Wellbore Dynamic Kill Simulation With Segmented Multiphase Pressure Modeling
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Solution Overview
Problem
The complexity and slowness in calculating pressure profiles during a dynamic kill of a wellbore blowout, particularly in harsh environments like deepwater drilling, due to the multiphase flow of mud and hydrocarbon, make it challenging to predict and minimize blowout events effectively.
Innovation Solution
A method involving the simulation of a dynamic kill by dividing the hydrocarbon/mud mixed fluid column into small elements, using an enhanced rock weathering model and multiphase flow model, and applying reservoir inflow and wellbore lift curves to estimate flowing bottomhole pressure, while considering pump capacity and formation fracture pressure.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If traditional multiphase flow calculation methods are used to calculate pressure profile during dynamic kill, then the calculation accounts for all physical phenomena including mud front movement and bottom hole pressure changes, but the calculation process becomes extremely complex and slow
Solution Approach 1:
The wellbore is divided into multiple segments along its length, with each segment having uniform properties. The mud front position is tracked at segment boundaries, and pressure calculations are performed segment by segment rather than continuously throughout the entire wellbore, significantly reducing computational complexity while maintaining accuracy.
Solution Approach 2:
The method uses iterative parameter adjustment where the mud front position and pump rate are varied in discrete steps. By changing these parameters incrementally and calculating pressure profiles for each step, the complex continuous problem is transformed into a series of simpler discrete calculations that can be solved efficiently.
2Reliability
If detailed multiphase flow modeling is performed to accurately predict blowout behavior, then the simulation captures complex fluid dynamics, but the computational complexity increases making real-time planning difficult
Solution Approach 1:
The complex multiphase flow system is segmented into distinct zones (hydrocarbon column, mixed fluid column, kill fluid column) with simplified assumptions applied to each zone. This allows accurate prediction of blowout behavior through manageable calculations rather than attempting to model every detail of the continuous multiphase system.
Solution Approach 2:
The method performs preliminary calculations to establish baseline pressure profiles and mud front positions before the actual dynamic kill operation begins. These preliminary results are used to pre-determine optimal pump rates and kill fluid requirements, enabling faster decision-making during the actual operation without requiring complex real-time simulations.
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 accurate simulation of pressure and temperature profiles, enabling precise control of the kill fluid inventory and reducing the risk of wellbore blowouts by optimizing pump rates to prevent formation fracturing.
Implementation Method 1
A dynamic kill is a technique that includes a static head of a kill fluid combined with frictional pressure losses in order to suppress the reservoir pressure to kill the blowout
Implementation Method 2
A dynamic kill is a technique that includes a static head of a kill fluid combined with frictional pressure losses in order to suppress the reservoir pressure to kill the blowout
Data Source
AI summary
A method comprises retrieving attributes of a blowout well and a relief well and simulating a dynamic kill of a blowout from the blowout well via a kill mud pumped down through the relief well, wherein the simulating comprises determining a flowing bottom hole pressure for the blowout well and the relief well based on an intersection of a reservoir inflow performance relationship (IPR) curve and a wellbore vertical lift (VLP) curve.