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Summary The fast marching method (FMM)-based rapid flow simulation has been shown to accelerate simulation efficiency by orders of magnitude by transforming 3D simulation to equivalent 1D simulation using the concept of the “diffusive time of flight” (DTOF). However, the 1D transformation does not directly apply to multiwell problems. In this paper, we propose a novel DTOF-based multidomain multiresolution discretization scheme to accelerate multiwell simulation of unconventional reservoirs. Our method formulates multiwell simulation problems based on the DTOF which displays the pressure front propagation in unconventional reservoirs. The DTOF contours are used to partition the reservoir into local and shared domains. A local domain is where the flow is dominated by a single well, and the shared domain is where the fluid flow is influenced by multiple wells. The DTOF contours expand independently in local domains and interfere in the shared domain. After the partitioning, each domain is discretized using a multiresolution scheme whereby the original 3D fine mesh is preserved near the wells to account for detailed physics including gravity, and the rest of the domain is discretized into 1D mesh based on the DTOF contours to alleviate the simulation workload. The power and efficacy of our approach are demonstrated using synthetic and field-scale simulation models with different degrees of geologic and well-completion complexity. The simulation results, number of active cells, and computation time for the proposed discretization scheme are compared with the original high-fidelity 3D model for each case. The results show that the proposed method is suitable for multiwell simulation problems in unconventional reservoirs and can accelerate flow simulations by orders of magnitude with minimal loss of accuracy. The novelty of this work is the creation of DTOF-derived multiresolution discretization with local and shared domains to simplify and accelerate the calculation of subsurface flow problems, especially in unconventional reservoirs. Our workflow can be easily interfaced with commercial simulators, making it suitable for large-scale field applications.
application, Artificial Intelligence, asia government, calculation, complex reservoir, compressibility, datta-gupta, Drillstem Testing, drillstem/well testing, DTOF, eikonal equation, europe government, fast marching method, flow in porous media, Fluid Dynamics, fracture, gridblock, Modeling & Simulation, multiresolution simulation, north america government, paper, reservoir simulation, scaling method, seismic surveying, shale gas, Simulation, transmissibility, unconventional reservoir, unconventional resource technology conference, united states government, Upstream Oil & Gas
Country:
- North America > United States > Texas (1.00)
- Europe (0.93)
- Asia (0.93)
Industry:
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.46)
Oilfield Places:
SPE Disciplines:
- Reservoir Description and Dynamics > Reservoir Simulation > Scaling methods (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (0.95)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (0.93)
Technology:
The linear equation solver is an important component in a reservoir simulator. It is used in the Newton step to solve the discretized nonlinear partial differential equations. These equations describe mass balances on the individual components treated in the model. For nonisothermal problems, an energy balance is added to the system. The matrix problem involves solvingAx b, where A is typically a large sparse matrix, b is the right-side vector, andx is the vector of unknowns.
Technology:
Any reservoir simulator consists of n m equations for each of N active gridblocks comprising the reservoir. These equations represent conservation of mass of each ofn components in each gridblock over a timestep Δt from tn to tn 1 . The firstn (primary) equations simply express conservation of mass for each of n components such as oil, gas, methane, CO2, and water, denoted by subscript I 1,2,…,n. In the thermal case, one of the "components" is energy and its equation expresses conservation of energy. An additional m (secondary or constraint) equations express constraints such as equal fugacities of each component in all phases where it is present, and the volume balanceSw So Sg Ssolid 1.0, whereS solid represents any immobile phase such as precipitated solid salt or coke. There must be n m variables (unknowns) corresponding to these n m equations. For example, consider the isothermal, three-phase, compositional case with all components present in all three phases.
Artificial Intelligence, asia government, asset and portfolio management, complex reservoir, condensate reservoir, conformance improvement, Directional Drilling, drilling operation, Drillstem Testing, drillstem/well testing, enhanced recovery, equation of state, europe government, Exhibition, flow in porous media, Fluid Dynamics, formulation, gas injection method, grid, history matching, Modeling & Simulation, multiphase flow, norway government, permeability, presented, processor, production control, production logging, production monitoring, PVT measurement, Reservoir Characterization, reservoir geomechanics, reservoir simulation, Reservoir Surveillance, SAGD, scaling method, Simulation, simulator, spe annual technical conference, spe reservoir simulation symposium, steam-assisted gravity drainage, streamline simulation, structural geology, thermal method, time-lapse seismic surveying, time-lapse surveying, united kingdom government, united states government, Upstream Oil & Gas, waterflooding, Wellbore Design, wellbore integrity
Country:
- Europe > United Kingdom (1.00)
- Europe > Norway (1.00)
- North America > United States > Texas (0.94)
- (2 more...)
Geophysics:
- Geophysics > Seismic Surveying (0.67)
- Geophysics > Time-Lapse Surveying > Time-Lapse Seismic Surveying (0.67)
Oilfield Places:
- South America > Argentina > Patagonia > Golfo San Jorge Basin (0.99)
- North America > United States > California > San Joaquin Basin > Lost Hills Field (0.99)
- North America > United States > Alaska > North Slope Basin > Prudhoe Bay Field (0.99)
- (20 more...)
SPE Disciplines:
Technology:
Abstract The key idea with multiscale methods for reservoir simulation is to construct a set of prolongation operators that interpolate solutions from a coarse spatial resolution to the grid resolution. Efficient multiscale methods need prolongation operators that accurately represent flow at the grid resolution. For high-contrast models, it is especially important that this flow interpolation is confined within high-contrast boundaries. In this paper, we present an improved algorithm to construct multiscale prolongation operators that better capture strong contrasts in geological properties. Specifically, to construct effective prolongation operators, the improved algorithm first finds dominant flow directions by comparing the values of connection transmissibility in a neighborhood, then emphasizes the interpolation along these dominant directions and ignores the interpolation in transverse direction if connection transmissibility is weak. The new algorithm is implemented in a commercial reservoir simulator that also provides a commercial implementation of a state-of-the-art multiscale method. The advantage of the new algorithm is demonstrated using synthetic and real reservoir models with high-contrast features. We also analyze the interpolation errors of poorly constructed prolongation operators for such models to identify the root cause of the slow linear solver convergence rate. With the new algorithm, we obtain better linear and nonlinear convergence rates in the pressure solver and shorter simulation time than with a previously published state-of-the-art multiscale method. For completeness, we also benchmark our multiscale pressure solver performance against a standard algebraic multigrid (AMG) fine-scale pressure solver, and we highlight differences in linear solver convergence and computational efficiency. Finally, we demonstrate that the new algorithm is beneficial for a real high-contrast heterogeneous field model.
algorithm, Artificial Intelligence, boundary, coarse grid, convergence, equation, europe government, iteration, linear iteration, linear solver convergence, Modeling & Simulation, multistage preconditioner, neighborhood, num, preconditioner, prolongation operator, reservoir simulation, scaling method, solver, transmissibility, united kingdom government, united states government, Upstream Oil & Gas
Country:
- North America > United States > Texas (0.29)
- Europe > United Kingdom > England (0.28)
Technology:
Abstract The use of hydraulic fracturing to improve well productivity in tight reservoirs and connecting unconsolidated quality reservoirs via hydraulic fracturing is very well practiced in the oil industry. Currently to model hydraulic fracture in order to fully assess its effect in the well and its interaction with the formation (or different layers) requires upscaling methods to reach higher resolution (refinement) in order to reach certain accuracy in simulations like sector-based or local grid refinement techniques around well-reservoir modeling. However, modeling hydraulic fracturing in a large full-field reservoir simulation model with hundreds of wells and millions of cells is computationally very expensive. The aim of this proposal is to provide an alternative modeling of hydraulic fracturing at any size-based cell without the need of refinement saving computational cost. Even though computational capacity has increase exponentially in the last decade, the complexity and resolution of simulation models does overwhelm conventional computational processing leaving high resolutions models to corporations and companies with major resources in computing as the only capable to ensure an effective simulation of stimulation in wells modeling interaction with full field reservoir models. The search of alternatives to simplify and propose representative models of hydraulic fracture is part of needed applications to provide tools in field development and reservoir management scenarios, specially if a sizable data base with good quality surveying and compensated with production and performance data can represent key cornerstones to create meaningful characteristic variables in order to apply in modeling and forecast activities as history matching. This paper proposes a new approach to model the hydraulic fracturing (HF) effect based on a volumetric relation between created fracture and influenced volume in a designated reservoir/productive formation to be use specially in coarse simulation models to simulate the enhancement of the hydraulic fracture effects in production and history matching modeling. The use of field data and pressure matched properties based on stimulation parameters is the foundation to rely on. The new approach helped developing a fracture factor used to model permeability interaction between formation and stimulated volume designated by cell size and position. The proposed approach guaranties no change on regional nor alteration of static model properties maintaining the geological concept intact and providing a more realistic approach in order to simulate effectively stimulation in modeled wells in any type of grid or geometry of cells.
alteration, asia government, assessment, coarse scale simulation model, conductivity, effective approach, fcdf, fracture, geometry, hydraulic fracture, hydraulic fracturing, Implementation, interaction, modeling, Modeling & Simulation, modeling hydraulic fracture, productivity, relation, reliability, reservoir simulation, scaling method, stimulation, united states government, Upstream Oil & Gas
Country:
- Asia > Middle East (0.47)
- North America > United States (0.28)
SPE Disciplines:
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