Wellbore Warm-Back Data Analysis for Injection Profiling
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Solution Overview
Problem
Existing methods for analyzing warm-back temperature data to predict injection fluid volumes for various zones within a hydrocarbon reservoir are subject to inaccuracies, necessitating an improved system and method for injection profiling.
Innovation Solution
A method and system that involve injecting fluid into an injection well, measuring temperature along the wellbore to create a warm-back data set, modifying the initial geotherm using data from the middle-time region to calculate a pseudo-geotherm, and estimating fluid volumes injected into each zone based on the initial and pseudo-geotherm.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If the shut-in period is extended to allow complete warm-back for accurate temperature measurements, then measurement precision improves, but loss of time increases due to extended downtime
Solution Approach 1:
The patent applies partial action by measuring temperature at strategically selected time points during the warm-back process rather than requiring complete thermal equilibrium. Specifically, temperature is measured at the initial shut-in time and at one or more intermediate times before full warm-back completion, allowing accurate injection profile determination with reduced shut-in duration.
Solution Approach 2:
The patent performs preliminary temperature measurements at defined time points during the warm-back process to capture sufficient thermal data without waiting for complete thermal recovery. This preliminary sampling approach provides adequate information for injection profile calculation while minimizing the shut-in period.
2Productivity
If traditional warm-back analysis methods are used to determine injection profiles, then zonal allocation can be achieved, but measurement precision deteriorates due to inaccuracies in predicting injection fluid volumes
Solution Approach 1:
The patent implements feedback by using measured temperature data from the warm-back process to iteratively refine the determination of injection fluid volumes in each zone. The temperature measurements at multiple time points provide feedback information that improves the accuracy of injection profile calculation compared to traditional single-time-point methods.
Solution Approach 2:
The patent changes the temporal parameter of measurement by taking temperature readings at multiple defined time points (initial shut-in time and one or more intermediate times) rather than at a single fixed time. This parameter change in the measurement approach improves the precision of injection fluid volume prediction.
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 enhances the accuracy of injection profiling by optimizing the shut-in period and minimizing downtime, allowing for more precise zonal flow rate determination and improved hydrocarbon recovery.
Implementation Method 1
measuring temperature along the wellbore to create a warm-back data set
Implementation Method 2
a laser or other light source at the surface of the well transmits a pulse of light into a fiber optic cable installed along the length of a well. Due to interactions with molecular vibrations within the glass of the fiber, a portion of the light is scattered back towards the surface (this phenomenon is referred to as Raman scattering, Brillouin scattering, and/or Rayleigh scattering)
Implementation Method 3
The injection fluid typically lowers the temperature in the region of the wellbore and the zones of fluid injection can be identified using the temperature probe
Implementation Method 4
the area surrounding the wellbore warms back to a steady state temperature, referred to as a 'geotherm,' over time
Data Source
AI summary
Herein disclosed are methods and systems related to processes for injection wells generally utilized in the oil and gas industry. The methods herein include a method of estimating the relative cumulative volume of fluids injected into multiple zones of an injection well located in a hydrocarbon reservoir, the injection well including a plurality of zones. The method comprises injecting fluid into a wellbore of the injection well. The method further includes measuring temperature at points along the wellbore to produce a warm-back data set that includes data for a plurality of times and depths. The method also includes modifying an initial geotherm using only data from the warm-back data set that is in a middle-time region (MTR) of the warm-back data set to produce a calculated pseudo-geotherm. The calculated pseudo-geotherm may be used to estimate a volume of fluid injected into each of the plurality of zones.