Flow Control Device Simulation in SAGD Reservoirs
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Solution Overview
Problem
Current reservoir simulators fail to accurately simulate the behavior of flow control devices (FCDs) under steam-assisted gravity drainage (SAGD) conditions, particularly due to phase transitions and inadequate accounting for differential pressure, leading to suboptimal thermal recovery processes in bitumen recovery from oil sands.
Innovation Solution
A method and system for simulating hydrocarbon production that determines differential pressure through FCDs based on flow rate, density, viscosity, steam quality, pressure, and temperature, transforming this function into an input parameter for reservoir models, accounting for both FCDs and reservoir behavior, using empirical equations and experimental data to predict fluid flow through chokes and chambers.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If traditional Reynolds number-based models are used to estimate differential pressure through FCDs, then the model complexity is low and ease of calculation is improved, but the simulation accuracy deteriorates under phase transition conditions
Solution Approach 1:
The patent transforms the differential pressure function to use reservoir model input parameters (flow rate, fluid properties, steam quality, pressure, temperature) instead of Reynolds number, allowing the model to adapt to phase transition conditions while maintaining compatibility with reservoir simulators
Solution Approach 2:
The patent introduces an intermediary transformation process that converts the differential pressure function into terms compatible with reservoir model inputs, bridging the gap between FCD behavior and reservoir simulation parameters
2Ease of operation
If FCDs are simulated as separate wellbores with constrained bottom hole pressures and rates, then the FCD behavior can be forced into the simulation, but the ability to accurately simulate steam conformance and cumulative production deteriorates
Solution Approach 1:
The patent merges the FCD simulation directly into the reservoir model by transforming the differential pressure function into an input parameter that can be used within the reservoir simulator, eliminating the need for separate wellbore simulations and constraints
Solution Approach 2:
The transformed differential pressure function serves multiple functions: it accounts for FCD behavior, maintains compatibility with reservoir model inputs, and enables accurate simulation of steam conformance, cumulative production, and steam-to-oil ratios within a single unified model
3Measurement precision
If the differential pressure function accounts for phase transitions and flashing, then the simulation accuracy is improved, but the computational complexity and data requirements increase
Solution Approach 1:
The patent changes the parameters used in the differential pressure function to include steam quality, pressure, and temperature directly, which are already tracked by reservoir models, rather than using Reynolds number which requires additional calculations and does not account for phase transitions
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 enables more accurate simulation of hydrocarbon production by accounting for the behavior of FCDs under SAGD conditions, improving steam conformance, cumulative production, and steam-to-oil ratios, thereby optimizing thermal recovery processes.
Implementation Method 1
ΔP estimation for flow through orifices in turbulent flow
Implementation Method 2
This assumption does not hold when there are phase transitions in the fluids
Implementation Method 3
Flashing of the water within fluids passing through the FCDs further complicates describing performance of the FCDs
Data Source
AI summary
Methods and systems simulate hydrocarbon production from a reservoir and predict impact of flow control devices on production for such reservoir simulation. The methods may transform equations capturing properties that describe flow of fluids through the flow control devices into input parameters desired for use with reservoir simulators. The equations may be determined based on physical properties of the flow control devices or fitted to match experimental or computational fluid dynamics data.