A novel centrifuge permeameter to characterize flow through low permeability strata

2013 ◽  
pp. 193-199 ◽  
Author(s):  
W Timms ◽  
M Whelan ◽  
I Acworth ◽  
D McGeeney ◽  
S Bouzalakos ◽  
...  
Keyword(s):  
Low Permeability ◽  
Flow Through

A Novel Coreflood Test to Evaluate EOR Potential of Wettability-Altering Surfactants in Oil-Wet Heterogeneous Carbonate Reservoirs

2021 ◽  
Author(s):  
Yue Shi ◽  
Kishore Mohanty ◽  
Manmath Panda
Keyword(s):  
Oil Recovery ◽  
Carbonate Reservoirs ◽  
Wettability Alteration ◽  
Low Permeability ◽  
High Permeability ◽  
Matrix Permeability ◽  
Rock Heterogeneity ◽  
The Matrix ◽  
Flow Through ◽  
Main Factors

Abstract Oil-wetness and heterogeneity (i.e., existence of low and high permeability regions) are two main factors that result in low oil recovery by waterflood in carbonate reservoirs. The injected water is likely to flow through high permeability regions and bypass the oil in low permeability matrix. In this study, systematic coreflood tests were carried out in both "homogeneous" cores and "heterogeneous" cores. The heterogeneous coreflood test was proposed to model the heterogeneity of carbonate reservoirs, bypassing in low-permeability matrix during waterfloods, and dynamic imbibition of surfactant into the low-permeability matrix. The results of homogeneous coreflood tests showed that both secondary-waterflood and secondary-surfactant flood can achieve high oil recovery (>50%) from relatively homogenous cores. A shut-in phase after the surfactant injection resulted in an additional oil recovery, which suggests enough time should be allowed while using surfactants for wettability alteration. The core with a higher extent of heterogeneity produced lower oil recovery to waterflood in the coreflood tests. Final oil recovery from the matrix depends on matrix permeability as well as the rock heterogeneity. The results of heterogeneous coreflood tests showed that a slow surfactant injection (dynamic imbibition) can significantly improve the oil recovery if the oil-wet reservoir is not well-swept.

HISTORY AND MECHANISMS OF ACTIVE FLUID FLOW THROUGH LOW-PERMEABILITY SEDIMENTARY ROCKS

2020 ◽  
Author(s):  
Robert H. Goldstein ◽  
◽  
Sahar Mohammadi ◽  
Andrew Michael Hollenbach
Keyword(s):  
Fluid Flow ◽  
Sedimentary Rocks ◽  
Low Permeability ◽  
Active Fluid ◽  
Flow Through

Low-Permeability Laboratory Measurements by Nonsteady-State and Conventional Methods

1983 ◽  
Vol 23 (06) ◽  
pp. 928-936 ◽  
Author(s):  
David Louis Freeman ◽  
Darrell Cleo Bush
Keyword(s):  
Mass Flow ◽  
Numerical Solutions ◽  
Gas Permeability ◽  
Laboratory Data ◽  
Test Method ◽  
Low Permeability ◽  
Well Completion ◽  
Pore Pressures ◽  
Nonsteady State ◽  
Flow Through

Abstract Evaluation of tight gas reservoirs requires an accurate but rapid and practical method to determine permeability. Such a method is presented for determining both specific and effective gas permeability in the 0.0001- to 0.35-md range for plug-size core samples. Equipment is described that meets the requirements for calculation of nonsteady-state flow and incorporates the capability of simulation, high net overburden pressures by either hydrostatic or triaxial confining pressures with ease of operation. The time required to collect data and calculate Klinkenberg permeability is typically less than 6 minutes per sample. Values normally differ by less than + 5 % from those obtained by steady-state methods. This method is well suited for routine laboratory determinations of permeability on samples from reservoirs with tight or very low gas permeability. Effective gas permeabilities on samples containing nearly irreducible water saturations and the water permeabilities presented are closer to the Klinkenberg permeability values in low-permeability samples than most previously reported. Introduction Substantial price incentives exist in the U.S. to make it attractive for producers to recover gas from tight formations that are less than 15,000 ft 14572 mi deep and have no more than 0.1 md in-situ permeability. This incentive, plus the need for a rapid method to obtain accurate laboratory data on low-permeability samples for well completion and gas reservoir engineering, made it desirable to develop the subject equipment and test method. Various methods used to determine limiting permeability were investigated. The conventional method of determining three specific gas permeabilities and using the Klinkenberg relation to determine a limiting permeability is laborious. Methods involving numerical solutions of one-dimensional (ID) gas-flow equations such as those proposed by Aronofsky and Jenkins and Bruce et al. involve solutions by finite differences. This approach required long calculation times, which made it too cumbersome. Methods such as those proposed by Brace et al. and Walls et al. require pore pressures of the sample to be brought to equilibrium at values close to the reservoir pressure before analysis of the sample, and thus excessive time is required in approaching equilibrium. Jones suggested accounting for the non steady mass flow through the sample during an upstream pressure drawdown test. Such an approach may be used with relatively low mean pore pressures ( - 100 psig ( 690 kPa). The number of calculations was not large, while the reported accuracy was good. The method described in this paper accounts for the nonsteady mass flow through a sample during a downstream pressure-buildup test. The downstream approach allows the smallest possible downstream volumes to be used and ensures flow through the sample. These small downstream volumes allow the detection of very small flow rates in a relatively short time. SPEJ P. 928^

AN ANALYTICAL MODEL FOR TWO-PHASE RELATIVE PERMEABILITY WITH JAMIN EFFECT IN POROUS MEDIA

Fractals ◽  
2018 ◽  
Vol 26 (03) ◽  
pp. 1850037 ◽  
Author(s):  
MINGCHAO LIANG ◽  
YINHAO GAO ◽  
SHANSHAN YANG ◽  
BOQI XIAO ◽  
ZHANKUI WANG ◽  
...  
Keyword(s):  
Porous Media ◽  
Relative Permeability ◽  
Pressure Difference ◽  
Applied Pressure ◽  
Fractal Model ◽  
Low Permeability ◽  
Two Phase ◽  
Low Permeability Reservoir ◽  
Model Predictions ◽  
Flow Through

Jamin effect, which is a capillary pressure obstructing the drop/bubble flow through the narrow throat, has an important effect on the multiphase flow in the low permeability reservoir porous media. In this work, a novel model for the relative permeability with Jamin effect is developed to study the two-phase flow through porous media based on the fractal theory. The proposed relative permeability is expressed as a function of the applied pressure difference, shape parameters of the drop/bubble, the physical parameters of the wetting and nonwetting fluids, and microstructural parameters of porous media. Good agreement between model predictions and available experimental data is obtained, and the advantage of the present fractal model can be highlighted by comparisons with the empirical model predictions. Additionally, the influences of Jamin effect on the two-phase relative permeability are discussed comprehensively and in detail. The model reveals that the length ratios ([Formula: see text] and [Formula: see text]) have significant effects on the relative permeabilities. It is also found that the nonwetting phase relative permeability strongly depends on the interfacial tension, applied pressure difference, viscosity ratio and porosity of porous media at the lower wetting phase saturation. Furthermore, the fractal model will shed light on the two-phase transport mechanism of the low permeability reservoir porous media.

The Divided Flow Permeameter

1988 ◽  
Vol 137 ◽  
Author(s):  
Stephan A. Jefferis ◽  
Raman J. Mangabhai
Keyword(s):  
Separate Flow ◽  
Peripheral Region ◽  
Moisture Distribution ◽  
Single Sample ◽  
Low Permeability ◽  
Test Results ◽  
Total Flow ◽  
King's College ◽  
Flow Through ◽  
Flow Division

AbstractIn permeameters for rigid materials such as concrete, cement paste, or rock the sample is generally sealed into the test cell with a resin or with a pressurised membrane and the permeability is calculated from the total flow through the apparatus. Clearly any leakage around the edge of the sample or other inhomogeneity in the peripheral region will lead to inaccuracy in the measured permeability. This problem is particularly severe with low permeability materials such as concrete and is further exacerbated by the fact that the true permeability of concrete can vary by many orders of magnitude and there may be little information with which to assess whether particular test results are reasonable.The divided flow permeameter offers a technique by which edge leakage and other edge effects can be assessed and several permeability results obtained from different areas of a single sample. The basic principle of this permeameter is that either the inflow or the outflow surface, or both, of the sample are divided into separate flow regions. Provided that there is no difference in pressure between the regions there should be no tendency for flow between them and the flow through each should be proportional to its area.As the technique gives several permeability results for a single sample information about permeability variation within the sample can be obtained; for example data on microcracking, moisture distribution etc. The technique can be used with gas or liquid permeants. The divided flow permeameter system developed at King's College is inexpensive and with a simple system of ‘0’ rings a flow division head can be fitted to many conventional permeameters.

scholarly journals Behavior of Flow Through Low-Permeability Reservoirs

2008 ◽  
Author(s):  
Qun Lei ◽  
Wei Xiong ◽  
Jiangru Yuan ◽  
Shusheng Shusheng Gao ◽  
Yu-Shu Wu
Keyword(s):  
Low Permeability ◽  
Flow Through ◽  
Low Permeability Reservoirs
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