scholarly journals Study on Validation of the OPM Reservoir Simulator by Comparative Solution Project

2020 ◽  
Vol 4 (4) ◽  
pp. 1-8
Author(s):  
Fan H
Keyword(s):  
Porous Media ◽  
Reservoir Simulation ◽  
Simulation Models ◽  
Operating Conditions ◽  
Reproducible Research ◽  
Well Test ◽  
Balance Test ◽  
Industry Standard ◽  
Wide Range ◽  
Reservoir Simulator

The Open Porous Media (OPM) reservoir simulation toolkit is a free and open-source development in the reservoir simulation world and one that has received very little attention. OPM Flow is a fully-implicit, black-oil simulator capable of running industry-standard simulation models, which encourage open innovation and reproducible research on modeling and simulation of porous media processes. This study validates and assesses the capabilities of OPM Flow comparing with the industry standard ECLIPSE simulator. Several tests were conducted in order to validate the simulator, including a zero- balance test, symmetrical well test, three simulation models based on the SPE Comparative Solution Project, and a real world dataset from the Norne oilfield in Norway. This variety of tests covers a wide range of reservoir types and specific operating conditions which are representative of expected applications of the software. By comparison it is concluded that OPM Flow reservoir simulator can be considered a validated and capable reservoir simulator that is able to compete with Schlumberger ECLIPSE in many cases and shows great potential for future development. In addition, a basic user interface for queuing and running simulations through the OPM Flow simulator was developed using the Python programming language as well as some modifications to the miscible flooding solver.

Incorporating Economic Decisions into Reservoir Simulation to Support Accurate and Efficient Optimization and Analysis of Field Development Strategies

2021 ◽  
Author(s):  
Jim Browning ◽  
Sheldon Gorell
Keyword(s):  
Reservoir Simulation ◽  
Value Added ◽  
Simulation Models ◽  
Operating Conditions ◽  
Conditional Logic ◽  
Economic Optimization ◽  
Field Development ◽  
Production Constraints ◽  
Automated Method ◽  
Economic Decision Making

Abstract Economic optimization of a reservoir can be extremely tedious and time consuming. It is particularly difficult with many wells, some of which can become non-economic within the simulated time period. These problems can be mitigated by: 1) analyzing the results of a simulation once it has run, or 2) applying injection or production constraints at the well level. An example of option 1 would be integration with a spreadsheet or economic simulation package after the simulation has run. An example of option 2 would be to set a maximum water cut, upon which the well constraints could be changed, or the well could be shut in within the simulation. Both of these methods have drawbacks. If the goal is to account for how changes in a well operating strategy affects other wells, then analysis after the fact requires many runs to sequentially identify and modify well constraints at the correct times and in the correct order. In contrast, applying injection and production constraints to wells is not the same as applying true economic constraints. The objective of this work was to develop an automated method which includes economic considerations within the simulator to decrease the amount of time optimizing a single model and allows more time to analyze uncertainty within the economic decision making process. This study developed automated methods and procedures to include economic calculations within the context of a standard reservoir simulation. The method utilized modifications to available conditional logic features to internally include and export key economic metrics to support appropriate automatic field development changes. This method was tested using synthetic models with different amounts of wells and operating conditions. It was validated using after the fact calculations on a well by well basis to confirm the process. People costs are always among the most significant associated with running a business. Therefore, it is imperative for people to be as efficient and productive as possible. The method presented in this study significantly reduces the amount of time and effort associated with tedious and manual manipulations of simulation models. These savings enable an organization to focus on more value-added activities including, but not limited to, accurately optimizing and estimating of uncertainty associated decisions supported by reservoir simulation.

Uncertainty Analysis in the Production History Matching by Using Proxies as Reservoir Simulators

2012 ◽  
Author(s):  
Paulo Camargo Silva ◽  
Virgílio José Martins Ferreira Filho
Keyword(s):  
Probability Density ◽  
Reservoir Simulation ◽  
History Matching ◽  
Simulation Models ◽  
Difficult Problem ◽  
Probability Density Functions ◽  
Density Functions ◽  
Production History ◽  
Definition Of ◽  
Reservoir Simulator

In the recent literature of the production history matching the problem of non-uniqueness of reservoir simulation models has been considered a difficult problem. Complex workflows have been proposed to solve the problem. However, the reduction of uncertainty can only be done with the definition of Probability Density Functions that are highly costly. In this article we introduce a methodology to reduce uncertainty in the history matching using techniques of Monte Carlo performed on proxies as Reservoir Simulator. This methodology is able to compare different Probability Density Functions for different reservoir simulation models to define among the models which simulation model can provide more appropriate matching.

MUFITS: A Universal Reservoir Simulator for Numerical Modelling, History Matching and Optimization of Multicomponent Flows in Porous Media

2020 ◽  
Author(s):  
Andrey Afanasyev ◽  
Elena Vedeneeva ◽  
Natalia Gorokhova
Keyword(s):  
Carbon Dioxide ◽  
Porous Media ◽  
Numerical Modelling ◽  
History Matching ◽  
External Control ◽  
Flows In Porous Media ◽  
Reservoir Simulations ◽  
Multicomponent Flows ◽  
Wide Range ◽  
Reservoir Simulator

<p>The recent development of the academic reservoir simulator MUFITS aims its transformation to a universal software package that allows for (a) numerical modelling of non-isothermal multicomponent flows in porous media under wide range of pressures and temperatures, including under critical thermodynamic conditions, (b) history matching of non-isothermal reservoir models, and (c) optimization of thermohydrodynamic processes in porous media.</p><p>The extended simulator capabilities for modelling of multicomponent flows includes a new fluid properties module for compositional and thermal reservoir simulations using different cubic equations of state (e.g. Peng-Robinson EoS). An extended library of hydrocarbons, carbon dioxide, nitrogen, water, and other components is built into the simulator, and additional components can be characterized and loaded into the library. An arbitrary number of components can be used in particular simulation. In order to simplify the module usage, the corresponding input data are made compatible with the petroleum industry standards. Unlike many other codes, MUFITS allows for compositional modelling of non-isothermal flows of fluids which properties are predicted with a cubic EoS.</p><p>For improved history matching and optimization the simulator is supplied with an external Simulation Control Unit (SCU), which automatically changes certain parameters of the digital reservoir model and reads back the results of the simulations. An external control loop is implemented in SCU. At each iteration of the loop non-isothermal flow in a porous medium is simulated, and the simulation results are used for calculation of the objective function being minimized. In order to accelerate the history matching and optimization, the SCU can simultaneously (in parallel) run several reservoir simulations. The simulator is supplied with the build-in capabilities for the calculation of gravity changes and surface uplift/subsidence which measurements can also be automatically used in history matching.</p><p>We complement the new developments with several application examples related to gas condensate fields exploration, carbon dioxide injection in depleted oil reservoirs and gas storages, and natural flows in deep geothermal systems.</p><p>We acknowledge the funding from Russian Science Foundation under grant # 19-71-10051.</p>

The chemical versus energy cost tug of war: A pulp mill perspective

TAPPI Journal ◽  
2011 ◽  
Vol 10 (7) ◽  
pp. 37-42 ◽  
Author(s):  
PETER W. HART
Keyword(s):  
Low Cost ◽  
Laboratory Data ◽  
Pulp Mill ◽  
Simulation Models ◽  
Operating Conditions ◽  
Operating Point ◽  
Cost Constraints ◽  
Cooking Process ◽  
Wide Range ◽  
The Impact

As the cost of energy and processing chemicals changes, the optimal, lowest cost operating conditions within a pulp mill also change. Additionally, the optimal cost operating point within one area of the mill may not result in a total mill low cost operation. Three practical pulp mill examples have been analyzed under varying cost constraints for energy and chemicals to determine the impact of energy and chemical cost changes on the low cost operating point. These examples include changing the digester kappa number target, changing the brownstock washing dilution factor, and the conversion of a continuous digester from one type of cooking process to a lower energy cooking process. Selected mill operating results and laboratory data were employed to tune various process simulation models to obtain cost predictions over a wide range of operating conditions.

The Athel: A Challenging Formation in South Oman

1998 ◽  
Vol 1 (04) ◽  
pp. 354-358
Author(s):  
P.M. O'Dell
Keyword(s):  
Reservoir Simulation ◽  
Simulation Models ◽  
Hydraulic Fractures ◽  
Well Testing ◽  
Well Test ◽  
Pressure Transient ◽  
Original Manuscript ◽  
Project Costs ◽  
Challenges And Opportunities ◽  
The Difference

This paper (SPE 50981) was revised for publication from paper SPE 37748, first presented at the 1997 SPE Middle East Oil Show held in Bahrain, 15-18 March. Original manuscript received for review 19 March 1997. Revised manuscript received 19 May 1998. Paper peer approved 26 May 1998. Summary The Athel silicilyte is a deep, tight formation containing light oil and dissolved sour gas. Because the potential volume is large, there is interest in early development. However, because individual wells are very expensive, every opportunity to gather information must be used. Well testing (production tests, pressure/volume/temperature (PVT) sampling, production logging runs, and pressure transient tests) has been used extensively to characterize the reservoir, to guide appraisal activities, and to shape the ultimate development. Key issues to be resolved before development are initial and sustained productivity and project costs. Production tests have demonstrated both challenges and opportunities in producing from this unique formation. Pressure transient tests have indicated that effective reservoir permeability is one-tenth of cleaned core plug permeability. The difference is likely caused by some combination of sealed fractures and the plugging effects of bitumen in the reservoir. Production logging has been used to measure the fraction of pay contributing to production. Reservoir simulation models, based on well test results, have been used to predict initial rates and ultimate recoveries for various well types (vertical, multiple drainhole, and multiple hydraulic fractures). Project costs (number of wells required) are based on these reservoir simulation results. P. 354

Investigation of Nanoparticle Adsorption During Transport in Porous Media

SPE Journal ◽  
2015 ◽  
Vol 20 (04) ◽  
pp. 667-677 ◽  
Author(s):  
Tiantian Zhang ◽  
Michael J. Murphy ◽  
Haiyang Yu ◽  
Hitesh G. Bagaria ◽  
Ki Youl Yoon ◽  
...  
Keyword(s):  
Porous Media ◽  
Flow Rate ◽  
Operating Conditions ◽  
Nanoparticle Concentration ◽  
Irreversible Adsorption ◽  
Nanoparticle Transport ◽  
Adsorption Sites ◽  
Adsorption Capacities ◽  
Wide Range ◽  
Pass Through

Summary Nanoparticles (diameter of approximately 5 to 50 nm) easily pass through typical pore throats in reservoirs, but physicochemical attraction between nanoparticles and pore walls may still lead to significant retention. We conducted an extensive series of nanoparticle-transport experiments in core plugs and in columns packed with crushed sedimentary rock, systematically varying flow rate, type of nanoparticle, injection-dispersion concentration, and porous-medium properties. Effluent-nanoparticle-concentration histories were measured with fine resolution in time, enabling the evaluation of nanoparticle adsorption in the columns during slug injection and post-flushes. We also applied this analysis to nanoparticle-transport experiments reported in the literature. Our analysis suggests that nanoparticles undergo both reversible and irreversible adsorption. Effluent-nanoparticle concentration reaches the injection concentration during slug injection, indicating the existence of an adsorption capacity. Experiments with a variety of nanoparticles and porous media yield a wide range of adsorption capacities (from 10–5 to 101 mg/g for nanoparticles and rock, respectively) and also a wide range of proportions of reversible and irreversible adsorption. Reversible- and irreversible-adsorption sites are distinct and interact with nanoparticles independently. The adsorption capacities are typically much smaller than monolayer coverage. Their values depend not only on the type of nanoparticle and porous media, but also on the operating conditions, such as injection concentration and flow rate.

Non-Darcy Flow Through Fibrous Porous Media

1969 ◽  
Vol 36 (4) ◽  
pp. 711-714 ◽  
Author(s):  
G. S. Beavers ◽  
E. M. Sparrow
Keyword(s):  
Porous Media ◽  
Flow Characteristics ◽  
Reynolds Numbers ◽  
Characteristic Dimension ◽  
Operating Conditions ◽  
Darcy Flow ◽  
Square Root ◽  
Axial Pressure Gradient ◽  
Wide Range ◽  
Metallic Fibers

Experiments are performed to explore the flow characteristics of porous media having the form of a latticework of metallic fibers. Five such media are investigated, four among which share the characteristic that there are no free fiber ends within the medium. The operating conditions of the experiments extend over a wide range of velocities greater than those for Darcy flow, but permeabilities deduced from the data are applicable to the Darcy regime. It is shown that for all the investigated media, the axial pressure gradient is representable as the sum of two terms, one linear in the velocity (viscous contribution) and the second quadratic in the velocity (inertia contribution). The flow-pressure characteristics for the structurally similar porous media are representable by a single dimensionless expression wherein the square root of the permeability is used as the characteristic dimension. Significant departures from Darcy’s law first occur at Reynolds numbers on the order of one; similar values of the Reynolds number are known to mark the termination of the regime of viscous unseparated flow about spheres and cylinders. This accord lends further support to the use of the square root of the permeability as the characteristic dimension.

scholarly journals A semi-implicit approach for the modeling of wells with inflow control completions

2020 ◽  
Vol 75 ◽  
pp. 39
Author(s):  
Eric Flauraud ◽  
Didier Yu Ding
Keyword(s):  
Oil Recovery ◽  
Reservoir Simulation ◽  
Flow Model ◽  
New Technologies ◽  
Control Valve ◽  
Simulation Models ◽  
Control Device ◽  
Fully Implicit ◽  
Implicit Approach ◽  
Reservoir Simulator

In the last two decades, new technologies have been introduced to equip wells with intelligent completions such as Inflow Control Device (ICD) or Inflow Control Valve (ICV) in order to optimize the oil recovery by reducing the undesirable production of gas and water. To optimally define the locations of the packers and the characteristics of the valves, efficient reservoir simulation models are required. This paper is aimed at presenting the specific developments introduced in a multipurpose industrial reservoir simulator to simulate such wells equipped with intelligent completions taking into account the pressure drop and multiphase flow. An explicit coupling or decoupling of a reservoir model and a well flow model with intelligent completion makes usually unstable and non-convergent results, and a fully implicit coupling is CPU time consuming and difficult to be implemented. This paper presents therefore a semi-implicit approach, which links on one side to the reservoir simulation model and on the other side to the well flow model, to integrate ICD and ICV.

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