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InSitu Fluid Analyzer

Real-time downhole fluid analysis system

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Real-time fluid answers—No more waiting for laboratory analysis

The InSitu Fluid Analyzer real-time downhole fluid analysis (DFA) system integrates various sensors making quantitative fluid properties measurements to deliver a comprehensive characterization of reservoir fluids at reservoir conditions.

Quantified, accurate fluid data that was previously unachievable from wireline logs or the laboratory analysis of collected samples is now possible:

  • hydrocarbon composition (C1, C2, C3–C5, and C6+)
  • gas/oil ratio (GOR)
  • live-oil density and viscosity
  • CO2
  • pH of water (aquifer, connate, injection, or water-based mud [WBM] filtrate)
  • reservoir fluid color
  • free-gas detection
  • downhole fluorescence (dew precipitation in retrograde gas condensates)
  • flowline pressure and temperature (regime of the sample chamber, not the probe)
  • resistivity of reservoir water
  • oil-based mud (OBM) filtrate contamination.
InSitu Fluid Analyzer service
InSitu Fluid Analyzer system integrates multiple InSitu Family downhole quantitative fluid properties measurements and sensors.

Investigate and quantify fluids at their source: your reservoir.

InSitu Fluid Analyzer Offerings

Fluid Profiling
Fluid properties and their variation across your reservoir
Compile and analyze data from InSitu Family downhole quantitative fluid properties measurements for fieldwide application.
InSitu GOR
Reservoir fluid GOR and CGR sensor
Determine gas/oil ratio and gas/condensate ratio in real time at downhole conditions.
InSitu Composition
Reservoir fluid composition sensor
Analyze fluid hydrocarbon composition, GOR, CO2, water content, and mud filtrate contamination.
InSitu CO₂
Reservoir fluid CO₂ sensor
Plot CO₂ content measured with a filter array spectrometer in real time.
InSitu Color
Reservoir fluid color sensor
Measure fluid color with a 20-channel filter array spectrometer.
InSitu Fluorescence
Reservoir fluid fluorescence sensor
Detect free gas bubbles and retrograde condensate liquid dropout for single-phase assurance.
InSitu pH
Reservoir fluid fluorescence sensor
Measure the pH of fluids across the entire flowline cross section.
InSitu Viscosity
Reservoir fluid viscosity sensor
Accurately measure the viscosity of flowing formation fluid at reservoir conditions.
InSitu Density
Reservoir fluid density and viscosity sensor
Directly measure formation fluid density and viscosity at reservoir conditions.
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Case Study Saturn Radial Probe Collects Fluid and Measures Pressure at 0.05-mD/cP Mobility in 6-in Caspian Sea Well

Oil samples and extended buildup in only 4.5-h total time on station in subsalt carbonate reservoir saves rig time and mitigates operational risk.
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Tech Paper Mapping and Modeling Large Viscosity and Asphaltene Variations in a Reservoir Undergoing Active Biodegradation

Viscosity is one of the key reservoir fluid properties. It plays a central role in well productivity and displacement efficiency and has a significant impact on completion strategies. Accurately assessing areal and vertical variations of viscosity will lead to more realistic reservoir simulation and optimal field development planning.

Case Study Saturn 3D Probe Confirms Mobile Oil in Low-Permeability Sakhalin Reservoir at 85% Water Saturation

Reliable fluid identification at 0.1-mD/cP mobility, where conventional techniques are inconclusive.

Industry Article Wireline Sensor Expands Capabilities of DFA

Downhole fluid analysis (DFA) is a critical aspect of well development that helps operators identify key reservoir fluid characteristics, such as hydrocarbon composition, gas/oil ratio and CO2.

Tech Paper Downhole Viscosity Measurement: Revealing Reservoir Fluid Complexities and Architecture

Knowledge of formation fluid viscosity and its vertical and lateral variations are important for reservoir management and determining field commerciality. Productivity and fluid displacement efficiency are directly related to fluid mobility, which, in turn, is greatly influenced by fluid viscosity.

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Tech Paper DFA Connectivity Advisor: A New Workflow to Use Measured and Modeled Fluid Gradients for Analysis of Reservoir Connectivity

In deepwater and other high-cost environments, reservoir compartmentalization has proven to be a vexing, persistent problem that mandates new approaches for reservoir analysis. In particular, methods involving reservoir fluids can often identify compartments, however, it is far more desirable to identify reservoir connectivity.

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