The Experts below are selected from a list of 75 Experts worldwide ranked by ideXlab platform
J.c. Robinson - One of the best experts on this subject based on the ideXlab platform.
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Transient Test Analysis: Solution-Gas-Drive Reservoir Examples
All Days, 1992Co-Authors: Wei-chun Chu, T.m. Little, J.c. RobinsonAbstract:Abstract Considerable research has been devoted to the analysis of pressure-transient data obtained from solution-Gas-Drive Reservoirs. Several techniques from the literature are demonstrated on data acquired from two wells in the Sand Dunes Field. Comparison and discussion of the resulting analyses are provided to aid the practicing engineer in selecting the appropriate evaluation method. Techniques evaluated for determination of flow capacity include pseudopressure, pressure-squared, modified MDH, direct calculation from derivative data, and type-curve analysis. Recent developments that enhance the quality of pressure-transient analysis, including the integral pressure, normalized integral pressure and changing wellbore-storage model, are also applied. Additionally, determination of drainage area from pressure-derivative data is demonstrated. Introduction Single-phase, conventional analysis of pressure-buildup data obtained from the Sand Dunes Field, a solution-Gas-Drive Reservoir located in Converse County, Wyoming, has previously been presented. Extensive data from both pre-stimulation and post-stimulation pressure buildup tests were analyzed to quantify Reservoir properties, determine completion damage and evaluate stimulation effectiveness. Comparison of the pressure response between the damaged and improved systems revealed two important characteristics:the damaged system demonstrates a longer period of wellbore storage andthe damaged system exhibits a wider separation between pressure change and its derivative during the "horizontal stabilization" portion of the test. These characteristics of the data can be utilized as qualitative indicators of near-wellbore conditions. In this paper, analysis of the pressure-buildup data is expanded to include a number of recent advances, particularly with regard to analysis of multiphase flow. Data obtained from the Sand Box 6–19 well is analyzed utilizing the pseudopressure and pressure-squared approaches and then compared to the conventional analysis. In addition, effective permeability as a function of pressure is calculated directly from the shut-in pressure. Application of the integral-pressure-derivative method to reduce noise in the derivative curve is demonstrated on the Sand Box 6–19 data. The smoothing effect of this technique is shown to aid type-curve matching, thereby simplifying interpretation of the well-test data. Finally, early-time data from the pre-stimulation buildup test, which had exhibited changing wellbore storage, was successfully matched utilizing the error function. Expanded pressure-derivative analysis of the buildup data obtained from Sand Box 7–14 includes computation of the drainage area at the instant of shut-in, and flow capacity. An extended post-stimulation buildup test, which consisted of over 300 hours of data acquisition, was performed on this well in anticipation of obtaining additional Reservoir information. P. 613^
Albertus Retnanto - One of the best experts on this subject based on the ideXlab platform.
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Inflow Performance Relationships of Horizontal and Multibranched Wells in a Solution- Gas-Drive Reservoir
European Petroleum Conference, 1998Co-Authors: Albertus Retnanto, Michael J. EconomidesAbstract:In predicting and optimizing the performance of single and multiple wells, or complex well architecture, within a drainage or flow unit, we have favored benchmark analytical or semianalytical models. Recently, a general productivity model has been constructed and presented that allows for the performance prediction of any single- and multi-well configuration within any Reservoir geometry in both isotropic and anisotropic media. Such an approximation is known to have limitations when applied to two-phase Reservoir flow. This work used a numerical simulator to generate IPR's for horizontal or multibranched wells producing from a solution-Gas-Drive Reservoir. First, a base case is considered with typical fluid, rock, and Reservoir properties. Then, variations from the base case are investigated. These variations cover a wide range of fluid, Reservoir, and well characteristics. The effects of numerous Reservoir and fluid properties on the calculated curves are investigated. Bubblepoint pressure and Reservoir depletion have a significant effect on the curves. A generalized dimensionless IPR based on nonlinear regression analysis of simulator results is developed. This IPR curve is then used to predict the performance of horizontal and multibranched wells in a solution-Gas-Drive Reservoir combined with our productivity model. For relatively low bubblepoint pressures, the curves coalesce on Vogel's classic relationship. For higher pressures they deviate substantially.
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Inflow Performance Relationships Gas-Drive Reservoir of Horizontal and Multibranched
1998Co-Authors: Albertus Retnanto, Michael J. EconomiesAbstract:In predicting and optimizing the performance of single and multiple wells, or complex well architecture, within a drainage or flow unit, we have favored benchmark analytical or semianalytical models. Recently, a general productivity model has heen constructed and presented that allows for the performance prediction of any single- and multi-well configuration within any Reservoir geometry in both isotropic and anisotropic media. Such an approximation is known to have limitations when applied to two-phase Reservoir flow. This work used a numerical simulator to generate IPR’s for horizontal or multibranched wells producing from a solutionGas-Drive Reservoir. First, a base case is considered with typical fluid, rock, and Reservoir properties. Then, variations from the base case are investigated. These variations cover a wide range of fluid, Reservoir, and well characteristics. The effects of numerous Reservoir and fluid properties on the calculated curves are investigated. Bubblepoint pressure and Reservoir depletion have a significant effect on the curves, A generalized dimensionless RR based on nonlinear regression analysis of simulator results is developed. This IPR curve is then used to predict the performance of horizontal and multibranched wells in a solution-Gas-Drive Reservoir combined with our productivity model. For relatively low bubblepoint pressures, the curves coalesce on Vogel’s classic relationship. For higher pressures they deviate substantially.
Thomas Alwin Blasingame - One of the best experts on this subject based on the ideXlab platform.
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inflow performance relationship ipr for solution Gas Drive Reservoirs analytical considerations
SPE Annual Technical Conference and Exhibition, 2007Co-Authors: Rodolfo Camacho Velazquez, Thomas Alwin BlasingameAbstract:This work provides the analytical development of "Vogel"type Inflow Performance Relation (or IPR) correlations for solution Gas-Drive Reservoir systems using characteristic flow behavior. Specifically, we provide the following results: ● An analytical form of the quadratic (Vogel) IPR correlation:
Hyai-shang Wang - One of the best experts on this subject based on the ideXlab platform.
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A Two-Phase IPR for Horizontal Oil Wells
All Days, 2005Co-Authors: Michael L. Wiggins, Hyai-shang WangAbstract:Abstract This paper investigates the rate-pressure behavior of a horizontal oil well with a fully penetrating wellbore producing during the boundary dominated flow regime. Based on linear regression analysis of simulator results, two empirical inflow performance relationships (IPRs) are developed to estimate well performance. A future performance relationship is also developed to allow estimates of future rate-pressure behavior from current test information. The IPR relationships are compared to other horizontal IPRs available in the literature and yield reasonable estimates of well behavior over a wide range of operating conditions. Introduction The number of horizontal well drilled by the oil and Gas industry has escalated rapidly since the mid-1980's primarily because the wells offer production solutions where conventional technology either fails or produces results that are less than desirable. The major advantage of a horizontal well is to increase the Reservoir contact area and thereby enhance well productivity or injectivity. Compared to a vertical well, the horizontal well can achieve higher ultimate recovery and produce at higher flow rates in certain Reservoir conditions. The horizontal well may be a viable economic alternative for naturally fractured Reservoirs, low permeability Reservoirs and in Reservoirs with oil and Gas coning problems. In many improved oil recovery applications, the horizontal well may be a suitable alternative for both production and injection. Over the years, the productivity of horizontal wells has been the subject of numerous studies. From these studies, several analytical solutions have been proposed to estimate horizontal well performance.[1–5] These solutions are based on single-phase flow principles and may not be appropriate for two-phase, oil-Gas flow. In time, several investigators have utilized Reservoir simulators to study the behavior of a horizontal well producing from solution-Gas Drive Reservoirs.[6–10] These investigations have led to proposed empirical inflow performance relationships (IPRs) to predict the rate-pressure behavior of horizontal oil wells. In 1968, Vogel[11] presented an empirical IPR for an oil well producing from a solution-Gas Drive Reservoir. This IPR for two-phase, oil-Gas flow was based on the analysis of simulation results and gained quick acceptance by industry as it was simple to apply and yielded acceptable results. Fetkovich and others soon followed with similar type IPRs for boundary-dominated flow in oil wells. These relations were developed for vertical wells and may not be appropriate for horizontal oil wells. Plahn et al.[6] were early investigators who studied the multiphase behavior of horizontal wells in a solution-Gas Drive Reservoir. They used a Reservoir simulator to investigate the well behavior and the effect of various Reservoir rock and fluid properties on that behavior. From this work, the authors developed a set of type curves that could be used to forecast production from horizontal oil wells producing at their maximum rate. In 1989, Bendakhlia and Aziz[7] utilized a commercial Reservoir simulator to study the performance of horizontal oil wells producing from solution-Gas Drive Reservoirs. Their work paralleled that of Vogel for vertical wells. Based on their simulation results they concluded that the inflow performance curves were not significantly affected by Reservoir rock and fluid properties; however, they did find the curves were influenced by the stage of Reservoir depletion. They proposed the following IPR for horizontal oil wells.
O.k. Dankwa - One of the best experts on this subject based on the ideXlab platform.
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Production Analysis for Solution Gas-Drive Reservoirs: General Variable Pressure/Variable Rate Case -Theory
All Days, 2014Co-Authors: Shaibu Mohammed, E. M. Amarfio, O.k. DankwaAbstract:Abstract Presently, analytical models for estimating Reservoir parameters for solution Gas-Drive are restricted to either constant pressure or constant rate assumption. Thus, current models for solution Gas-Drive do not allow for rigorous analysis of simultaneous variations in pressure and rate. In addition, the traditional material balance time or pseudotime, which models variable pressure and/or variable rate case, is limited to single-phase flow. This paper proposes a normalized multiphase pseudotime function that is capable of modeling general variable pressure and/or variable rate data for solution Gas Drive Reservoirs during boundary-dominated flow. In particular, we present a multiphase flow equation that incorporates this pseudotime function. This flow equation is expressed in a form that traces the rate/time harmonic depletion curve. Thus, the proposed approach allows analysts to use a single depletion curve to model constant rate, constant pressure and variable pressure/variable rate cases for solution Gas Drive Reservoir systems. In addition, we propose a multiphase pseudocumulative function that is normalized by pseudopressure drop to permit the extension of flowing material balance method to solution Gas Drive. This is essential since analysis using flowing material balance method offers a better resolution than decline type curves. It also permits the computation of initial-oil-in-place. The significant contribution of this paper is the generality of the proposed model that allows the rigorous handling of variable pressure and/or variable rate case for solution Gas Drive Reservoir systems. Thus, the proposed approach, as opposed to existing models, is not limited to production constraints. Only the appropriate equations and the methods of analyses and interpretation are presented in this paper. Illustrative examples are deferred to a subsequent writing.
