Core Analysis Services for Conventional Reservoirs

Evaluating grain density, porosity, permeability, fluid saturations, and more to optimize production and maximize recovery

Core analysis provides information for reservoir description, characterization, and simulation; log calibration; recovery methods; and other purposes throughout the life cycle of a field. Our core analysts work with operators to design a study program to address the specific issues of each project.

Wellsite services

Our specialists process and stabilize whole core at the wellsite. The core is cataloged and stabilized for shipment. Schlumberger specialists also provide sidewall coring services using both percussion and rotary sidewall coring.

Routine Core Analysis

The basic description of core material comes from routine analysis. This service includes measurement of porosity, saturation and permeability to answer three fundamental questions about a reservoir. Does the rock contain a fluid-filled space (porosity); does it contain hydrocarbons in that space (saturation); and can those hydrocarbon fluids be produced (permeability)? Core gamma logging provides a link of the core depth to wellbore logging depth, and core computed tomography (CT) scans indicate the core heterogeneity. Core photographs taken in both white and ultraviolet light are used for both documentation and core description.


Clients can use our viewing room to examine a whole core in detail. Cores are used to describe the geology and sedimentology to help understand the optimal way to develop and produce a field. Finer details are obtained using X-ray diffraction, thin sections, and scanning electron microscopy.

Special Core Analysis

Detailed understanding of a reservoir requires additional measurements obtained in the special core analysis laboratory (SCAL). Electrical measurements obtain Archie exponents for calibrating electrical logging measurements of porosity and saturation, and nuclear magnetic resonance (NMR) core measurements determine a formation-specific cutoff value for the relaxation time from an NMR log. Capillary pressure measurements by mercury injection, centrifuge, or porous plate methods indicate distributions of pore throats and are used to evaluate saturation distribution as a function of height in a formation. Relative permeability determines the multiphase flow character of the formation, and can be performed at ambient or elevated conditions of pressure and temperature. Wettability is determined by Amott-Harvey or USBM methods.

Enhanced Oil Recovery (EOR)

Our EOR laboratories evaluate miscible-gas and chemical flooding methods. Core-flow and sandpack studies can be performed for either scenario. Slim-tube and rising-bubble methods evaluate miscibility conditions, and we can provide multiple-contact miscibility, interfacial tension, contact angle, and viscosity measurements. Chemical flooding includes polymer, surfactant, alkali, and combinations of those injectants. Our laboratory evaluates different combinations of chemicals, the optimal salinity, and surfactant adsorption onto the matrix.

Formation Damage

Our laboratory can evaluate formation damage caused by a variety of sources that can occur throughout the life cycle of a field. Tests evaluate return permeability after mud invasion, fluid-rock interactions, fluid-fluid interactions, and damage caused by pressure and temperature changes in the reservoir.

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Laboratory Services for Better Reservoir Understanding

Schlumberger Reservoir Laboratories
More than 25 Schlumberger Reservoir Laboratories around the world support a wide range of characterization projects. Download brochure (6.38 MB PDF)