Intermittent Well State Sampling in Managed Pressure Drilling
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Solution Overview
Problem
Conventional managed pressure drilling (MPD) systems rely solely on pressure sensor data and differential flow rate measurements, which are delayed and lack precision in detecting well control events like kicks or losses, requiring substantial fluid accumulation before detection is possible, and fail to convey the nature and magnitude of fluid interactions within the wellbore.
Innovation Solution
A method that calculates an expected volume differential by considering wellbore pressure changes, fluid compressibility, and geometry, allowing for earlier and more accurate detection of well control events by comparing measured and expected volume differentials, and using this information to control wellbore pressure through surface backpressure manipulation.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If conventional MPD systems rely solely on pressure sensor data and differential flow rate measurements, then the system structure remains simple, but the detection precision and response time for well control events are insufficient
Solution Approach 1:
The patent segments the detection function into multiple independent measurement components: pressure sensors distributed at different locations, flow rate meters at inlet and outlet, and temperature sensors. Each component measures a specific parameter, and their combined data provides comprehensive well control event detection with higher precision without requiring a completely complex new system architecture.
Solution Approach 2:
The patent adds a new dimension of detection by incorporating temperature measurements alongside pressure and flow rate data. This multi-dimensional approach allows detection of well control events through thermal signatures and fluid property changes, providing earlier and more accurate detection capability beyond traditional single-parameter pressure monitoring.
2Reliability
If the system waits for substantial fluid accumulation before detection, then measurement reliability improves, but the response time to well control events is delayed
Solution Approach 1:
The patent implements preliminary detection by continuously monitoring multiple parameters (pressure, flow rate, temperature) and calculating expected versus actual fluid volumes in real-time. This allows the system to detect well control events at their onset before substantial fluid accumulation occurs, providing early warning while maintaining measurement reliability through multi-parameter validation.
Solution Approach 2:
The system uses feedback mechanisms where measured pressure and flow rate data are continuously compared against expected values based on drilling parameters and wellbore geometry. Deviations from expected behavior trigger alerts, enabling timely response to well control events while maintaining reliable detection through continuous comparison and validation of measurements.
3Loss of information
If conventional systems use only pressure and flow rate measurements, then the measurement system remains simple, but the system fails to convey the nature and magnitude of fluid interactions within the wellbore
Solution Approach 1:
The patent implements a multi-functional measurement system where sensors measure multiple parameters simultaneously: pressure sensors monitor both static and dynamic pressure, flow rate meters measure both influx and return flow, and temperature sensors detect thermal variations. This universal measurement approach provides comprehensive information about fluid interactions, kick detection, and loss detection without requiring separate specialized systems for each function.
Solution Approach 2:
The patent adds temperature as a new measurement dimension to capture thermal signatures of fluid interactions. This enables detection of fluid properties, phase changes, and heat transfer effects that provide qualitative and quantitative insights into downhole conditions, conveying the nature and magnitude of fluid interactions that pressure and flow rate measurements alone cannot detect.
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
Enables timely and precise detection of well control events, such as kicks or losses, before fluids transit the system, providing qualitative and quantitative insights into downhole conditions, thereby improving drilling safety and efficiency.
Implementation Method 1
determining an expected volume differential by calculating a fluid volume of the wellbore system, determining a wellbore pressure difference, determining a well system bulk modulus, and multiplying the fluid volume of the wellbore by the wellbore pressure difference and dividing a result by the well system bulk modulus
Data Source
AI summary
A method of monitoring a well state with intermittent well state sampling includes determining a measured volume differential by measuring flow out of a wellbore, measuring flow into the wellbore, and calculating a difference between the measured flow out and the measured flow in. The method includes determining an expected volume differential by calculating a fluid volume of the wellbore system, determining a wellbore pressure difference, determining a well system bulk modulus, and multiplying the fluid volume of the wellbore by the wellbore pressure difference and dividing a result by the well system bulk modulus. If the expected volume differential is not substantially equal to the measured volume differential, reporting to the user that the well state is experiencing a significant change requiring user intervention.