton Paar Rheometerand capillary tube for viscosity measurements
  • Pendant drop and capillary risefor interfacial tension measurements
  • Slim tube facilitiesfor Minimum Miscibility Pressure (MMP) measurements
  • High-pressure glass micro model and visual cellsfor simulating CO₂ injection in depleted reservoirs or saline aquifers.

In addition, our comprehensive thermodynamic model HydraFLASH has been tuning and validated using literature and in-house data for predicting phase behaviour and properties of CO₂-rich systems.

View Our Recent CO2 Projects
  • Risk of Hydrate Formation in Low Water Content CO₂ and Rich CO₂ Systems
  • Water Content Measurements of Different Gas Mixtures with varying Carbon Dioxide Content in Equilibrium with Hydrates
  • Experimental and Modelling Study of Vapour Liquid Hydrate Equilibria of Carbon Dioxide Hydrates
  • Wytch Farm Slim Tube Displacement and PVT Tests
  • Water Content of CO₂-Rich Fluids in Equilibrium with Hydrates
  • Equilibrium Experiments and Modelling of CO₂ With CH₄ and Low H₂O Concentrations
  • Risk of Water Condensation and Hydrate Formation in Pipeline Transportation of CO₂-Rich Systems
  • Bubble Point and Density Measurements for a CO₂/H₂ Binary Mixture, 5 Mole% H₂
  • Salt Deposition Due to Injection of CO₂ into a Highly Saturated Saline Aquifer
  • Measurement and Modelling of CO₂ Frost Points in the CO₂-Methane Systems
  • Role of CO₂ Hydrates in Subsurface Storage of CO₂
  • Monitoring CO₂ Diffusion in Subsea Sediments
  • IFT Measurement in CO₂-Oil Systems


Around 2010, based on industrial demand we build an H2S compatible laboratory at Hydrafact

Typical Projects Include:

  • Study on Reversibility of KHI Precipitation with Temperature: Full CGI Approach
  • Study on Reversibility of KHI Precipitation with Temperature: Induction Time Approach
  • Hydrate Laboratory Study
  • KHI Fouling Mitigation

And a lot more.


The precipitation of salt (e.g. NaCl, KCl) is a serious problem and can block the flow path of hydrocarbons.

Salt scaling is particularly severe in wells with high saline (>200 g/l) formation brines which may be near saturation with respect to sodium chloride. The phenomena occur more frequently in gas wells than in oil wells, and can be caused by low pressures, decreasing temperatures and/or the addition of organic hydrate inhibitors.

Salts readily adhere to surfaces, particularly rough surfaces, and are capable of forming very dense plugs, severely restricting flow and thus production efficiency.

Our experimental facilities include:

Salt deposition technical services we offer include:

  • Measurement of salt solubility at surface and reservoir conditions, including the effects of organic inhibitors
  • Assessment of salt inhibitors (e.g., crystal grow modifiers) on deposition conditions and surface adherence


In response to the current challenging climate in the oil & gas industry, Hydrafact is offering a new, cost-effective approach to consultancy based on annual subscription.

Support 24/7

Direct access to experts with 24/7 support on urgent operational challenges

Service Plus+

Discounted priority use of advanced experimental facilities.

Power more

Innovative solutions to flow assurance problems.

Our Tailor-Made Solutions

Our tailor-made solutions to common problems experienced during field life include:

  • Gas Hydrate plugging, including monitoring & early warning systems
  • PVT phase behaviour & properties of reservoir fluids
  • Emulsion & foaming problems
  • Wax & asphaltene

Subscription Packages

Cover technical advice, thermodynamic modelling, data interpretation and the planning of laboratory test programmes

Are available as subscription tiers and at considerably reduced rates compared to one-off projects

Projects delivered

To learn more about our consulting and technical services.