Abstract:Summary
A new technique is presented for analyzing pressuretransient data for wells intercepted by afinite-conductivity vertical fracture. This method is basedon the bilinear flow theory, which considers transientlinear flow in both fracture and formation. It isdemonstrated that a graph of p vs. t 1/4 produces astraight line whose slope is inversely proportional toh (k b) 1/2 . New type curves are presented thatovercome the uniqueness problem exhibited by othertype curves.
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“…E. Ortiz R. et al: Two-dimensional numerical investigations with previous theoretical and numerical analyses (Cinco-Ley and Samaniego-V., 1981;Weir, 1999), the derivatives follow a straight line with a slope of 1/4 over over a certain period of dimensionless time. For sufficiently high dimensionless fracture conductivities (i.e., T D 1), the derivative first turns counterclockwise into a straight line with slope ½cor-responding to formation linear flow, fully developed only for T D > 50 (Fig.…”
mentioning
confidence: 76%
“…A1 in Cinco-Ley and Samaniego-V., 1981), the transient term on the left side appears multiplied by the diffusivity ratio κ = D m /D F . When this ratio is small, the effect of the intrinsic transient term on wellbore pressure becomes important only for extremely small values of time, and thus can be neglected for bilinear flow (see Cinco-Ley and Samaniego-V., 1981;Riley, 1991).…”
Section: Modeling Approachmentioning
confidence: 99%
“…The theoretical background of bilinear flow was first presented by Cinco-Ley et al (1978) and Cinco-Ley and Samaniego-V. (1981), who studied the solution of (1) and (2) using a two-dimensional numerical model and Laplace transform, respectively. They demonstrated that the pressure in a vertically fractured well producing at constant flow rate is proportional to the fourth root of time in the bilinear flow regime.…”
Section: Previously Presented Solutions For Bilinear Flowmentioning
confidence: 99%
“…The time window, during which this fourth-root relation can be observed, is however finite, and thus long-term predictions -of great practical importance for exploitation of liquid or gaseous resources -are erroneous when using this relationship. Therefore, constraining estimates of the end time of bilinear flow received attention in previous research (Cinco-Ley and Samaniego-V., 1981;Weir, 1999). Since radial flow dominated by the matrix properties develops when this time is exceeded, it specifically marks the end of the gain due to a stimulation operation involving hydraulic fracturing.…”
Abstract. Bilinear flow occurs when fluid is drained from a permeable matrix by producing it through an enclosed fracture of finite conductivity intersecting a well along its axis. The terminology reflects the combination of two approximately linear flow regimes: one in the matrix with flow essentially perpendicular to the fracture, and one along the fracture itself associated with the non-negligible pressure drop in it. We investigated the characteristics, in particular the termination, of bilinear flow by numerical modeling allowing for an examination of the entire flow field without prescribing the flow geometry in the matrix. Fracture storage capacity was neglected relying on previous findings that bilinear flow is associated with a quasi-steady flow in the fracture. Numerical results were generalized by dimensionless presentation. Definition of a dimensionless time that, other than in previous approaches, does not use geometrical parameters of the fracture permitted identifying the dimensionless well pressure for the infinitely long fracture as the master curve for type curves of all fractures with finite length from the beginning of bilinear flow up to fully developed radial flow. In log-log scale the master curve's logarithmic derivative initially follows a 1/4-slope straight line (characteristic for bilinear flow) and gradually bends into a horizontal line (characteristic for radial flow) for long times. During the bilinear flow period, isobars normalized to well pressure propagate with the fourth and second root of time in fracture and matrix, respectively. The width-to-length ratio of the pressure field increases proportional to the fourth root of time during the bilinear period, and starts to deviate from this relation close to the deviation of well pressure and its derivative from their fourth-root-oftime relations. At this time, isobars are already significantly inclined with respect to the fracture. The type curves of finite fractures all deviate counterclockwise from the master curve instead of clockwise or counterclockwise from the 1/4-slope straight line as previously proposed. The counterclockwise deviation from the master curve was identified as the arrival of a normalized isobar reflected at the fracture tip 16 times earlier. Nevertheless, two distinct regimes were found in regard to pressure at the fracture tip when bilinear flow ends. For dimensionless fracture conductivities T D < 1, a significant pressure increase is not observed at the fracture tip until bilinear flow is succeeded by radial flow at a fixed dimensionless time. For T D > 10, the pressure at the fracture tip has reached substantial fractions of the associated change in well pressure when the flow field transforms towards intermittent formation linear flow at times that scale inversely with the fourth power of dimensionless fracture conductivity. Our results suggest that semi-log plots of normalized well pressure provide a means for the determination of hydraulic parameters of fracture and matrix after shorter test duration ...
“…E. Ortiz R. et al: Two-dimensional numerical investigations with previous theoretical and numerical analyses (Cinco-Ley and Samaniego-V., 1981;Weir, 1999), the derivatives follow a straight line with a slope of 1/4 over over a certain period of dimensionless time. For sufficiently high dimensionless fracture conductivities (i.e., T D 1), the derivative first turns counterclockwise into a straight line with slope ½cor-responding to formation linear flow, fully developed only for T D > 50 (Fig.…”
mentioning
confidence: 76%
“…A1 in Cinco-Ley and Samaniego-V., 1981), the transient term on the left side appears multiplied by the diffusivity ratio κ = D m /D F . When this ratio is small, the effect of the intrinsic transient term on wellbore pressure becomes important only for extremely small values of time, and thus can be neglected for bilinear flow (see Cinco-Ley and Samaniego-V., 1981;Riley, 1991).…”
Section: Modeling Approachmentioning
confidence: 99%
“…The theoretical background of bilinear flow was first presented by Cinco-Ley et al (1978) and Cinco-Ley and Samaniego-V. (1981), who studied the solution of (1) and (2) using a two-dimensional numerical model and Laplace transform, respectively. They demonstrated that the pressure in a vertically fractured well producing at constant flow rate is proportional to the fourth root of time in the bilinear flow regime.…”
Section: Previously Presented Solutions For Bilinear Flowmentioning
confidence: 99%
“…The time window, during which this fourth-root relation can be observed, is however finite, and thus long-term predictions -of great practical importance for exploitation of liquid or gaseous resources -are erroneous when using this relationship. Therefore, constraining estimates of the end time of bilinear flow received attention in previous research (Cinco-Ley and Samaniego-V., 1981;Weir, 1999). Since radial flow dominated by the matrix properties develops when this time is exceeded, it specifically marks the end of the gain due to a stimulation operation involving hydraulic fracturing.…”
Abstract. Bilinear flow occurs when fluid is drained from a permeable matrix by producing it through an enclosed fracture of finite conductivity intersecting a well along its axis. The terminology reflects the combination of two approximately linear flow regimes: one in the matrix with flow essentially perpendicular to the fracture, and one along the fracture itself associated with the non-negligible pressure drop in it. We investigated the characteristics, in particular the termination, of bilinear flow by numerical modeling allowing for an examination of the entire flow field without prescribing the flow geometry in the matrix. Fracture storage capacity was neglected relying on previous findings that bilinear flow is associated with a quasi-steady flow in the fracture. Numerical results were generalized by dimensionless presentation. Definition of a dimensionless time that, other than in previous approaches, does not use geometrical parameters of the fracture permitted identifying the dimensionless well pressure for the infinitely long fracture as the master curve for type curves of all fractures with finite length from the beginning of bilinear flow up to fully developed radial flow. In log-log scale the master curve's logarithmic derivative initially follows a 1/4-slope straight line (characteristic for bilinear flow) and gradually bends into a horizontal line (characteristic for radial flow) for long times. During the bilinear flow period, isobars normalized to well pressure propagate with the fourth and second root of time in fracture and matrix, respectively. The width-to-length ratio of the pressure field increases proportional to the fourth root of time during the bilinear period, and starts to deviate from this relation close to the deviation of well pressure and its derivative from their fourth-root-oftime relations. At this time, isobars are already significantly inclined with respect to the fracture. The type curves of finite fractures all deviate counterclockwise from the master curve instead of clockwise or counterclockwise from the 1/4-slope straight line as previously proposed. The counterclockwise deviation from the master curve was identified as the arrival of a normalized isobar reflected at the fracture tip 16 times earlier. Nevertheless, two distinct regimes were found in regard to pressure at the fracture tip when bilinear flow ends. For dimensionless fracture conductivities T D < 1, a significant pressure increase is not observed at the fracture tip until bilinear flow is succeeded by radial flow at a fixed dimensionless time. For T D > 10, the pressure at the fracture tip has reached substantial fractions of the associated change in well pressure when the flow field transforms towards intermittent formation linear flow at times that scale inversely with the fourth power of dimensionless fracture conductivity. Our results suggest that semi-log plots of normalized well pressure provide a means for the determination of hydraulic parameters of fracture and matrix after shorter test duration ...
“…The efficiency of the first step depends on fracture dimension length "x f " and height "h f, " and the efficiency of the second step depends on fracture permeability "k f. " The importance of each of the steps can be analyzed using the concept of parameter fracture conductivity "F CD " defined as (Agarwal et al 1979;Cinco-Ley 1981): (w f is fracture width)…”
Section: Hydraulic Fractured Well Simulationmentioning
A significant percentage of hydrocarbon reservoirs around the world is fractured. Moreover, the major part of gas reservoirs in Iran is also fractured type, so the existence of an in-house software is necessary. In this study, an efficient, user-friendly, and indigenous simulation of a three-dimensional black oil fractured dry gas reservoir has been developed through IMPES method with the two-phase flow of gas and water. The presented simulator, which was written by C ++ language and was known as fracture dry gas reservoir simulator, uses the implicit pressure and explicit saturation method for solving the equations. Also, effect of gravity pressure is neglected and effect of the capillary is considered in equations. By this simulator, we can investigate the dry gas reservoirs behavior with fractures. Darcy or non-Darcy fracture and matrix flow, Cartesian, cylindrical, and combination of Cartesian-cylindrical reservoir gridding, single porosity, dual porosity-single permeability, and dual porosity-dual permeability modeling are abilities of this simulator too. Additionally, this simulator is able to make outputs (such as pressure) at any given specific radius and time interval as numerical and/or graphical output in so little run time. Also, this simulator has PVT box and gridding box for doing the calculation of PVT and gridding. PVT box contains new correlations and EOS in comparison with another reservoir simulator. Gridding box makes us be able to simulate fractured dry gas reservoirs and hydraulically fractured well reservoirs too. Finally, the validity of this simulator was verified by comparing the simulation results with the other reservoir simulator (Eclipse) and showed a good compatibility between the developed software and Eclipse results in each time with different conditions such as various gridding conditions, various fluid data conditions and also various well configuration conditions.
Due to the duality in terms of (1) the groundwater flow field and (2) the discharge conditions, flow patterns of karst aquifer systems are complex. Estimated aquifer parameters may differ by several orders of magnitude from local (borehole) to regional (catchment) scale because of the large contrast in hydraulic parameters between matrix and conduit, their heterogeneity and anisotropy. One approach to deal with the scale effect problem in the estimation of hydraulic parameters of karst aquifers is the application of large‐scale experiments such as long‐term high‐abstraction conduit pumping tests, stimulating measurable groundwater drawdown in both, the karst conduit system as well as the fractured matrix. The numerical discrete conduit‐continuum modeling approach MODFLOW‐2005 Conduit Flow Process Mode 1 (CFPM1) is employed to simulate laminar and nonlaminar conduit flow, induced by large‐scale experiments, in combination with Darcian matrix flow. Effects of large‐scale experiments were simulated for idealized settings. Subsequently, diagnostic plots and analyses of different fluxes are applied to interpret differences in the simulated conduit drawdown and general flow patterns. The main focus is set on the question to which extent different conduit flow regimes will affect the drawdown in conduit and matrix depending on the hydraulic properties of the conduit system, i.e., conduit diameter and relative roughness. In this context, CFPM1 is applied to investigate the importance of considering turbulent conditions for the simulation of karst conduit flow. This work quantifies the relative error that results from assuming laminar conduit flow for the interpretation of a synthetic large‐scale pumping test in karst.
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