Virtual Flow Metering for Well Production Monitoring
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Solution Overview
Problem
Existing methods for monitoring flow rates of different fluid phases in wellbore operations are costly, require frequent maintenance, and do not provide continuous records of production from individual wells.
Innovation Solution
The implementation of a virtual flow metering system that analyzes signals and measurements from multiple sensors, incorporating additional data such as fluid properties and production system measurements, to estimate flow rates using software models or machine learning algorithms.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If multi-phase flow meters are installed on individual wells to monitor each well separately, then measurement precision is improved, but device complexity and operational cost increase
Solution Approach 1:
The patent creates a virtual copy of the flow metering function through software modeling. Instead of installing physical multi-phase flow meters on each well, the system uses a virtual flow meter that replicates measurement capabilities by processing data from simpler sensors (flow meters, pressure transducers, temperature sensors) and incorporating well characteristics and production history into a computational model.
Solution Approach 2:
The patent replaces the mechanical/physical flow metering system with an information-processing system. The virtual flow meter substitutes physical measurement devices with a software-based approach that infers flow rates from indirect measurements and well data, eliminating the need for complex physical instrumentation in each well.
2Productivity
If physical flow meters are used to monitor flow rates continuously, then productivity is improved, but loss of energy and operational cost increase
Solution Approach 1:
The system creates a virtual replica that performs the same monitoring function without the energy consumption of physical flow meters. The virtual flow meter processes data from existing sensors and well data using computational algorithms, eliminating the need for power-consuming acoustic or electromagnetic measurement devices in each well.
Solution Approach 2:
The virtual flow meter leverages existing data from the well production system (flow meter readings, pressure, temperature, well characteristics) to perform flow rate calculations. Instead of requiring dedicated energy-intensive measurement devices, the system uses freely available or already-measured data to derive the required information.
3Ease of operation
If test-separator method is used to monitor fluid flow rates, then ease of operation is improved, but loss of time increases due to non-continuous records
Solution Approach 1:
The virtual flow meter enables continuous monitoring by operating continuously without requiring physical well interventions. The system processes data streams from sensors and well data in real-time, providing uninterrupted flow rate information unlike periodic test-separator measurements that require wells to be shut in and physically tested.
Solution Approach 2:
The system incorporates feedback from continuous sensor data and well production history to dynamically update flow rate calculations. The virtual flow meter uses real-time pressure, temperature, and flow meter data along with well characteristics to continuously refine and update production records, eliminating gaps between measurements.
4Ease of manufacture
If aggregate flow from multiple wells is processed in a single separator, then ease of manufacture is improved, but loss of information increases regarding individual well flow rates
Solution Approach 1:
The virtual flow meter acts as an intermediary that reconciles the simplicity of aggregate processing with the need for individual well data. By processing data from sensors and well records, the virtual system attributes aggregate flow measurements to individual wells, preserving well-specific information without requiring separate physical measurement systems for each well.
Data Source
AI summary
A method for determining flow information of a well producing fluid from a subsurface formation comprising. The method comprises obtaining at least one first production measurement from the well. The method comprises obtaining, with a sensor, a first measurement generated by the fluid flowing through a device. The method comprises inputting the first measurement and the at least one first production measurement into a virtual flow meter. The method comprises determining, via the virtual flow meter, a multi-phase flow rate of the fluid based on the first measurement and the at least one first production measurement.