On Near Wellbore Modeling and Real Time Reservoir Management
Abstract: TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper is concerned with the problems of real time reservoir management, simulation while drilling and near well bore modeling. These problems are discussed in terms of work process, feasibility as well as numerical and simulation related aspects. A software tool developed to perform high precision local simulation and at the same time account for global field behaviour is described. Field examples are presented to illustrate the potential and use for sim… Show more
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Cited by 3 publications
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Use of sector models with fine grids that preserve the boundary conditions of the full field model has been of particular benefit to studying well coning behaviour for the different well geometries while allowing detail studies of the physics of flow and to optimize production rate by different well designs. The objective of this project was to carry out simulation studies to investigate the pattern of gas coning and water encroachment for a bilateral well with the primary aim of producing oil from a reservoir overlain by a large gas cap in Field A. High precision local refinement studies in the simulation model were undertaken to help place the wells and optimize the completion design at the same time capturing the global field behaviour. This methodology was also used to properly simulate multilateral wells containing inflow control devices, allowing for pressure losses along the wellbore to be equalized and to minimize gas and water coning. Prior to undertaking the simulation studies, several sensitivities were carried out to determine how other parameters such as boundary conditions and grid refinements could affect the output of near well bore models. By taking advantage of the time savings resulting from the generation of reduced fine grid models, several simulations were run to investigate the impact of different well configurations and operations due for instance to close/opening of valves or laterals. The simulation studies resulted in the determination of the pattern of gas coning, water encroachment, optimum vertical placement of the oil lateral and the orientation of the gas lateral as they affect total recovery. The use of Inflow Control Device (ICD) was determined to be of benefit especially in controlling water and gas influx while providing a uniform production profile along the wellbore that delay gas and water coning and this is being incorporated now in the plan of development. Introduction These simulation studies are part of an ongoing reservoir development project for a gas/oil field with an oil rim about 40m thick and large gas cap. The objective of this study was to carry out several sensitivity studies so as to optimize the production of oil using multilateral well and smart completions, while accounting for the uncertainties in developing the model. The main uncertainties that have been identified while developing the static model include determination of the exact fluid contacts GOC and GWC, depth conversion methods, porosity and permeability distribution, which are directly related to facies distribution. Uncertainties in the dynamic model include permeability distribution, relative permeability data, impact of fractures, direction and density, aquifer size and connectivity, and the transmissibility in the z-direction. The main focus of this project was to try to model capture the effects of some of these uncertainties and how they impact the production of oil from the well. The multilateral wells are bilateral with the top lateral drilled through the gas cap with the primary aim of producing gas which will serve as the means for meeting the gas requirements for a natural gas lift system and gas producers when oil production finishes. The well completion is such as to make the gas available at the main bore and at the appropriate depth to lighten the liquid column with the adequate adjustment of the inlet control valves if water breakthrough fractures.
Use of sector models with fine grids that preserve the boundary conditions of the full field model has been of particular benefit to studying well coning behaviour for the different well geometries while allowing detail studies of the physics of flow and to optimize production rate by different well designs. The objective of this project was to carry out simulation studies to investigate the pattern of gas coning and water encroachment for a bilateral well with the primary aim of producing oil from a reservoir overlain by a large gas cap in Field A. High precision local refinement studies in the simulation model were undertaken to help place the wells and optimize the completion design at the same time capturing the global field behaviour. This methodology was also used to properly simulate multilateral wells containing inflow control devices, allowing for pressure losses along the wellbore to be equalized and to minimize gas and water coning. Prior to undertaking the simulation studies, several sensitivities were carried out to determine how other parameters such as boundary conditions and grid refinements could affect the output of near well bore models. By taking advantage of the time savings resulting from the generation of reduced fine grid models, several simulations were run to investigate the impact of different well configurations and operations due for instance to close/opening of valves or laterals. The simulation studies resulted in the determination of the pattern of gas coning, water encroachment, optimum vertical placement of the oil lateral and the orientation of the gas lateral as they affect total recovery. The use of Inflow Control Device (ICD) was determined to be of benefit especially in controlling water and gas influx while providing a uniform production profile along the wellbore that delay gas and water coning and this is being incorporated now in the plan of development. Introduction These simulation studies are part of an ongoing reservoir development project for a gas/oil field with an oil rim about 40m thick and large gas cap. The objective of this study was to carry out several sensitivity studies so as to optimize the production of oil using multilateral well and smart completions, while accounting for the uncertainties in developing the model. The main uncertainties that have been identified while developing the static model include determination of the exact fluid contacts GOC and GWC, depth conversion methods, porosity and permeability distribution, which are directly related to facies distribution. Uncertainties in the dynamic model include permeability distribution, relative permeability data, impact of fractures, direction and density, aquifer size and connectivity, and the transmissibility in the z-direction. The main focus of this project was to try to model capture the effects of some of these uncertainties and how they impact the production of oil from the well. The multilateral wells are bilateral with the top lateral drilled through the gas cap with the primary aim of producing gas which will serve as the means for meeting the gas requirements for a natural gas lift system and gas producers when oil production finishes. The well completion is such as to make the gas available at the main bore and at the appropriate depth to lighten the liquid column with the adequate adjustment of the inlet control valves if water breakthrough fractures.
Numerical Reservoir Simulation has been used in the industry as a powerful production planning tool over the last 20 years, and its efficiency for reservoir production forecasts is very well known. Nevertheless, simulation models are the final result of multiple data sources representing considerable time efforts in model building and updating. This restricts the technique to processes and decisions that can only be held inside level of days, weeks and even months; and depending on the resolution of the geological description and the complexity of the fluid behavior, simulation runs could be very time consuming. This paper address the possibility to use reservoir simulation while drilling to simulate the reservoir conditions in real-time and dynamically improve the well trajectory and completion strategy based on the well performance predictions. During this study a critical review of the techniques that can improve the reservoir simulation speed and the real-time model updates is presented. To better quantify the impact of this technique, a synthetic model based on real information from a North Sea Field was used and the reservoir model was continuously updated by assuming new information from well logs and structural markers. Advanced simulation techniques, as boundary conditions and grid refinement, were combined to improve the speed of the simulation runs while preserving an acceptable level of accuracy in the well performance predictions. Multiple wells deviations and configurations can be planned using this methodology while drilling a well. Introduction On the last few years there has been an increasing adoption of advanced wells (wells with arbitrary trajectory and/or multiple branches) for many field development programs. These wells are designed to increase productivity by intercepting multiple targets and contacting greatest portions of the reservoir. With the introduction of the Geosteering technique, real-time data acquisition from Logging While Drilling / Measurement While Drilling (LWD/MWD) tools has been used to make a correlation of the subsurface model and keep a continuous monitoring of the well position. While this technique results valuable to continuously correlate the initial well targets with the actual position, the optimization of the well trajectory based only in geological criteria may not lead to optimal results. The productivity of an advanced well is a very complex problem involving geometrical and structural considerations, anisotropy of near wellbore heterogeneities, multiphase flow phenomena like friction and phase slipping (non darcy effects), among others, which can only be treated rigorously by building a representative simulation model. Reservoir Simulation has been traditionally used as a tool for field development planning, partly because model updates have only been considered within level of months and years, when an extensive amount of new information has become available. But today, this misleading conception may be coming to an end. Next generation reservoir simulators are becoming faster and more stable. The evolution of high performance parallel clusters dramatically increases the computational speed needed to solve complex flow problems and modern reservoir simulator architectures has been adapted to show scalable performance on these platforms. Novel software tools allow you to integrate real-time information and perform automatic geological and property updates on the reservoir description. The convergence of all of these state-of-the-art technologies clearly shows that today is feasible to perform fast and accurate performance predictions and introduce the reservoir simulation technique within the context of real-time optimization. During this work a general framework for the introduction of Simulation While Drilling (SiWD) for the optimization of the well construction process in real-time will be presented. A detailed summary of the techniques that enable the process of SiWD are described and the existing challenges that still needs to be addressed for the success of this technique will be explained. Finally, a synthetic model is presented with its results to evaluate the potential benefits and pitfalls that might be expected from a SiWD exercise.
The Optimization of Fracturing Parameters of Horizontal Well under Different Reservoir Conditions in Tight Sandstone Gas Reservoir
Abstract-In order to ensure the good fracturing effect of horizontal well in the Sulige gas field, block SuX of Sulige gas field was used as an example, the typical horizontal wells of different fracturing mode were selected. According to the different reservoir conditions, the fracturing mode of horizontal well was optimized, the hybrid PEBI meshing method of near wellbore module (NWM) of numerical simulation software named Eclipse was used to mesh the typical horizontal well area, the coupling relationship between the fracture of fractured horizontal well and wellbore and matrix was described, the coupled numerical simulation model between the matrix of gas reservoir and fracture was established, the fracture parameters including fracture interval, fracture half length and fracture conductivity of different fracturing mode of horizontal wells were reasonably optimized using numerical simulation method, the reasonable configuration relationship between the reservoir conditions and the fracturing parameters of horizontal well were established. The results indicate that, the different fracturing mode is suitable for the reservoir conditions, and the reasonable fracturing parameter is suitable for the fracturing mode.
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