Nuclear Magnetic Resonance (NMR)
Studies are conducted providing petrophysical properties of core and NMR log calibration. Measurements provide clay conductivity (Qv) and T2 log mean and T2 cutoffs for permeability models and log calibration. Quick Rock Properties provides quick screening of porosity, water saturation, and permeability of core plugs while maintaining the as received saturations in the core. Measurements include Air/brine and oil/brine at ambient conditions or reservoir conditions up to 150°C and 5000 psi NCS with gradient capability.

Capillary Pressure Air/brine or oil/brine porous plate at ambient or reservoir confining stress up to 10,000 psi. High speed centrifuge at ambient, or overburden centrifuge for unconsolidated and friable samples, up to 3500 psi confining pressure and 70°C. Mercury injection up to 60,000 psi for drainage or imbibition.

Electrical Properties
Formation resistivity factor at ambient and confining stresses up to 10,000 psi. Formation resistivity index by porous plate, air/brine or oil/brine method at ambient or net reservoir confining stress. Formation resistivity index by ultra-low rate continuous oil injection (RICI™) with automated data capture. Continuous RI versus Sw relationship determined at net reservoir confining stresses up to 10,000 psi.

Excess conductivity for clay correction by multi-salinity Co/Cw method or wet chemistry CEC.

Stress Measurements
Pore volume compressibility and porosity reduction, specific or effective permeability to air, brine or oil as a function of confining stress up to 10,000 psi.

Wettability
Determination by Amott and USBM methods. Restoration of wetting state using live or dead crude oils.

Relative Permeability
Unsteady state and steady state techniques for Water-Oil, Gas-Oil and Water-Gas displacements in either drainage, imbibition or combination of these displacements, up to 30cm long core or composite stacks. In-situ Saturation Monitoring by the Attenuation of X-rays (SMAXTM) can be provided for all displacements.

Reservoir Conditions Relative Permeability
Live oils and brines with full in-situ saturation monitoring at pressure and temperature up to 10,000 psi and 150°C on cores up to 30cm in length.

Simulation of Flow Experiments
Determines estimates of relative permeability and capillary pressure flow functions by history matching to the laboratory data.

Core Flood
Various analyses can be performed at reservoir pressure and temperature to simulate near well bore conditions during drilling, clean up or completions processes.

Geomechanic Testing
Comprehensive facility providing uniaxial and triaxial testing for static moduli. Dynamic moduli at seismic to ultrasonic frequencies for shear and compressional waves under uniaxial and triaxial stress conditions.

Inorganic Scale
Determination of fluid compatibility and scale potential by modelling and laboratory testing. Evaluation of scale and corrosion inhibitors with reservoir rock material at reservoir conditions. Compatibility testing of the formation with the inhibitors and evaluation of the release of inhibitors with throughput.

Fracture Damage & Proppant Evaluation
Full range of proppant analysis for leak off of fracturing fluid, conductivity, flow back and embedment. Proppant evaluation against API standards. Fracture fluid damage to formation and natural fractures in the reservoir. Modelling and laboratory analysis is provided. Fracture design and input into a 3D fracture model using Gohfer™ which has been shown in the field to simulate proppant transport, reservoir heterogeneity and symmetric or asymmetric designs.

Fluid & Rock Compatibility
Detailed analysis of the rock mineralogy of the formation and introduced fluids provide indications of any incompatibility which may occur in the reservoir.