Saudi Arabian Oil Company

Massachusetts Institute of Technology

Saudi Aramco

Aramco Services Company

Ali Haydar Dogru

Jorge A Pita

Xiang Yang Ding

Nabil M Al-Zamel

Larry Siu-Kuen Fung

Usuf Middya

John R Williams

Larry S Fung

Qiqi Wang

James C T Tan

Florian Mannuss

Maitham Makki Alhubail

Thomas James Byer

Systems and methods include a computer-implemented method for generating and using a graph/document structure to store reservoir simulation results. A graph is generated that represents reservoir simulation results of a reservoir simulation performed on a reservoir using a reservoir simulation model. The graph represents a full set of relational data and non-relational data included in the reservoir simulation results. The graph stores graph information and relational data in a graph/document structure. Objects of the reservoir, elements of the reservoir simulation results, and inputs of the reservoir simulation model are represented as vertices in the graph. Relationships between vertices are represented as edges in the graph. An edge is defined by a pair of vertices in the graph.

Graph framework (database methods) to analyze trillion cell reservoir and basin simulation results

A method may include determining, during a first time step within an iterative simulation process, various pseudo-pressure values based on model data. The method may include determining, during the first time step, a first set of skin factor values for the wellbore radial grid portions using the pseudo-pressure values. The method may include simulating, during the first time step, a first well production rate for a well within a reservoir region of interest using the first set of skin factor values and a first pressure distribution for the reservoir region of interest. The method may include simulating, during a second time step within the iterative simulation process, a second well production rate for the well using a second set of skin factor values and a second pressure distribution for the reservoir region of interest.

Methods and systems for gas condensate well performance prediction

Performance of computers is improved during determination of pressure distribution among grid cells of a reservoir model during reservoir simulation by computer processing. Convergence can prove difficult to obtain when conditions cause a coefficient matrix involved in the processing to become indefinite. An indefinite coefficient matrix can occur either due to physical conditions in the reservoir related to vapor liquid equilibria, or due to nonphysical conditions created numerically due to improper derivatives. The conventional previously taken corrective action of time step cutting is avoided when convergence becomes difficult during reservoir simulation. Time step cutting has proven to be very costly, in terms of computer usage and time, for very large reservoirs having models involving millions, billions or more number of unknown parameter values.

Reservoir simulation with pressure solver for non-diagonally dominant indefinite coefficient matrices

Orthogonal unstructured grids are automatically constructed for a field or reservoir model with two types of internal boundaries: complex wells and faults, or other discontinuities. The methodology is used to constructed simulation grids for reservoirs or fields which contains both complex fault planes and multi-lateral wells. A hierarchical grid point generation, prioritization, conflict point removal system is provided enabling the use of unconstrained Delaunay triangulation. High-quality orthogonal unstructured grids are produced with good convergence properties for reservoir simulation.

Modeling reservoir flow and transport processes in reservoir simulation

A data processing system systems with parallel processors performing simulations by numerical solution of partial differential equations or similar numerical simulations. The data processing system extends the scaling limit of parallel solvers in those numerical simulations by overcoming the frequent network latencies encountered during a simulation. Fewer, yet larger batches of data are exchanged between computing nodes.

Parallel processor data processing system with reduced latency

A data processing system is provided which determines the migration of oil and gas by a basin simulation section and predicts future reservoir performance from current reservoir production measures. The data processing system provides more accurate reservoir rock and fluid property distribution in reservoir locations between well locations where such attributes cannot be measured. The data processing system operates based on physical realities captured from migration by the basin simulation section. The data processing system differs from conventional methods, which use measurements obtained at the wells and interpolate between for regions between the wells using statistical techniques. Results from the data processing system shed more light into reservoir discontinuities among the wells, and yield better distribution of hydrogen sulfide, tar zones (Heavy Oil) within the reservoir. More accurate initial fluid and rock property distribution within the reservoir in a reservoir model obtained with the data processing system also improves production forecasting accuracy for hydrocarbon reservoirs by the reservoir simulation section.

Locating new hydrocarbon fields and predicting reservoir performance from hydrocarbon migration

A subsurface hydrocarbon reservoir is simulated by sequential solution of reservoir and well equations to simulate fluid flow inside the reservoir and well production rates. Sequential solution of reservoir and well equations treats wells as specified bottom hole pressure wells. This avoids solving large matrices resulting from the simultaneous solution of the reservoir and well equations which can be computationally very expensive for large number of unknowns and require special sparse matrix solvers. Such sequential solution involves regular reservoir system solvers complemented by small matrices for the numerical solution of the well bottom hole pressures. The solution is performed on tridiagonal matrices for the adjacent reservoir cells to the well cells at the perforated well intervals; and a vector of the unknown reservoir potentials for the adjacent reservoir cells.

Sequential fully implicit well model with tridiagonal matrix structure for reservoir simulation

A subsurface hydrocarbon reservoir with horizontal wells is simulated by sequential solution of reservoir and well equations to simulate fluid flow inside the reservoir and well production rates. Sequential solution of reservoir and well equations treats wells as specified bottom hole pressure wells. This avoids solving large matrices resulting from the simultaneous solution of the reservoir and well equations which can be computationally very expensive for large number of unknowns and require special sparse matrix solvers. Such sequential solution involves regular reservoir system solvers complemented by a small matrix for the numerical solution of the well bottom hole pressures.

Sequential fully implicit horizontal well model with tridiagonal matrix structure for reservoir simulation

Computer system performance is improved during reservoir simulation runs where heterogeneous rock formations suffer from convergence problems. Convergence problems are affected by accurate determination of pressure distribution for reservoir simulation, which is very complex when properties or attributes of reservoir rock formations are heterogeneous. In heterogeneous reservoir rock formations, pressure distribution is affected over three dimensions by variations of rock permeability and porosity. The difficulty in convergence of the simulation runs results in increased computer operation and processing time and consequent computer usage costs. Improved determination of pressure distribution in heterogeneous rock formations permits acceptable initial pressure measures for pressure determination during reservoir simulation and to reduce convergence problems with existing reservoir simulation.

Determining pressure distribution in heterogeneous rock formations for reservoir simulation

Modeling intersecting faults and complex wellbores in reservoir simulation

Unstructured grids are automatically constructed in a domain containing complex internal boundaries. Simulation grids are constructed for reservoirs or fields which contain complex fault planes. Reconciling among generated fault grid-points and other reservoir/field grid-points is performed, enabling the use of unconstrained Delaunay triangulation. High-quality orthogonal unstructured grids are provided with good convergence properties for reservoir simulation.

Generating unconstrained voronoi grids in a domain containing complex internal boundaries

A subsurface hydrocarbon reservoir with a horizontal well or multiple vertical wells is simulated by sequential solution of reservoir and well equations to simulate fluid flow inside the reservoir and well production rates. Sequential solution of reservoir and well equations treats wells as specified bottom hole pressure wells. This avoids solving large matrices resulting from the simultaneous solution of the reservoir and well equations which can be computationally very expensive for large number of unknowns and require special sparse matrix solvers. Such sequential solution involves regular reservoir system solvers complemented by small matrices for the numerical solution of the well bottom hole pressures. The solution is performed on tridiagonal matrices for the adjacent reservoir cells to the well cells at the perforated well intervals; and a vector of the unknown reservoir potentials for the adjacent reservoir cells.

A subsurface hydrocarbon reservoir with wells is simulated by sequential solution of reservoir and well equations to simulate fluid flow inside the reservoir and well production rates. Sequential solution of reservoir and well equations treats wells as specified bottom hole pressure wells. This avoids solving large matrices resulting from the simultaneous solution of the reservoir and well equations which can be computationally very expensive for large number of unknowns and require special sparse matrix solvers. Such sequential solution involves regular reservoir system solvers complemented by a small matrix for the numerical solution of the well bottom hole pressures. The solution is performed on a matrix of the transmissibilities of the adjacent reservoir cells to the well cells at the perforated well intervals; and a vector of unknown reservoir potentials for the adjacent reservoir cells.

Sequential fully implicit well modeling of transmissibility for reservoir simulation

A subsurface hydrocarbon reservoir with wells is simulated by sequential solution of reservoir and well equations to simulate fluid flow inside the reservoir and well production rates. Sequential solution of reservoir and well equations treats wells as specified bottom hole pressure wells. This avoids solving large matrices resulting from the simultaneous solution of the reservoir and well equations which can be computationally very expensive for large number of unknowns and require special sparse matrix solvers. Such sequential solution involves regular reservoir system solvers complemented by a small matrix for the numerical solution of the well bottom hole pressures. The solution is on a steady state volume balance relationship of the layer completion rates, formation pressures and transmissibilities to determine completion rates for the layers of the well for the full reservoir model, and determine total rate for the well from the determined completion rates for the layers of the well.

Growing community of inventors

Dhahran, Saudi Arabia

Ali Haydar Dogru