MCP For Claude Marketplace
Reservoir Characterization Model

Reservoir Characterization Model MCP Connector for Claude

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Analyzes petrophysical data to characterize reservoir properties and flow units.

4 tools Official Updated Oct 1, 2026 Official Vinkius Partner
More Details Connect to Claude

This MCP server provides advanced analytical tools for petrophysical reservoir characterization. It transforms raw core and log data into actionable insights by calculating property distributions, assessing spatial heterogeneity, and identifying distinct flow units. Use analyze_property_statistics for high-level summaries, evaluate_heterogeneity to quantify spatial complexity, identify_flow_units to segment the reservoir, and calculate_permeability_trends to determine directional flow characteristics.

petrophysicsreservoirgeologyporositypermeability

4 tools expose this connector's capabilities to your AI agent.

analyze_property_statistics

Provides a high-level statistical summary of the basic petrophysical properties

calculate_permeability_trends

Determines the directional flow characteristics of the reservoir

evaluate_heterogeneity

Quantifies the complexity and spatial variation of the reservoir

identify_flow_units

Segments the reservoir into distinct zones that function as unified fluid conduits

See how to talk to your AI agent using Reservoir Characterization Model.

Can you provide a statistical summary for these porosity and permeability values? Porosity: [0.15, 0.18, 0.22], Permeability: [10, 15, 25], Saturation: [0.8, 0.75, 0.7]

The mean porosity is 0.183, mean permeability is 16.67, and mean saturation is 0.75.

What is the permeability ratio if horizontal permeability is 50 mD and vertical permeability is 10 mD?

The permeability ratio is 0.2, indicating preferred horizontal flow.

Identify flow units for a sandstone reservoir with porosity [0.2, 0.21, 0.12] and permeability [100, 110, 20].

Two distinct flow units were identified: Unit 1 (high porosity/permeability) and Unit 2 (low porosity/permeability).

The model requires petrophysical measurements such as porosity, permeability, and saturation data, along with lithology information for segmentation.

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