Fluid inclusion services

Fluid inclusions are sealed “containers” of fluids trapped in minerals. Fluid inclusions can be thought of as time capsules storing information about ancient temperatures, pressures, and fluid compositions.

Fluid inclusions are vacuoles sealed within minerals. When trapped within diagenetic and ore-forming minerals, they provide the only direct means of examining the fluids present in ancient geological systems.

They may provide the following valuable information with simple petrographic observations, microthermometric analysis, or sophisticated geochemical analysis of inclusions contents:

  • Temperature of mineral precipitation
  • Pressure of mineral precipitation
  • Composition and origin of fluids of mineral precipitation
  • Later history of temperature, pressure and fluid composition
  • Improve understanding of diagenetic- and ore-forming systems
  • Improve understanding of subsurface fluid evolution
  • Improve interpretation of petroleum migrating history

Natural processes have provided:

  • Constant volume
  • Constant composition
Figure: Primary HCFI with Permian age condensate mixed with brine hosted in quartz. From Søndeled, On-shore Norway. Combined white light and 366 nm UV light.

Figure: Primary HCFI with Permian age condensate mixed with brine hosted in quartz. From Søndeled, On-shore Norway. Combined white light and 366 nm UV light.

Fluid Inclusion Analytical Services tendered

Fluid Inclusion Analytical Services tendered

Textural Mapping

  • Abundances of petroleum inclusions
  • Presence of diverse types and generations of aqueous (AqFI) and petroleum inclusions (HCFI)
  • Appearance of HCFI (bubble size, color, fluorescence emission, presence of solids, etc.)
  • Time of trapping of HCFI relative to the diagenetic sequence
  • Textural occurrence of AqFI and HCFI in autigenic (diagenetic) minerals
  • Photographic documentation


  • Homogenization temperature (i.e. the disappearance of vapor bubble or liquid phase in petroleum or aqueous inclusions)
  • Clathrate melting temperature in mixed petroleum and aqueous inclusions
  • Ice melting temperature for salinity estimation of aqueous fluids
  • Hydrate melting temperature for Ca/Na ratios of aqueous fluids

Fluorescence Emission Spectroscopy

  • Emission spectra within 380-750 nm
  • Correlation with API density – the reclaimed IFE Q580 parameter

Gas Chromatography

  • Quantified gas composition (C1-C5)
  • Quantified compositional parameters in the C7 range
  • Semiquantification of pseudocomponents (C6 to ≈C30)

Isotope compositions of inclusion gases

  • 13C compositions of individual gas components (C1-C5, CO2)

Data Interpretation

  • Integration of analytical data
  • PVT modelling
  • Evaluation of fluid flow patterns

Petroleum Inclusions (HCFI)

Quick look mapping 

  • By immersing raw sample rock chips into non-toxic highly refractive fluids in a custom made micro-instrument adapting premium quality UV-transmissive optics, the initial stage differentiation between barren samples and fluid inclusion rich samples becomes an ease, significantly reducing time and funds spent on samples which would add no value. (This methodology was invented by IFE in 1994.)
  • Qualitative evaluation of fluid composition based on vapor bubble size, color and fluorescence emission
  • Petrographical distribution and abundances of different fluid types
Two generations of secondary HCFI in healed fractures in Baryte, Svalbard.

Reservoir filling history – the dating concept

  • The textural relationship between the fluid inclusions and their host minerals can be used as a “dating tool”.
  • Changes in fluid composition during various stages of the diagenetic history of the reservoir can be established.
Figure: Illustration of primary, pseudo-secondary and secondary inclusions in a detrital quartz grain with diagenetic overgrowth. Green inclusions predate blue inclusions which again predate yellow inclusions (all HCFI). The youngest fluid event is represented by trails of AqFI (grey) occurring in healed fractures crosscutting the detrital grain core as well as the diagenetic overgrowth.

Migration: Pressure or composition compartments?

Microthermometric results of aqueous and petroleum inclusions which are trapped at the same time, give important constraints on fluid phase relationships.


Figure: Microthermometric histogram of coexisting aqueous and petroleum inclusions from three case studies.


Trapping temperature of both aqueous and petroleum inclusions is equal to the homogenisation temperature of the aqueous inclusions. The difference between the homogenisation temperature of the aqueous and petroleum inclusions gives indication of the degree of under-saturation of the petroleum.


A: An oil field which is very close to gas saturation.


B and C: Two compartments of the same field. The lower homogenisation temperatures of petroleum inclusions in C indicate significant under-saturation, due to overpressure.



Figure: Coexisting petroleum (HC) and aqueous inclusions (AQ) hosted in a Spanish calcite.

Fluid Inclusion Fluorescence Emission Spectroscopy

A compositional fingerprint on microscale….….or how to resolve complex filling histories:

The correlation of Petroleum density (° API) with fluorescence spectroscopy – the Q580 parameter.

Figure 6: Fluid inclusion fluorescence emission spectra from a suite of Calcite and Baryte samples from Svalbard, ranging from light oils to asphaltene-rich compositions (Q580 = 0.18 – 0.79).


Figure: Left: Correlation of fluorescence emission spectra (Q580) versus petroleum density (°API) based on 112 reference petroleum samples. Right: Healed fractures in Baryte displaying two generations of petroleum migration. Compare Fig. 1 for an overview image of fractures.




Gas- and Light Hydrocarbon Components

Generation, migration, mixing, biodegradation

…. are processes which can be addressed by characterization of molecular and isotopic composition of natural gas. Typical applications of natural gas data are source-fluid correlation and evaluation of maturity and biodegradation.

From fluid inclusions:

Composition and δ13C of individual gas components [C1-C5, CO2) from inclusion fluids may now be analyzed.

The figure shows an example of comparison between the δ13C results from fluid inclusion and Drill Stem Test (DST) samples from the same well.

The figure shows an example of comparison between the δ13C results from fluid inclusion and Drill Stem Test (DST) samples from the same well.


A tool for fluid correlation …….

Recent work has shown some of the light hydrocarbon parameters to be excellent tools for fluid and source rock correlations. This is especially valuable fingerprints for condensates.


….or constraints on migration?

Light hydrocarbons are sensitive to fluid phase relationships. The light aromatics (as benzene and toluene) have a relatively high solubility in the aqueous phase. The content of light aromatics in the oil should thus be a measure of the amount of water “seen” by the oil during migration. Low contents of light aromatics may hence indicate a long migration distance.

Recent instrumental developments have enabled quantitative analyses of light hydrocarbons in fluid inclusions. Together with data from microthermometry on fluid phase relationships, this gives a powerful tool for fluid characterization through time.

Basin Dynamics

Temperature control from fluid inclusions


Diagenetic processes are crucial for reservoir quality of deep prospects. Temperature control from geochemical analyses gives


  • Data for integration with basin modelling
  • A link between diagenetic processes and basin evolution
Figure left: Example of quartz cementation (outside distinct dustrim) with subsequent formation of poikilotopic calcite. Right: Microthermometry of aqueous inclusions from the calcite- and quartz cements, as depicted to the left, gives detailed temperature control on the diagenetic history.

Aqueous salinity

An indicator of basinal hydrodynamics

Aqueous basinal fluids may show large compositional variations in time and space. Analysis of aqueous inclusions trapped in diagenetic minerals enables characterization of salinity and sometimes also Na/Ca ratios and constitutes a tool for resolving basinal hydrodynamics.

Figure left: Multiple saline aqueous inclusions with halite (NaCl) cubes – one in each (red arrows). Right: Homogenisation temperature and salinity of single inclusions can be analysed, and represented in cross-plots, used to define different water types for different sample populations.


Photo: Jan Braly Kihle 2014
ALSA-2B, Wafer section #3, incusion #1, primary HCFI, size 38×18 micrometer, Calcite hosted
ALSA-4A, Wafer section #1, inclusion #2b, primary AqFI, size 50×25 micrometer, Calcite hosted




IFE offers research on assignments. Please contact:

Kihle, Jan Braly

Reservoir Technology,

+47 465 41 759

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