Reservoir Rock Analysis
Reservoir Rock Analysis - Related Videos
12:18
Pore-scale Imaging and Characterization of Hydrocarbon Reservoir Rock Wettability at Subsurface Conditions Using X-ray Microtomography
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Cited by 17 •
2018
This protocol is presented to characterize the complex wetting conditions of an opaque porous medium (hydrocarbon reservoir rock) using three-dimensional images obtained by X-ray microtomography at subsurface conditions.
09:26
Igneous Intrusive Rock
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2023
Source: Laboratory of Alan Lester - University of Colorado Boulder Igneous rocks are products of the cooling and crystallization of high temperature liquid rock, called magma. Magmatic temperatures typically range from approximately 800 °C to 1,200 °C. Molten rock is, perhaps luckily for humans, an anomaly on planet Earth. If a random and imaginary drill hole were made in the Earth, it would most likely not reach a region of truly and totally molten material until the outer core, at nearly...
07:28
Igneous Volcanic Rock
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2023
Source: Laboratory of Alan Lester - University of Colorado Boulder Igneous rocks are the products of cooling and crystallization of magma. Volcanic rocks are a particular variety of igneous rock, forming as a consequence of magma breaching the surface, then cooling and crystallizing in the subaerial environment. Magma is molten rock that typically ranges in temperature from approximately 800 °C to 1,200 °C (Figure 1). Magma itself is produced within the Earth via three primary melting...
01:30
Reservoir of Infection
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2026
Infectious diseases arise from intricate interactions between pathogens and their reservoirs. A reservoir of infection refers to the natural habitat where a pathogen lives, grows, and multiplies, serving as a continual source of infection. Reservoirs are broadly classified as either living or nonliving, and each plays a unique role in disease transmission, significantly influencing public health interventions and control strategies.Humans act as reservoirs for a wide array of pathogens,...
08:02
Reservoir Condition Pore-scale Imaging of Multiple Fluid Phases Using X-ray Microtomography
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Cited by 28 •
2015
We present a methodology for the imaging of multiple fluid phases at reservoir conditions by the use of x-ray microtomography. We show some representative results of capillary trapping in a carbonate rock sample.
FAQs
Porosity indicates the space available within a rock, whereas permeability describes how readily fluids can move through it. Pore structure connects these properties by determining how storage space relates to fluid movement. Reservoir rock analysis considers them together because storage capacity alone does not establish deliverability. Their relationship helps engineers interpret flow behavior and assess production potential.
Mineral composition and fluid saturation add context to measurements of pore space and flow. Mineral composition characterizes what the rock contains, while saturation identifies the fluids occupying its pores. Examining these properties alongside porosity and permeability gives engineers a more complete basis for interpreting reservoir behavior under reservoir conditions, rather than relying on a single measurement.
Microscopic features provide the small-scale basis for understanding how fluids may move through reservoir rock. By relating these features to measured porosity, permeability, and pore structure, engineers can interpret larger-scale flow behavior more effectively. This connection helps reduce uncertainty in geological and petrophysical models, improving the technical basis for production planning and reservoir evaluation.
Core samples provide physical rock material for examination, while well logs supply information collected along the well. Laboratory measurements add quantitative evaluations of properties such as porosity, permeability, mineral composition, pore structure, and fluid saturation. Considering these sources together gives engineers a broader characterization than any single source can provide and supports more informed reservoir models.
An engineering study typically combines core-sample examination, well-log interpretation, and laboratory measurements. Engineers evaluate the resulting information for porosity, permeability, mineral composition, pore structure, and fluid saturation, then relate those properties to flow behavior under reservoir conditions. The interpreted results are incorporated into geological and petrophysical models for planning wells, completions, and production.
Results from reservoir rock analysis identify how rock properties relate to storage and fluid transmission, giving engineers evidence for development decisions. Those results support estimates of reserves, selection of well locations, and completion design. Because the analysis reduces uncertainty in geological and petrophysical models, it also helps align development choices with expected recovery performance.
Reservoir rock analysis becomes especially useful when engineers evaluate enhanced recovery options or plan long-term resource management. Characterizing rock properties and fluid saturation provides a basis for interpreting how the reservoir may behave during development. These findings inform recovery decisions, help assess expected performance, and support more deliberate management of available oil, gas, or water resources.