A Comprehensive Application of a Composite Reservoir Model to Pressure-Transient Analysis

Olarewaju, J.S.; Lee, John W.

doi:10.2118/16345-pa

Cited by 25 publications

(14 citation statements)

References 15 publications

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“…In practice, the first semilog straight line may be masked by wellbore storage, whereas the second straight line may not have been reached or may be superseded by boundary effects, thus making the intersection-time method often inapplicable. Another method uses type-curve matching of well-test pressure and pressure-derivative data (Olarewaju and Lee 1989;Olarewaju et al 1991). The pressure match can be used to calculate the inner-region mobility: …”

Section: Appendix Amentioning

confidence: 99%

“…Interpretation of gas/condensate pressure-transient data that exhibit a two-or a three-region radial composite behavior yields the effective reservoir permeability, the wellbore skin effect, and the mobility or permeability ratios between the various regions [using straight-line analysis (Brown 1985)-see Appendix B-or typecurve matching (Olarewaju and Lee 1989)]. The storativity ratio between two adjacent regions, however, cannot be uncoupled from the radius because analytical well-test-analysis methods can only account for one set of pressure/volume/temperature (PVT) data, yet both are needed to estimate the total skin effect.…”

Section: Introductionmentioning

confidence: 99%

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Condensate Bank Characterization from Well Test Data and Fluid PVT Properties

Bozorgzadeh

Gringarten

2006

SPE Reservoir Evaluation &Amp; Engineering

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Published well-test analyses in gas/condensate reservoirs in which the pressure has dropped below the dewpoint are usually based on a two-or three-region radial composite well-test interpretation model to represent condensate dropout around the wellbore and initial gas in place away from the well. Gas/condensate-specific results from well-test analysis are the mobility and storativity ratios between the regions and the condensate-bank radius. For a given region, however, well-test analysis cannot uncouple the storativity ratio from the region radius, and the storativity ratio must be estimated independently to obtain the correct bank radius. In most cases, the storativity ratio is calculated incorrectly, which explains why condensate bank radii from well-test analysis often differ greatly from those obtained by numerical compositional simulation.In this study, a new method is introduced to estimate the storativity ratios between the different zones from buildup data when the saturation profile does not change during the buildup. Application of the method is illustrated with the analysis of a transientpressure test in a gas/condensate field in the North Sea. The analysis uses single-phase pseudopressures and two-and three-zone radial composite well-test interpretation models to yield the condensate-bank radius. The calculated condensate-bank radius is validated by verifying analytical well-test analyses with compositional simulations that include capillary number and inertia effects. Fig. 1-Schematic of pressure and derivative composite behavior (Gringarten et al. 2000).

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Section: Appendix Amentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Condensate Bank Characterization from Well Test Data and Fluid PVT Properties

Bozorgzadeh

Gringarten

2006

SPE Reservoir Evaluation &Amp; Engineering

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“…Issaka and Ambastha (1996) developed a generalised pressure derivative formula for a composite reservoir to identify the flow regimes in four flow geometries (radial, elliptical, linear and spherical). Olarewaju and Lee (1989) found that the pressure derivative curves for a composite reservoir show a different response from homogeneous reservoirs. Jokhio et al (2001) and Hachlaf et al (2002) extended the Tiab's direct synthesis technique to analyse injection and fall off tests in water injection wells, and the problem was described and solved as a composite reservoir.…”

Section: Introductionmentioning

confidence: 98%

Estimating distance to water front for edge water using derivative of pressure transient data

Alrumah

Ertekin

2016

IJOGCT

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New procedures are proposed to help estimate the distance to the discontinuity under certain conditions with good accuracy. These procedures can be applied using the derivative of the pressure buildup test data if the mobility ratio is less than unity. A 3-D numerical model is used to generate pressure transient data from synthetic data for a vertical well. The reservoir is considered as a composite reservoir where the inner zone contains the oil phase, and the outer zone contains the water phase. Some of the parameters that control the accuracy of the proposed analysis procedure are the producing time and the external reservoir radius. The procedures are useful in monitoring the position of the edge water front for future planning development purposes.[porous media including shale oil, shale gas and coalbed methane reservoirs. He, with his graduate students, works in the implementation of advanced simulation, well testing and artificial intelligence technologies to the 2 M. Alrumah and T. Ertekin aforementioned reservoir systems. His research efforts with his graduate students have produced more than 100 PhD and MS theses. He is the author and co-author more than 250 publications including four books and has given more than 250 lectures and seminars, workshops and short courses throughout the world.

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“…According to the concept of composite reservoir, when there is a discontinuity in the material properties in the radial direction from a well, the reservoir can be regarded as a composite reservoir [26][27][28]. Considering that acid fracturing creates a high permeability zone near the wellbore, the case of a well with wormholes and artificial fractures in FVCRs can be represented by a composite reservoir.…”

Section: Introductionmentioning

confidence: 99%

Analysis of Flow Behavior for Acid Fracturing Wells in Fractured-Vuggy Carbonate Reservoirs

Wang

Fan

Dong

et al. 2018

Mathematical Problems in Engineering

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This study develops a mathematical model for transient flow analysis of acid fracturing wells in fractured-vuggy carbonate reservoirs. This model considers a composite system with the inner region containing finite number of artificial fractures and wormholes and the outer region showing a triple-porosity medium. Both analytical and numerical solutions are derived in this work, and the comparison between two solutions verifies the model accurately. Flow behavior is analyzed thoroughly by examining the standard log-log type curves. Flow in this composite system can be divided into six or eight main flow regimes comprehensively. Three or two characteristic V-shaped segments can be observed on pressure derivative curves. Each V-shaped segment corresponds to a specific flow regime. One or two of the V-shaped segments may be absent in particular cases. Effects of interregional diffusivity ratio and interregional conductivity ratio on transient responses are strong in the early-flow period. The shape and position of type curves are also influenced by interporosity coefficients, storativity ratios, and reservoir radius significantly. Finally, we show the differences between our model and the similar model with single fracture or without acid fracturing and further investigate the pseudo-skin factor caused by acid fracturing.

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A Comprehensive Application of a Composite Reservoir Model to Pressure-Transient Analysis

Cited by 25 publications

References 15 publications

Condensate Bank Characterization from Well Test Data and Fluid PVT Properties

Condensate Bank Characterization from Well Test Data and Fluid PVT Properties

Estimating distance to water front for edge water using derivative of pressure transient data

Analysis of Flow Behavior for Acid Fracturing Wells in Fractured-Vuggy Carbonate Reservoirs

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