Automated Reservoir Pressure Estimation from Downhole Data
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Solution Overview
Problem
The complexity of modern oil and gas production fields, with hundreds of wells and intricate networks, generates overwhelming data from downhole pressure sensors, making it time-consuming and prone to errors for reservoir engineers to analyze reservoir pressure and other parameters, limiting the frequency and accuracy of production optimization decisions.
Innovation Solution
An automated system processes real-time measurements from downhole sensors, detecting changes in well operating modes to determine reservoir pressure and update well and reservoir models, reducing the manual effort required for data analysis and improving the timeliness and accuracy of reservoir pressure analysis.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If manual analysis of downhole pressure sensor data is performed, then reservoir pressure can be determined, but the process is time-consuming and prone to errors
Solution Approach 1:
The patent replaces manual mechanical analysis with an automated computer-based system that processes downhole pressure sensor data. The system automatically detects well operating mode changes, retrieves relevant pressure data, and determines reservoir pressure without human intervention, eliminating time-consuming manual analysis while maintaining or improving accuracy through consistent algorithmic processing.
Solution Approach 2:
The system enables self-service by automatically performing the complete reservoir pressure analysis workflow. The computer system independently detects operating mode changes, retrieves data from databases, processes pressure measurements, and generates reservoir pressure determinations without requiring engineer intervention, thereby reducing both time and potential human errors.
2Productivity
If frequent reservoir pressure analysis is performed to improve optimization decisions, then production optimization frequency increases, but manual analysis capacity is exceeded
Solution Approach 1:
The automated system replaces manual analysis capabilities with computer-based processing that can handle frequent data analysis requests. The system continuously monitors downhole pressure sensors, automatically detects operating mode changes, and processes pressure data at any frequency required, removing the bottleneck of manual analysis capacity and enabling frequent production optimization decisions.
Solution Approach 2:
The system enables continuous useful action by maintaining constant monitoring of downhole pressure sensors and being ready to process analysis requests at any time. The automated architecture allows the system to operate continuously without fatigue or capacity limitations, supporting frequent and timely production optimization decisions.
3Speed
If automated processing of downhole pressure measurements is implemented, then analysis speed increases, but system complexity increases
Solution Approach 1:
The patent replaces complex manual analysis procedures with a standardized computer-based automated system. While the automated system introduces computational complexity, it eliminates the complexity of manual data retrieval, processing, and interpretation steps. The system uses structured databases and algorithmic processing to achieve rapid reservoir pressure determination.
Solution Approach 2:
The system introduces a computer-based intermediary layer between downhole pressure sensors and reservoir pressure determination. This intermediary automatically retrieves data from databases, processes pressure measurements according to predefined algorithms, and generates results, simplifying the overall process despite adding computational components. The intermediary handles data management and processing tasks that would otherwise require complex manual coordination.
Data Source
AI summary
A method and system for estimating reservoir pressure in a hydrocarbon reservoir from downhole pressure measurements of producing wells is disclosed. Pressure measurements are obtained from wells in the production field over time, and communicated to a server that applies the pressure measurements for a well to a model of that well. The server operates the model using the pressure measurements to determine an operating mode of the well, such as producing or shut-in. Upon detection of a change in operating mode indicative of an abrupt change in flow at the well, such as corresponding to a shut-in event, additional downhole pressure measurement data is acquired until a steady-state condition is reached. The pressure measurements are used to determine a reservoir pressure, which is transmitted to a responsible reservoir engineer or other user. Modification of the determined reservoir pressure value by the user can be received, and the stored reservoir pressure and well model are updated accordingly.