Horizontal Well Permeability Calculation via Segmented Production Logs
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Solution Overview
Problem
Existing methods for determining permeability in horizontal wells are inaccurate and limited, especially in heterogeneous reservoirs with faults, fractures, and high conductive flow channels, as they rely on indirect measurements and empirical models that perform poorly across different formations.
Innovation Solution
A method for calculating permeability using actual multiphase production log data from horizontal wells, dividing the well into segments and applying a well deliverability model based on Darcy's law for multiphase flow, considering relative permeability to oil and water, and well trajectory, to estimate permeability profiles on a foot-by-foot basis.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Ease of manufacture
If empirical models based on porosity and water saturation correlations are used, then permeability can be estimated using readily available well log data, but the accuracy deteriorates in heterogeneous reservoirs and different formation types
Solution Approach 1:
The horizontal well is divided into multiple discrete segments along its trajectory. Each segment is independently characterized using production log data, allowing permeability to be calculated on a foot-by-foot basis. This segmentation enables the model to capture spatial variability in heterogeneous reservoirs while maintaining computational efficiency through modular processing of production data.
Solution Approach 2:
The methodology transforms the approach from using static core-derived empirical correlations to using dynamic production log measurements. By incorporating actual production data (rates, pressures, temperatures) and relative permeability relationships, the model adapts to specific reservoir conditions rather than relying on formation-type generalizations, thereby improving accuracy across heterogeneous formations.
2Measurement precision
If core plugs and formation fluid testers are used for direct permeability measurement, then accurate permeability values can be obtained at discrete points, but the ability to estimate permeability continuously across the wellbore deteriorates due to limited core availability
Solution Approach 1:
Production log data serves as an intermediary between discrete core measurements and continuous permeability profiling. The methodology uses production data (flow rates, pressures, temperatures) combined with relative permeability relationships to calculate permeability at multiple discrete intervals along the wellbore, effectively creating a continuous permeability profile without requiring continuous core sampling.
Solution Approach 2:
The approach transitions from spatial sampling (core plugs at discrete depths) to temporal-spatial measurement (production logs capturing flow dynamics along the entire wellbore). By utilizing production data collected over time and space, the methodology reconstructs continuous permeability profiles that extend beyond the limited spatial coverage of core samples.
3Ease of manufacture
If porosity and irreducible water saturation are derived from well logs to use in empirical models, then permeability can be calculated using available log data, but the accuracy deteriorates because log-derived porosity is not necessarily effective porosity
Solution Approach 1:
The methodology uses production log data to directly calculate permeability without requiring external derivation of effective porosity or irreducible water saturation from well logs. By incorporating relative permeability relationships and actual production measurements (rates, pressures, temperatures), the system self-determines permeability values that inherently account for effective flow pathways, eliminating the need for potentially inaccurate log-derived porosity conversions.
Applied Scientific Principles
This section explains which scientific principles are used to turn an abstract innovation direction into a practical engineering solution.
Function Achieved in This Case
This approach provides accurate permeability profiles for horizontal wells, improving inflow control device design, intelligent well completions, and multilateral well performance, leading to increased well productivity and enhanced oil recovery.
Implementation Method 1
applying a well deliverability model based on Darcy's law for multiphase flow
Data Source
AI summary
A method for permeability calculation includes determining fluid properties associated with a horizontal well, relative permeability to oil and relative permeability to water, for the horizontal well, and an approximate upper boundary and an approximate lower boundary of the horizontal well. In accordance with a particular embodiment, the horizontal well may be divided into a plurality of well segments. Actual production logging data associated with the horizontal well may be received at an interface. For each respective well segment, a horizontal permeability is calculated using the fluid properties, relative permeability to oil, relative permeability to water and actual production logging data.