An Equation To Predict Two-Phase Relative Permeability Curves in Fractures

2010 ◽  
Author(s):  
Andres Chima ◽  
Efren Antonio Chavez Iriarte ◽  
Zuly Himelda Calderon Carrillo
Keyword(s):  
Relative Permeability ◽  
Two Phase ◽  
Relative Permeability Curves

scholarly journals Relative Permeability Characteristics During Carbon Capture and Sequestration Process in Low-Permeable Reservoirs

Materials ◽  
2020 ◽  
Vol 13 (4) ◽  
pp. 990
Author(s):  
Mingxing Bai ◽  
Lu Liu ◽  
Chengli Li ◽  
Kaoping Song
Keyword(s):  
Relative Permeability ◽  
Carbon Capture ◽  
Oil And Gas ◽  
Co2 Flooding ◽  
Two Phase ◽  
Permeability Characteristics ◽  
Gas Recovery ◽  
Miscible Flooding ◽  
Relative Permeability Curves ◽  
Carbon Dioxide Co2

The injection of carbon dioxide (CO2) in low-permeable reservoirs can not only mitigate the greenhouse effect on the environment, but also enhance oil and gas recovery (EOR). For numerical simulation work of this process, relative permeability can help predict the capacity for the flow of CO2 throughout the life of the reservoir, and reflect the changes induced by the injected CO2. In this paper, the experimental methods and empirical correlations to determine relative permeability are reviewed and discussed. Specifically, for a low-permeable reservoir in China, a core displacement experiment is performed for both natural and artificial low-permeable cores to study the relative permeability characteristics. The results show that for immiscible CO2 flooding, when considering the threshold pressure and gas slippage, the relative permeability decreases to some extent, and the relative permeability of oil/water does not reduce as much as that of CO2. In miscible flooding, the curves have different shapes for cores with a different permeability. By comparing the relative permeability curves under immiscible and miscible CO2 flooding, it is found that the two-phase span of miscible flooding is wider, and the relative permeability at the gas endpoint becomes larger.

The Characteristics and Impacts Factors of Relative Permeability Curves in High Temperature and Low-Permeability Limestone Reservoirs

2014 ◽  
Vol 1010-1012 ◽  
pp. 1676-1683 ◽  
Author(s):  
Bin Li ◽  
Wan Fen Pu ◽  
Ke Xing Li ◽  
Hu Jia ◽  
Ke Yu Wang ◽  
...  
Keyword(s):  
Relative Permeability ◽  
Oil Recovery ◽  
Water Saturation ◽  
Phase Region ◽  
Two Phase ◽  
Experimental Conditions ◽  
Irreducible Water Saturation ◽  
Productive Water ◽  
Relative Permeability Curves ◽  
Water Cut

To improve the understanding of the influence of effective permeability, reservoir temperature and oil-water viscosity on relative permeability and oil recovery factor, core displacement experiments had been performed under several experimental conditions. Core samples used in every test were natural cores that came from Halfaya oilfield while formation fluids were simulated oil and water prepared based on analyze data of actual oil and productive water. Results from the experiments indicated that the shape of relative permeability curves, irreducible water saturation, residual oil saturation, width of two-phase region and position of isotonic point were all affected by these factors. Besides, oil recovery and water cut were also related closely to permeability, temperature and viscosity ratio.

A Semianalytical Approach for Analysis of Wells Exhibiting Multiphase Transient Linear Flow: Application to Field Data

SPE Journal ◽  
2020 ◽  
Vol 25 (06) ◽  
pp. 3265-3279
Author(s):  
Hamidreza Hamdi ◽  
Hamid Behmanesh ◽  
Christopher R. Clarkson
Keyword(s):  
Numerical Model ◽  
Relative Permeability ◽  
History Matching ◽  
Volatile Oil ◽  
Low Permeability ◽  
Two Phase ◽  
Linear Flow ◽  
Field Case ◽  
Three Phase ◽  
Relative Permeability Curves

Summary Rate-transient analysis (RTA) is a useful reservoir/hydraulic fracture characterization method that can be applied to multifractured horizontal wells (MFHWs) producing from low-permeability (tight) and shale reservoirs. In this paper, we applied a recently developed three-phase RTA technique to the analysis of production data from an MFHW completed in a low-permeability volatile oil reservoir in the Western Canadian Sedimentary Basin. This RTA technique is used to analyze the transient linear flow regime for wells operated under constant flowing bottomhole pressure (BHP) conditions. With this method, the slope of the square-root-of-time plot applied to any of the producing phases can be used to directly calculate the linear flow parameter xfk without defining pseudovariables. The method requires a set of input pressure/volume/temperature (PVT) data and an estimate of two-phase relative permeability curves. For the field case studied herein, the PVT model is constructed by tuning an equation of state (EOS) from a set of PVT experiments, while the relative permeability curves are estimated from numerical model history-matchingresults. The subject well, an MFHW completed in 15 stages, produces oil, water, and gas at a nearly constant (measured downhole) flowing BHP. This well is completed in a low-permeability,near-critical volatile oil system. For this field case, application of the recently proposed RTA method leads to an estimate of xfk that is in close agreement (within 7%) with the results of a numerical model history match performed in parallel. The RTA method also provides pressure–saturation (P–S) relationships for all three phases that are within 2% of those derived from the numerical model. The derived P–S relationships are central to the use of other RTA methods that require calculation of multiphase pseudovariables. The three-phase RTA technique developed herein is a simple-yet-rigorous and accurate alternative to numerical model history matching for estimating xfk when fluid properties and relative permeability data are available.

A New Analytical Equation to Predict Gas-Water Two-Phase Relative Permeability Curves in Fractures

2014 ◽  
Author(s):  
Gang Lei ◽  
Pingchuan Dong ◽  
Shu Yang ◽  
Yuansheng Li ◽  
Shaoyuan Mo ◽  
...  
Keyword(s):  
Relative Permeability ◽  
Analytical Equation ◽  
Two Phase ◽  
Relative Permeability Curves

A New Analytical Equation to Predict Gas-Water Two-Phase Relative Permeability Curves in Fractures

2014 ◽  
Author(s):  
Gang Lei ◽  
Pingchuan Dong ◽  
Shu Yang ◽  
Yuansheng Li ◽  
Shaoyuan Mo ◽  
...  
Keyword(s):  
Relative Permeability ◽  
Analytical Equation ◽  
Two Phase ◽  
Relative Permeability Curves

scholarly journals New ν ‐type relative permeability curves for two‐phase flows through subsurface fractures

2015 ◽  
Vol 51 (4) ◽  
pp. 2807-2824 ◽  
Author(s):  
Noriaki Watanabe ◽  
Keisuke Sakurai ◽  
Takuya Ishibashi ◽  
Yutaka Ohsaki ◽  
Tetsuya Tamagawa ◽  
...  
Keyword(s):  
Relative Permeability ◽  
Two Phase Flows ◽  
Two Phase ◽  
Subsurface Fractures ◽  
Relative Permeability Curves

scholarly journals Promediando curvas de permeabilidad relativa en yacimientos de metano en mantos de carbón con flujo bifásico en Queensland, Australia.

2017 ◽  
Vol 4 (1) ◽  
pp. 129-140
Author(s):  
Jorge Ordóñez ◽  
José Villegas ◽  
Alamir Alvarez
Keyword(s):  
Relative Permeability ◽  
Water Saturation ◽  
Single Layer ◽  
Absolute Permeability ◽  
Phase Flow ◽  
Two Phase ◽  
Desorption Process ◽  
Gas Desorption ◽  
Relative Permeability Curves ◽  
Single Set

En el presente trabajo se propone el uso de un único set de curvas de permeabilidad a ser empleado en los estudios de simulación y caracterización de yacimientos de gas en mantos de carbón (CBM), en vez del uso común de un set de curvas para cada estrato individual. Para comprobar la aplicabilidad de este procedimiento, se simula un yacimiento usando ambos métodos: el resultado de producción debe ser similar en ambas simulacionesEl modelo para promediar la permeabilidad absoluta en un flujo monofásico, fue usado para el caso de predecir un promedio de permeabilidad relativa para un yacimiento con flujo bifásico. Luego de correr varios casos y corroborar que la ecuación propuesta no cumplía las expectativas, el enfoque del trabajo fue explicar el por qué del no funcionamiento de la ecuación propuesta. Una posible explicación fue la no consideración de la gravedad, que acorde a varias simulaciones presentadas, es un parámetro principal en las curvas de producción. La saturación de agua tampoco puede excluirse de la ecuación que prediga este promedio.  Por tanto si se quiere presentar una ecuación para el cálculo de promedio de permeabilidades relativas, es fundamental que tanto la gravedad como la saturación de agua estén incluidas en esta ecuación.Abstract This paper tries to average relative permeability in a way that instead of using different sets of relative permeability curves to different layers, one single set could be used in one single layer, and to get similar production results as if different layers and different relative permeability were used instead. The model to average absolute permeability in a single-phase flow system was used to predict two-phase flow average relative permeability. After running different cases and corroborating that the equation proposed did not match the expectations. The focus of this work was changed in order to explain why the equation was not working. A possible explanation of why the equation is not accurate could be that the equation is not considering the influence of gravity. Gravity plays a very important role in reservoirs. After gas desorption process occurs, free gas migrates to top layers and water migrates to bottom layers. Water saturation could not be excluded from the equation that averages relative permeability curves. The effects of gravity should be considered too, if you want to get an equation to predict production behaviour by using one average equation in a single layer.

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