Orientation Webcast
Approx. 1 hour virtual, instructorled webcast
This is Reservoir Engineering
Approx. 1 hour online learning activities
This skill module is an introduction to the blended version of the Applied Reservoir Engineering course.
You will learn:
 About the Principal Tasks of a Reservoir Engineer
 About the Principal Tools of a Reservoir Engineer
 How this course is organized to cover these topics
Reservoir Rock Properties
Approx. 9 hours online learning activities
You will learn:
 Different types of rocks
 Primary rock properties from a reservoir engineering point of view
 How rock properties are measured
 How rock property values are interpolated/extrapolated throughout the reservoir
Reservoir Rock Properties Fundamentals
Approx. 1.5 hours virtual, instructorled training
This module introduces the concepts or wettability, capillary pressure and relative permeability, and discusses how they are measured and modeled for reservoir behavior description.
You will learn how to:
 Describe the concept of fluid contacts
 Describe how saturations change when crossing contacts
 Describe wettability
 Describe interfacial tension
 Describe how residual oil saturation is controlled by the interplay of different forces
 Define capillary pressure
 Explain how capillary pressure is a combination of several related phenomena
 Describe how capillary pressure can be used to explain macroscopic reservoir phenomena
 Show how collecting capillary pressure data can actually save money
 Discuss the various choices available for measuring relative permeability in the laboratory
 Discuss the various choices available for measuring capillary pressure in the laboratory
 Discuss the various choices available for measuring capillary pressure in the laboratory
 Show how reservoir engineers model relative permeability and capillary pressure
 Describe how reservoir engineers define saturations
 Apply concepts discussed in the module to build relative permeability and capillary data datasets
Reservoir Fluid
Approx. 9 hours online learning activities
You will learn how to:
 Describe how fluids change in response to changes in pressure and temperature
 Define the engineering properties of reservoir fluids
 Describe the makeup of reservoir fluids
 Describe how fluids are sampled
 Describe how fluid properties are measured in the laboratory
Reservoir Fluid Fundamentals
Session 1  approx. 1.5 hours virtual, instructorled training
Session 2  approx. 1.5 hours virtual, instructorled training
Reservoir Fluid Fundamentals explores the calculation fluid properties such as formation volume factors, viscosities and densities for a wide range of fluids under reservoir conditions.
You will learn how to calculate fluid properties needed for:
 Volumetrics
 Material Balance
 Fluid Flow using Darcy’s Law
 Pressure Transient Analysis
 Rate Transient Analysis
 Fluid Displacement
 Many other types of analysis
Reservoir Flow Properties
Approx. 9 hours online learning activities
This module discusses the extensions and limitations of Darcy’s Law. This module also includes the application of Darcy’s Law to gas an oil and how the law can be applied to homogenize to calculate effective permeability.
You will learn how to:
 Explain the origin of Darcy’s law and how it evolved
 State the difference between gravity and the pressure gradients, and how they play a role in determining the rate of which fluid could flow in the porous medium
 Identify the differences between the equations of Linear versus radial flow when calculating the flow
 Explain how do heterogeneities affect the flow in porous medium, and how Darcy's law can be applied to homogenize to calculate effective permeability
 Differentiate between oil and gas flow
 Apply Darcy’s law to gas and oil
 Calculate the amount of fluid that is flowing when you have single cell phase vs single phase oil
 Describe the Importance of nonDarcy effect on well performance
 Apply Darcy's law when calculating the rate of the of oil and gas well
 Identify the differences between layers in parallel and layers in series
 Discuss the effective permeability of both layers in parallel and layers in series
 State limitations of Darcy’s law
 Assess the differences between gas and oil reservoirs
 Describe the effect of nonDarcy flow
Reservoir Flow Properties Fundamentals
Session 1  approx. 1.5 hours virtual, instructorled training
Session 2  approx. 1.5 hours virtual, instructorled training
This Reservoir Flow Properties Fundamentals Module covers multiple basic and advanced levels of topics. The topics include but are not limited to, Darcy’s law, Flow Regimes, Fractured Wells, and Heterogeneous systems and Skin factor. This module also includes an interactive virtual phase where the learner works with the instructor virtually to analyze and solve problems.
You will learn how to:
 Apply Darcy’s law for radial flows
 Differentiate between oil and gas flows
 Solve simple problems for radial flow across porous medium
 Define and calculate productivity index
 Predict the inflow performance relationship for oil and gas wells
 Calculate the flow rate under different flow regimes
 Understand why productivity index changes for transient flow
 Calculate the flow rates for both oil wells and gas wells
 Understand the difference between boundary pressure and average pressure
 Understand the application of both pseudoreal pressure and pressure squared methods for gas wells in calculating the rates
 Evaluate the end of transient and the beginning of pseudosteady state flows for circular as well as noncircular reservoirs
 Understand the importance of vertically fractured and horizontal wells
 Calculate the rates and productivity indices for vertically fractured and horizontal wells using the concept of effective well bore radius
 Understand different flow regimes encountered by vertically fractured and horizontal wells
 Evaluate efficacy of horizontal wells and compare the performance to vertically fractured wells
 Calculate the effective permeability for parallel layers
 Calculate the effective permeability for layers in series
 Evaluate the difference under linear and radial flows
 Calculate the value of skin factor using damaged zone permeability
 Evaluate the performance of a well in the presence of skin factor
 Evaluate the performance of the well with limited amount of production data
 Understand the conditions under which nonDarcy flow is important
 Evaluate the performance of gas wells in the presence of nonDarcy flow using both pressure squared and pseudopressure equations
 Understand the concept multirate test and why it is important
 Evaluate the oil well performance when the well is producing below bubble point
 nalyze and solve basic and advanced level problems
Reservoir Material Balance
Approx. 3 hours online learning activities
This module covers the basics of material balance. The topics included are drive mechanisms, principles of material balance, how to develop equations, and application of the material balance equation.
You will learn how to:

Describe the purpose of the material balance technique to estimate the initial hydrocarbons in place

Differentiate between volumetric analysis and material balance technique

State the basic principle of material balance analysis

Describe the principles behind material balance equation

Identify the data that is needed to apply the material balance equation and the uncertainties associated with collecting such data

Identify the purpose of the modified black oil model in material balance equation

State the assumptions involved in applying the material balance equation

Identify the limitations of material balance technique

Develop the material balance equations from the first principle

Identify and explain the different mechanisms influencing the production of hydrocarbons and how they are incorporated in the material balance equation

Understand the necessary equations to be used depending on the type of reservoir from which hydrocarbons produce

Develop appropriate equations for dry gas, wet gas, condensate, volatile oil and black oil reservoirs

Describe modifications of material balance equations to estimate the initial oil and gas in place

Explain the Havlena and Odeh method and the appropriate way to linearize the material balance equations

Express the importance of water influx and how to detect the presence of aquifer based on production data

Recognize the uncertainties associated with predicting the water influx as a function of time
Reservoir Material Balance Fundamentals
Session 1  approx. 1.5 hours virtual, instructorled training
Online learning  approx. 4 hours of online learning activities
Session 2  approx. 1.5 hours virtual, instructorled training
You will learn how to:
 Calculate volumetric estimates
 Adjust volumetric estimates for transition zones and calculate recovery factors
 Perform material balance analysis
 Leverage straightline expressions of material balance equations to analyze gas reservoirs
 Leverage straightline expressions of material balance equations to analyze oil reservoirs
Decline Curve Analysis and Empirical Approaches
Approx. 11 hours online learning activities
This module introduces the use of statistical methods in reservoir engineering. A range of applications are described, concentrating on decline curve analysis.
You will learn how to:
 Perform Basic Statistics
 Calculate Decline Curve Analysis
 Estimate Recovery Factors
Decline Curve Analysis and Empirical Approaches Fundamentals
Session 1  approx. 1 hour virtual, instructorled training
Session 2  approx. 1 hour virtual, instructorled training
This module describes the application statistical methods to solve reservoir engineering challenges. The emphasis will be on decline curve analysis and curve fitting measured data such as relative permeability.
Reserves and Resources
Approx. 6 hours online learning activities
This module brings your attention to reserves management and the difference between resources and reserves at a core competency level.
You will learn:
 The importance of integration with other disciplines
 Calculations using the volumetric formulas for gas and oil
 The importance of dividing into flow units for dynamic reserves in reservoir simulation
 Reserves management: what it is and how to do it
 The Reservoir Engineer’s input to reserves and resources (R & R)
 How a Geoscientist and Reservoir Engineer work together on reserves
 The risk and uncertainty that drive reserves
 Other nontechnical factors that influence R & R
 The standardized process between reserve estimates
 The ethical basis underlying R & R estimations
Pressure Transient Analysis
Approx. 4 hours online learning activities
This module brings your attention to pressure transient analysis concepts, equations, and terminology. These will get you started in the process of understanding and using this key technology for understanding oil and gas reservoir architecture and nearwell parameters.
You will learn:
 Pressure transient analysis concepts, terminology, equations and objectives
 Pressure transient analysis in buildup and drawdown tests
 Time period analysis  challenges and objectives
 Semilog and loglog analysis
Rate Transient Analysis
Approx. 4 hours online learning activities
You will learn how to:
 Describe the relationship between 'rate transient analysis' and 'pressure transient analysis'
 Describe the situations under which rate transient analysis would be preferred to pressure transient analysis
Reservoir Fluid Displacement
Approx. 3 hours online learning activities
This covers immiscible, linear displacement, as dispersed and segregated flow. It also discusses aquifers, coning, and vertical layering.
You will learn:
 About immiscible fluid displacement linearly and vertically
 About dispersed and segregated flow
 About aquifer models
 Coning in oil/water systems, including when it is most likely to occur, and how to prevent it
Reservoir Fluid Displacement Fundamentals
Session 1  approx. 2 hours virtual, instructorled training
Online learning  approx. 7 hours of online learning activities
You will learn how to:
 Model aquifers using analytical expressions
 Calculate mobility ratios, heterogeneity indices and sweep efficiencies
 Calculate the movement of flood fronts through the reservoir
 Plot saturation vs. distance plots
 Calculate how concentrations change spatially
Enhanced Oil Recovery
Approx. 4 hours online learning activities
You will learn how to:
 Discusses the modification of rock and fluid properties in tertiary recovery
 Describes (at a high level) the range of secondary and tertiary recovery techniques currently available (and relates them back to rock & fluid properties)
Improved Oil Recovery Fundamentals
Session 1  approx. 2 hours virtual, instructorled training
Online learning  approx. 4 hours of online learning activities
You will learn:
Waterflood types:
 Pattern vs. peripheral
 Above vs. below bubble point pressure
 Above vs. below fracture pressure
 High vs. low reserves to producing ratios
 Normal vs. enhanced
 Onshore vs. offshore
Waterflood operations:
 Modeling the reservoir
 Monitoring injectors
 Monitoring patterns
 Water quality
Reservoir Simulation
Approx. 4 hours online learning activities
You will learn how to:
 Describe the physical basis, use and limitations of reservoir simulation models
 Describe the kind of data required to perform a simulation study
 Describe the issues and requirements for making rate and recoverable predictions for unconventional reservoirs with simulation tools (UC)
 Describe the issues and requirements for making rate and recoverable predictions for heavyoil reservoirs with simulation tools (HO)
Reservoir Surveillance
Approx. 4 hours online learning activities
You will learn:
 How surveillance plan objectives must be aligned with asset specific tactical details
 How surveillance activities must add value and how they do not after reaching a certain optimum
 How to calculate the Value of Information derived from surveillance activities
 How surveillance activities reduce uncertainty
 How surveillance plan must change constantly as asset objectives change
 The impact of the production and well environment, including well construction concepts and how this impacts Reservoir Surveillance activities
 How production allocation impacts the quality of the data and the impact of data frequency
 Measurement principles behind oil field measurements, including concepts related to precision, accuracy, and repeatability
 Collect data that adds value to an asset
Reservoir Surveillance Fundamentals
Session 1  approx. 1.5 hours virtual, instructorled training
Online learning  approx. 6 hours of online learning activities
Session 2  approx. 1.5 hours virtual, instructorled training
You will learn how to:
 Calculate the value of a particular type of data to your asset
 Calculate how the value of a particular type of data varies with the frequency of collection and the quality of the measurement
 Use the analysis of measurement data to identify reservoir and well problems
 Apply data integration methods, such as montages
 Integrate surveillance data with forecasting methods.
Reservoir Management
Approx. 6 hours online learning activities
You will learn how to:
 Retain flexibility in reservoir management without giving up key principles for depletion
 Build flow units critical to asset reservoir management
 Describe the value of an asset and the roles, risk, and uncertainty of that valuation
 Explain the roles of risk and uncertainty in that valuation
 Evaluate vertical equilibrium and nocrossflow, and how to get the most out of each through integrated technologies from multiple disciplines
Reservoir Management Fundamentals
Session 1  approx. 1.5 hours virtual, instructorled training
Online learning  approx. 3 hours of online learning activities
Session 2  approx. 1.5 hours virtual, instructorled training
You will learn how to:
 Manage reservoir uncertainties throughout phases of field maturity
 Identify the geologic and reservoir parameters that make an opportunity, and the capture techniques to the particularities of that opportunity
 Conduct analysis to determine the most appropriate injectant, including EOR techniques (if any) for a particular reservoir situation
 Apply the appropriate well architecture(s) or combination of well architectures to match the combined geology and reservoir drive mechanism
 Adjust and adapt the reservoir management plan for each new phase of field life