Mandel-Cryer Pressure Signal Diagnostics for Reservoir Drainage
Find Innovative SolutionsGenerate Solutions
Solution Overview
Problem
Unconventional reservoirs face challenges in hydrocarbon recovery due to low permeability and pressure changes that are not effectively addressed by conventional methods, leading to delayed multiphase effects and impaired well productivity.
Innovation Solution
The method involves mapping poromechanic pressure changes in subterranean formations by measuring lithostatic load sharing, identifying local pressure peaks, and determining regions for single-phase hydrocarbon production, utilizing coupled fluid flow and poromechanical physics to understand and predict pressure escalation and depletion patterns.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If conventional production methods are used in unconventional reservoirs, then development cost is reduced, but hydrocarbon recovery efficiency deteriorates due to low permeability and pressure changes
Solution Approach 1:
The invention changes the approach from conventional single-phase production methods to a method that accounts for poromechanic pressure changes and Mandel-Cryer effects. By monitoring pressure escalation and depletion patterns, the method adapts production parameters to the actual reservoir response, improving hydrocarbon recovery efficiency in low permeability formations where conventional methods fail.
Solution Approach 2:
The invention implements a feedback mechanism by continuously monitoring pressure changes in the reservoir and using this information to understand drainage volume and optimize production. The pressure escalation and depletion signals provide real-time feedback on reservoir behavior, allowing operators to adjust production strategies accordingly, thereby improving recovery efficiency without excessive complexity.
2Measurement precision
If pressure monitoring is extended to capture Mandel-Cryer effects, then drainage volume estimation accuracy is improved, but measurement and data analysis complexity increases
Solution Approach 1:
The invention uses pressure monitoring as an intermediary to indirectly measure drainage volume. Instead of directly measuring the extensive drainage volume in unconventional reservoirs, the method monitors pressure escalation and depletion signals that serve as proxies for drainage extent. This intermediary approach improves estimation accuracy while keeping measurements feasible through standard pressure gauges.
Solution Approach 2:
The invention replaces direct mechanical measurement of drainage volume with poromechanic pressure signal analysis. By substituting the mechanical measurement approach with pressure-based detection, the method achieves higher measurement precision for drainage volume estimation while managing the complexity through established pressure monitoring technology rather than requiring new measurement systems.
3Productivity
If well spacing is optimized based on drained reservoir volume, then asset management efficiency is improved, but the complexity of reservoir characterization increases
Solution Approach 1:
The invention performs preliminary reservoir characterization by analyzing pressure escalation and depletion patterns before finalizing well spacing decisions. By conducting poromechanic pressure signal analysis in advance, the method provides drainage volume estimates that guide well spacing optimization, improving asset management efficiency while managing characterization complexity through a structured preliminary assessment approach.
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 allows for more reliable reserve forecasts, optimal well operating strategies, and improved hydrocarbon recovery by estimating pressure escalation duration and magnitude, enabling better asset management and productivity forecasts in unconventional reservoirs.
Implementation Method 1
measuring a poromechanic pressure change due to lithostatic load sharing in the subterranean formation
Implementation Method 2
identifying one or more local pressure peaks in the poromechanic pressure change, wherein the one or more local pressure peaks are each marked by a pressure escalation and subsequent pressure depletion
Data Source
Figure 1
Figure 2
Figure 3A
AI summary
A method for obtaining hydrocarbon from a reservoir in a subterranean formation is described. The method includes measuring a poromechanic pressure change due to lithostatic load sharing in the subterranean formation. Mapping the poromechanic pressure change to one or more locations in the subterranean formation. Identifying one or more local pressure peaks in the poromechanic pressure change, wherein the one or more local pressure peaks are each marked by a pressure escalation and subsequent pressure depletion. Determining a drained reservoir volume in the hydrocarbon reservoir based on the pressure escalation.