Formation Damage Evaluation Workflow for Shale Stabilization
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Solution Overview
Problem
Current methods for treating subterranean formations are inadequate in diagnosing and addressing formation damage, particularly due to water sensitivity and proppant degradation, which leads to reduced fracture conductivity and production losses, as existing testing methods have limitations in predicting damage mechanisms and evaluating treatment efficacy.
Innovation Solution
A workflow that combines conductivity testing, computed tomography (CT) imaging, and water analysis to evaluate damage mechanisms in shale formations, allowing for the selection and ranking of effective stabilization treatments by simulating reservoir conditions and evaluating geochemical reactions, thereby optimizing treatment fluids and preventing damage.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If conventional testing methods (XRD, SST, CEC, coreflood) are used to evaluate formation damage, then certain aspects of formation sensitivity can be assessed, but the methods cannot comprehensively diagnose all damage mechanisms or predict treatment efficacy
Solution Approach 1:
The patent combines multiple testing methodologies (conductivity testing, CT imaging, water analysis) into a single integrated workflow that simultaneously evaluates multiple damage mechanisms and treatment responses, resolving the limitation of individual methods being unable to comprehensively diagnose all damage types
Solution Approach 2:
The integrated workflow serves multiple functions: it diagnoses various damage mechanisms (swelling, fines migration, proppant degradation), evaluates treatment efficacy, and provides predictive capabilities for different formation types, making the system universally applicable across diverse formation conditions
2Reliability
If formation stabilization treatments are applied to address water sensitivity and fines migration, then formation permeability may be preserved, but fracture conductivity is reduced due to proppant cracking, breaking, and degradation
Solution Approach 1:
The patent evaluates how treatment fluids change physical and chemical parameters (pH, ionic composition, viscosity) to determine their differential effects on formation stability versus proppant integrity, allowing optimization of treatment parameters to balance both concerns
Solution Approach 2:
The conductivity testing workflow acts as an intermediary evaluation system that measures the actual impact of treatment fluids on both formation properties and proppant performance, enabling selection of treatments that maintain an acceptable balance between formation stabilization and conductivity preservation
3Productivity
If high pump rates are used during formation treating, then treatment efficiency is improved, but formation damage increases due to swelling and mechanical damage
Solution Approach 1:
The patent performs preliminary evaluation of formation sensitivity to pump rate-induced damage through conductivity testing and CT imaging before actual treatment, allowing prediction of damage risks at different pump rates and optimization of treatment design to achieve high efficiency with minimal damage
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 a more direct evaluation of damage mechanisms and enhances fracture conductivity by selecting optimal stabilization treatments, increasing oil and gas production while differentiating between various damage types and mineral stabilizing characteristics.
Implementation Method 1
conductive properties of the formation sample, the effluent from the formation sample, and/or the treatment fluid
Implementation Method 2
one or more damage properties of the formation sample using computed tomography images of a surface of the formation sample
Implementation Method 3
one or more properties of the effluent from the formation sample, and/or the treatment fluid
Data Source
AI summary
Methods of evaluating and/or selecting formation stabilization treatments for subterranean formations are provided. In some embodiments, the methods comprise: subjecting a test formation sample to stress loads, wherein sample comprises: two wafers of a formation material from a subterranean formation, and a plurality of proppant particulates between and in contact with the two wafers; measuring a conductivity of a test fluid through the test formation sample, wherein an eluted test fluid is collected after passing through the test formation sample; determining one or more damage properties of the test formation sample using computed tomography images; determining one or more properties of the eluted test fluid; and selecting a formation stabilization treatment for the subterranean formation based at least in part on the conductivity of the test fluid through the test formation sample, the damage properties of the test formation sample, and/or the properties of the eluted test fluid.