Overview of Reservoir Simulation by Prem Dayal Saini
Reservoir simulation is the study of how fluids flow in a hydrocarbon reservoir when put under production conditions. The purpose is usually to predict the behavior of a reservoir to different production scenarios, or to increase the understanding of its geological properties by comparing known behavior to a simulation using different geological representations.
The efficiency of enhanced oil recovery method is a measure of the ability to provide greater hydrocarbon recovery than by natural depletion, at an economically attractive production rate.
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The efficiency of enhanced oil recovery method is a measure of the ability to provide greater hydrocarbon recovery than by natural depletion, at an economically attractive production rate.
Facebook Page: https://www.facebook.com/petroleumengineeringz
Blogspot: http://petroleumengineeringsociety.blogspot.com/
Selection of the best artificial lift systems for the well depend on location, depth, estimated production, reservoir properties, and many other factors. Here is an overview on selection criteria for the best results
The problem of water and gas coning has plagued the petroleum industry for decades. Water or gas encroachment in oil zone and thus simultaneous production of oil & water or oil & gas is a major technical, environmental and economic problems associated with oil and gas production. This can limit the productive life of the oil and gas wells and can cause severe problems including corrosion of tubulars, fine migration, hydrostatic loading etc. The environmental impact of handling, treating and disposing of the produced water can seriously affect the economics of the production. Commonly, the reservoirs have an aquifer beneath the zone of hydrocarbon. While producing from oil zone, there develops a low pressure zone as a result of which the water zone starts coning upwards and gas zone cones down towards the production perforation in oil zone and thus reducing the oil production. Pressure enhanced capillary transition zone enlargement around the wellbore is responsible for the concurrent production. This also results in the loss of water drive and gas drive to a certain extent.
Numerous technologies have been developed to control unwanted water and gas coning. In order to design an effective strategy to control the coning of oil or gas, it is important to understand the mechanism of coning of oil and gas in reservoirs by developing a model of it. Non-Darcy flow effect (NDFE), vertical permeability, aquifer size, density of well perforation, and flow behind casing increase water coning/inflow to wells in homogeneous gas reservoirs with bottom water are important factors to consider. There are several methods to slow down coning of water and/or gas such as producing at a certain critical rate, polymer injection, Downhole Water Sink (DWS) technology etc.
Shubham Saxena
B.Tech. petroleum Engineering
IIT (ISM) Dhanbad
calculating reservoir pressure, knowing Depth of gas-oil. oil water interface, GOC AND WOC, numeric method to calculate interface. importance of isobaric maps in estimating reservoir pressure.
Selection of the best artificial lift systems for the well depend on location, depth, estimated production, reservoir properties, and many other factors. Here is an overview on selection criteria for the best results
The problem of water and gas coning has plagued the petroleum industry for decades. Water or gas encroachment in oil zone and thus simultaneous production of oil & water or oil & gas is a major technical, environmental and economic problems associated with oil and gas production. This can limit the productive life of the oil and gas wells and can cause severe problems including corrosion of tubulars, fine migration, hydrostatic loading etc. The environmental impact of handling, treating and disposing of the produced water can seriously affect the economics of the production. Commonly, the reservoirs have an aquifer beneath the zone of hydrocarbon. While producing from oil zone, there develops a low pressure zone as a result of which the water zone starts coning upwards and gas zone cones down towards the production perforation in oil zone and thus reducing the oil production. Pressure enhanced capillary transition zone enlargement around the wellbore is responsible for the concurrent production. This also results in the loss of water drive and gas drive to a certain extent.
Numerous technologies have been developed to control unwanted water and gas coning. In order to design an effective strategy to control the coning of oil or gas, it is important to understand the mechanism of coning of oil and gas in reservoirs by developing a model of it. Non-Darcy flow effect (NDFE), vertical permeability, aquifer size, density of well perforation, and flow behind casing increase water coning/inflow to wells in homogeneous gas reservoirs with bottom water are important factors to consider. There are several methods to slow down coning of water and/or gas such as producing at a certain critical rate, polymer injection, Downhole Water Sink (DWS) technology etc.
Shubham Saxena
B.Tech. petroleum Engineering
IIT (ISM) Dhanbad
calculating reservoir pressure, knowing Depth of gas-oil. oil water interface, GOC AND WOC, numeric method to calculate interface. importance of isobaric maps in estimating reservoir pressure.
Pumping Tests are conducted to examine the aquifer response, under controlled conditions, to the abstraction of water. Hydrogeologists determine the hydraulic characteristics of water-bearing formations, by conducting pumping tests. A pumping test is a practical, reliable method of estimating well performance, well yield, the zone of influence of the well and aquifer characteristics. There is a procedure for conducting pumping tests in wells. This lesson highlights the prevailing methods adopted while conducting pumping tests.
New Approach to Design Capillary Pressure Curves, which Would Improve Simulat...Faisal Al-Jenaibi
This presentation is discussing New Approach to Design Capillary Pressure Curves, which Would Improve Simulation Models Initialization and shorten History Match time consumed.
ResAssure - The World’s Fastest Reservoir Simulator | A Revolution in Reserve...Stochastic Simulation
This Presentation Will:
1. Introduce a new way of evaluating reservoir uncertainty with RESASSURE
2. Illustrate the concepts used
3. Highlight the benefits achieved
4. Demonstrate the value of the results
Stochastic Simulation has unleashed the world’s fastest reservoir simulator, ResAssure, which is set to revolutionize production planning and reserves reporting in the Oil & Gas industry.
ResAssure easily computes > 1 Million realisations within a 24 hour period, a fraction of the time it currently takes with traditional methods and software packages. The release of ResAssure marks a significant milestone in the history of reservoir simulation – the first real industry technology advance in 30 years.
Dr Wadsley, Chief Technology Officer at Stochastic Simulation, commented “ResAssure is capable of quickly generating more accurate reserve estimates than is currently possible by any other software system. The approach taken generates a complete distribution of history matched models all of which are consistent with the geological model and observed production history. The time taken for this is orders of magnitude faster than current history matching methods.”
“Field development planning based on ResAssure’s distribution of models (rather than just upon a single history-matched model using conventional methodologies) will significantly reduce uncertainty and risk.” he added.
By enabling faster and more accurate analysis of dynamic subsurface geological data than has previously been possible, ResAssure markedly reduces the risk in the development of oil and gas fields by narrowing the range of uncertainty in reserves estimates: thereby supporting better production and financing decisions, with substantial increases in project ROI.
ResAssure’s innovation in reservoir simulation solves fully-implicit, dynamic three-phase fluid flow equations for every geological realisation. The speed breakthrough was achieved by a combination of proprietary algorithms, polygonal gridding and aggressive spatial coarsening and time stepping, based upon a conventional finite-difference discretization of the reservoir.
Key Insights Identified:
1. Consistency between volumetric, material balance and fractional flow places very strong constraints on feasible reservoir models.
2. The mathematics of reservoir simulation is NOT complex – it is the geology which is complex.
3. Reserves uncertainty is not quantified, but estimated from current ‘best’ estimate in an ad hoc unsystematic way.
4. What’s the point of preserving mass balance in the simulator when the hydrocarbons in the reservoir are imprecise and we don’t include all production data – mass balance should act to regularise our solution, not to define it.
5. The role of reservoir simulation is not to compute an exact solution of a poorly defined geological model – it is to define a range of feasible reservoir models and associated production forecasts.
A numerical model is a system of mathematical equations that depict the functioning of the system and its variables. A useful model must identify the factors that can influence the course of a particular decision and shows the impacts. A good model becomes a tool for decision making and predictions. A model helps in simulating the system for finding out some solutions . To simulate something physical, you will first need to create a mathematical model which represents that physical object. Models can take many forms including declarative, functional, constraint, spatial or multimodel.
Cost (& Time) Optimization of Hydrogeological StudiesGidahatari Agua
Cost optimization has to identify the most common problems to the hydrogeological investigation as travel time and transport issues, seasonal restrictions, personal availability, protocols, etc. This post is focused on strategies and best practices for cost (& time) optimization, specially for hydrogeological investigation on mining projects.
This presentation by Morris Kleiner (University of Minnesota), was made during the discussion “Competition and Regulation in Professions and Occupations” held at the Working Party No. 2 on Competition and Regulation on 10 June 2024. More papers and presentations on the topic can be found out at oe.cd/crps.
This presentation was uploaded with the author’s consent.
Acorn Recovery: Restore IT infra within minutesIP ServerOne
Introducing Acorn Recovery as a Service, a simple, fast, and secure managed disaster recovery (DRaaS) by IP ServerOne. A DR solution that helps restore your IT infra within minutes.
Sharpen existing tools or get a new toolbox? Contemporary cluster initiatives...Orkestra
UIIN Conference, Madrid, 27-29 May 2024
James Wilson, Orkestra and Deusto Business School
Emily Wise, Lund University
Madeline Smith, The Glasgow School of Art
0x01 - Newton's Third Law: Static vs. Dynamic AbusersOWASP Beja
f you offer a service on the web, odds are that someone will abuse it. Be it an API, a SaaS, a PaaS, or even a static website, someone somewhere will try to figure out a way to use it to their own needs. In this talk we'll compare measures that are effective against static attackers and how to battle a dynamic attacker who adapts to your counter-measures.
About the Speaker
===============
Diogo Sousa, Engineering Manager @ Canonical
An opinionated individual with an interest in cryptography and its intersection with secure software development.
Have you ever wondered how search works while visiting an e-commerce site, internal website, or searching through other types of online resources? Look no further than this informative session on the ways that taxonomies help end-users navigate the internet! Hear from taxonomists and other information professionals who have first-hand experience creating and working with taxonomies that aid in navigation, search, and discovery across a range of disciplines.
2. 2
What is a Petroleum Reservoir?
• A petroleum reservoir or an oil and gas reservoir (or system), is a subsurface
pool of hydrocarbons contained in porous rock formations. The naturally
occurring hydrocarbons are trapped by overlying rock formations with lower
permeability.
3. 3
What is Reservoir Simulation?
• Reservoir simulation is the study of how fluids flow in a hydrocarbon reservoir
when put under production conditions. The purpose is usually to predict the
behavior of a reservoir to different production scenarios, or to increase the
understanding of its geological properties by comparing known behavior to a
simulation using different geological representations.
• Reservoir simulator is a tool for predicting hydrocarbon reservoir performance
under various operating strategies developed by combining physics,
mathematics, reservoir engineering, and computer programming.
• Simulator + Simulation Engineer + Reservoir description
4. 4
Why Do We Need Reservoir Simulation?
• What is the most efficient well spacing?
• What are the optimum production strategies?
• Where are the external boundaries located?
• What are the intrinsic reservoir properties?
• What is the predominant recovery mechanism?
• What and how should we employ infill drilling?
• When and which improved recovery technique should we implement?
5. 5
Simulation Approaches
• The analytical approach:
Involves a great deal of assumptions-in essence, it renders an exact
solution to an approximate problem (not used much).
• The numerical approach:
Attempts to solve the more realistic problem with less stringent
assumptions-in other words, it provides an approximate solution to an
exact problem.
• The domain of interest :
Focus on a single well, entire field or a section of the reservoir
6. 6
Reservoir Simulators
Simulators are the combination of :
1. Flow equations i.e. Mathematical model
2. Algorithms for solving the flow equations (rock and fluid properties)
3. Computer program commands
7. 7
Steps of a Simulation Study
• Setting objectives
-Fact-finding, Optimization
• Selecting the model and approach
-Reservoir complexity
-fluid type
-Scope of the study
• Gathering, collecting and preparing the input data
• Planning the computer runs, in terms of history matching and/or
performance prediction
• Analyzing, interpreting and reporting the results
9. 9
Steps of a Simulation Study…
• Setting objectives:
-Fact-finding - History matching (eg. Well test data to find the damaged zone)
-Optimization
10. 10
Overview of how to set up a Simulation case in
Petrel using Eclipse Simulators
1. Build a grid and populate it with properties.
2. (Optionally) scale up the structure and properties onto a coarser grid.
3. Define or import well paths.
4. Define or import well completion events.
5. (Optionally) import historical production rates.
6. (Optionally) define a well segmentation set.
7. Define a fluid model, describing the properties of the reservoir fluids at varying
pressures, volumes and temperatures (PVT) and the initial conditions (pressures and
contacts) in the reservoir.
8. Define a saturation function, describing the relative permeability and capillary pressure
of the fluids as a function of saturation.
9. Define a rock compaction function, describing how the rock expands and compresses
with changing pressure.
10. Define aquifers, describing the type, size and connections of the acting
11. Define a development strategy to control how the wells will produce and inject.
12. Define a simulation case, putting all the above data objects together.
13. Analyze and view the results using the Function window and the Results pane.
11. 11
Physical principles
• Conservation of Mass
The first principle is modeled by a so called partial differential equation that says
that if there is a difference between flow into and out of a tiny volume of space,
this will either cause a build-up or a draw down of mass in this tiny volume.
• Conservation of Momentum
The second principle is approximated by an experimental law, called Darcy's law,
that relate the pressure difference (force) across a porous rock containing a fluid
and the resulting velocity (momentum) of this fluid. This experimental law is also
represented by a partial differential equation that is combined with the equation
based on the first principle to form a set of partial differential equations that is the
mathematical description of the flow of fluids through a porous media.
• Conservation of Energy
The third principle is approximated by a relationship between Pressure, Volume
and Temperature (PVT) for the rock and the fluids. The PVT data is represented
by a set of tables for each reservoir.
12. 12
Upscaling
• Build a grid and populate it with properties.
• Scale up the structure and properties onto a coarser grid.
-Upscaling is the process of creating a coarser (lower resolution) grid based
on the geological grid which is more appropriate for simulation
15. 15
Well Design
Define or import well paths.
-The Well path design process is a tool which enables users to generate well
trajectories based on reservoir properties, seismic attributes or any other
data
16. 16
Well Completion Design
• Define or import well completion events
-Well completion consists of sealing off a drilled well in preparation for production.
1. Casing
2. Liner
3. Tubing
4. Packer
5. Perforation
17. 17
Well Segmentation
• Define a well segmentation set
-Conventional well models treat the entire wellbore as a single entity, averaging
all the fluid properties in the well bore.
-Well segmentation divides the wellbore into segments, much like the reservoir is
divided up into grid-cells.
18. 18
Making a fluid model
• Define a fluid model, describing the properties of the reservoir fluids at varying
pressures, volumes and temperatures (PVT) and the initial conditions (pressures
and contacts) in the reservoir.
• Black oil fluid models are defined by specifying several properties such as
viscosity, density and volume formation factors for each of the fluid phases
24. 24
Making rock physics functions
• Define a saturation function, describing the relative permeability and
capillary pressure of the fluids as a function of saturation.
• Saturation functions
– are tables showing relative permeability and capillary pressure versus
saturation.
-gas-oil and water-oil capillary pressure versus saturation
Define a rock compaction function, describing how the rock expands and
compresses with changing pressure
Rock compaction functions are tables showing pore volume multipliers versus
pressure, or a single rock compressibility value used by the simulator to calculate
the pore volume change.
27. 27
Make aquifer
• Define aquifers, describing the type, size and connections of the acting aquifer.
• Aquifer modeling is a method of simulating large amounts of water (or gas)
connected to the reservoir whereby it is not essential to know how the fluid
moves in it, but rather how it affects our reservoir.
28. 28
Development Strategies
• Define a development strategy to control how the wells will produce and inject
• Development Strategies are used to describe to the simulator how a field will be
developed - that is, which wells will produce or inject, what rates and pressures
they will flow at, what operations will be carried out on the wells over time, and so
forth.
29. 29
Numerical Models: Time step selection
• Time is the "fourth dimension" in mathematical representations of flow dynamics
in porous media
• A typical simulation study may cover a number of years
• require subdividing this period into smaller time segments
• As time step size progressively increases, it is common for material balance
errors to appear
• Material balance Saturation and Pressure calculations flow rates
• Material balance checks help the engineer to determine the maximum time step
size that is admissable by the particular problem, and that can be tolerated by
the model we are using.
30. 30
Simulation case and Results
• Define a simulation case, putting all the above data objects together
• Analyze and view the results using the Function window and the Results
pane :
1. Summary Vectors
2. Properties
3. Streamlines
4. Simulation logs
31. 31
Streamline simulation
• For reservoirs where the movement of the fluids is mostly driven by
the potential field induced by producing wells:
1. Water flooding.
2. Highly heterogeneous reservoirs
• Streamline Calculation
• Streamline representation
Streamline method is the possibility it offers to do relatively quick simulations
on large geologically and architecturally complex models
33. 33
Reservoir Simulation and the Computational Environment
• Simple material balance calculations are now routinely performed on
desktop personal computers, while running a field-scale three-
dimensional compositional simulator may call for the use of a
supercomputer
• In designing a simulation study, we must always be aware of the
capabilities and limitations of our computing resources.
35. 35
History Matching, Prediction and Re-Simulating
• Analysis of results
• Updating or re-simulating
• Progressive evolution of the reservoir model
• Progressive assessment of the simulation approach
36. 36
Types of Eclipse Simulators
• ECLIPSE Blackoil
• It is a fully implicit, three-phase,three-dimensional, general-purpose black oil
• simulator.
• The Blackoil model assumes the reservoir fluids consist of reservoir oil, solvent
gas and water.
• ECLIPSE Compositional
• It is useful when the behavior of the hydrocarbons is complex—condensate or
volatile crude oil, or gas injection developments fall in this category.
37. 37
Types of Eclipse Simulators
• ECLIPSE Thermal
• Thermal recovery methods are typically used in heavy oil reservoirs where the oil
viscosity is high at reservoir temperatures, but reduces as the temperature
increases.
• ECLIPSE FrontSim
• It is a three-dimensional, three-phase streamline simulator.
38. 38
Special Purpose Reservoir Simulators
• Water Coning Simulators
• Dual Porosity/Permeability Simulators
• Thermal Recovery Simulators
• Compositional Simulators
• Miscible Displacement Simulators
• Chemical and Polymer Flooding Simulators
• Coalbed Reservoir Simulators