Integration of Permeability Derived From Well Pressure Transient Analysis To Improve Prediction Model Permeability In High Heterogeneous Carbonates Reservoir - Case Study-offshore Abu Dhabi, UAE.

Khemissa, Hocine; Lesage, Alexander; Ahmad, Farooq; Draoui, Elyés; Nakamura, Shinichi; Alyak, Abbas Ali Abbas Al; Walia, Samir; Das, Surya Prakash

doi:10.2118/166016-ms

Cited by 3 publications

(2 citation statements)

References 1 publication

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“…Previous approaches [29,30] used pressure build-up data for calibration with logging data and to determine the true permeability of rock. In [31], the authors used a neural network based on core and logging data from 254 wells, as well as analysis of 600 pressure build-up curves, and forecasted rock permeability in the formation. With the help of such approaches, it is possible to determine the formation permeability at the time of the study.…”

Section: Introductionmentioning

confidence: 99%

“…It is also worth noting that in works [29][30][31][32][33][34][35][36][37], as in many other works, the main attention is paid to the study of changes in the pressure build-up curves of a stress-sensitive formation. These studies show how permeability changes from pressure in situ and the results of historical observations during production are not presented.…”

Section: Introductionmentioning

confidence: 99%

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A Model of Reservoir Permeability Evolution during Oil Production

2021

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In this paper, we present a mathematical model to predict the evolution of rock permeability depending on effective pressure during oil production. The model is based on the use of the results of well testing data from wells operating in the oil fields of the Perm–Solikamsk region in the north of the Volgo Ural oil and gas province. Dependences of the change in flow characteristics in the reservoir on the effective pressure were established. We performed a comparative assessment using permeability and effective pressure data that were normalized to dimensionless forms of k/ko and P/Po. The factors and their influence on the nature of the change in permeability from the reservoir pressure were determined. Depending on the type of rock, its composition, initial permeability, and bedding conditions, we determined the limits of variation of the constants in empirical equations describing the change in the permeability of rocks from the effective pressure. The mathematical model we developed enables the prediction of the change in permeability of rocks during oil production from reservoirs on the basis of reservoir properties such as initial permeability, initial reservoir pressure, average bedding depth, net-to-gross ratio, and initial effective rock pressure.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

A Model of Reservoir Permeability Evolution during Oil Production

2021

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Assessing Macroscopic Dynamic Permeability Through Pressure and Noise Analysis

Aslanyan¹,

Aslanyan²,

Farakhova

2015

Day 2 Tue, September 15, 2015

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One of the common applications of Pressure Transient Analysis and Pressure Pulse Testing is the evaluation of formation permeability that is referred to as dynamic permeability and is then used to calibrate permeability distribution from a geological model before running full-field flow simulations. In practice, though, the correlation between permeability from pressure tests and that predicted from open-hole logs is often poor and does not provide consistent calibration because of many factors including poor core data, poor porosity-permeability, complex pressure transient responses and others. In many cases, inaccurate dynamic permeability values are due to misinterpretation of flowing thickness. In this paper, we demonstrate how Spectral Noise Logging can pick the boundaries of actual flow units and enable the accurate determination of effective thickness to substantially improve the correlation between dynamic and open-hole permeabilities.

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Pressure Transient Analysis (PTA) Enables a New Approach for Building Robust Reservoir Permeability Distribution for Miscible Gas Injection Development

Al Hinai,

Agarwal,

Dmitrii

et al. 2024

Day 3 Wed, February 14, 2024

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Accurate estimation of oil recovery and optimization of reservoir performance requires realistic estimates of permeability distribution. This paper presents an approach to build different modeling realizations for testing possible reservoir behavior during miscible gas injection (MGI) and UR range for MGI development. Multiple geological realizations were built for nine Area-H carbonated reservoirs to bracket the permeability distribution range away from well control, which is a major uncertainty impacting production behavior and history match. Two main factors that affect ultimate recovery and production forecasts are property distribution and permeability range. Therefore, different geological and dynamic model realizations were built to test the reservoir behavior during MGI, which helped to make reliable estimates of production profiles and UR. Full-field reservoir models were constructed for multiple geological realizations, and permeability distribution results showed that using permeability-thickness (KH) and high-perm model methods increased confidence by preserving high-permeability streaks and introducing higher heterogeneity. Fewer changes were required to calibrate the full-field reservoir model to actual pressure data with KH than with conventional core-based permeability. High-permeability streak models provided faster gas breakthrough, higher GOR, and lower UR than conventional and KH-matched models. High-contrast permeability models provided a higher confidence estimation of faster gas breakthrough and oil recovery. High-permeability streaks and high-contrast models can mitigate the negative influence of enhanced reservoir heterogeneity on field production performance forecast. As a result, robust ranges of production profiles and promise would help the project forecast robustness check against low case realizations and upfront planning on potential mitigation/recovery options in case of heterogeneity indies thief zone behavior leading to faster gas breakthrough. A new approach is presented that helps to estimate realistic production forecasts and UR ranges for gas injection development projects. It allows testing models for different subsurface realizations and generating robust project economics. The methodology given in this study can show a good practice for the characterization of heterogeneous reservoirs for MGI flooding development, especially for capturing the downside as an alternate geological realization.

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Integration of Permeability Derived From Well Pressure Transient Analysis To Improve Prediction Model Permeability In High Heterogeneous Carbonates Reservoir - Case Study-offshore Abu Dhabi, UAE.

Cited by 3 publications

References 1 publication

A Model of Reservoir Permeability Evolution during Oil Production

A Model of Reservoir Permeability Evolution during Oil Production

Assessing Macroscopic Dynamic Permeability Through Pressure and Noise Analysis

Pressure Transient Analysis (PTA) Enables a New Approach for Building Robust Reservoir Permeability Distribution for Miscible Gas Injection Development

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