Reservoir Engineering I
How much oil and gas a reservoir holds, how it is driven and how fast it can be produced: volumetric estimates with Monte Carlo ranges, PVT and rock properties for reservoir work, the general material balance and the Havlena-Odeh method, solution-gas, gas-cap and water drive with aquifer models, the gas p/z method, steady, transient and pseudosteady radial flow, Buckley-Leverett displacement, and Arps decline curves, applied in a reservoir study of an Alberta Cardium pool.
PET-320 Year 3 3 credits 12 lessons · 3 h 48 min ▶ Video lessons coming soon
Offered by HSM University · Petroleum Engineering
This is the Canadian version of this course. See the American version.
What you'll learn
- Describe the work of a reservoir engineer, classify reservoir fluids from field data and the phase envelope, and locate the free water level from pressure gradients.
- Estimate oil and gas in place volumetrically, express the uncertainty with scenarios and Monte Carlo simulation as P90, P50 and P10, and relate them to reserves categories.
- Build and check black-oil PVT tables of Bo, Rs, Bg, Bt and viscosity from laboratory data or correlations, and use consistent units.
- Select and average the rock properties used in reservoir calculations, including pore and effective compressibility, permeability, saturation endpoints, relative permeability and mobility ratio.
- Derive and apply the general material balance equation, and use the Havlena-Odeh method to estimate oil in place and diagnose drive energy.
- Explain solution-gas and gas-cap drive, forecast solution-gas drive performance with Muskat's method, and calculate drive indices.
- Recognize water drive, apply pot, steady-state and unsteady-state aquifer models, and size an aquifer by matching pressure history.
- Estimate gas in place and recoverable gas with the p/z method, and recognize the effects of water influx and overpressure.
- Apply Darcy's law to steady-state radial flow, calculate rates, productivity index and skin, and explain why tight rock needs fractured horizontal wells.
- Use the diffusivity equation and its line-source and pseudosteady-state solutions, the radius of investigation and superposition.
- Analyse immiscible displacement with fractional flow, Buckley-Leverett theory and Welge's method, and estimate waterflood recovery with sweep efficiencies.
- Fit Arps and modified hyperbolic decline curves, estimate ultimate recovery, and reconcile volumetric, material balance and decline estimates into a reservoir study recommendation.
Course content
12 lessons · 3 h 48 min total · final exam
- 1 The reservoir engineer's job and reservoir types 22 min · quiz
- 2 Volumetric estimates of oil and gas in place 19 min · quiz
- 3 Fluid properties for reservoir engineering 19 min · quiz
- 4 Rock properties for reservoir engineering 19 min · quiz
- 5 The general material balance equation 19 min · quiz
- 6 Depletion drive and gas cap drive reservoirs 18 min · quiz
- 7 Water drive and aquifer models 19 min · quiz
- 8 Gas reservoir material balance 18 min · quiz
- 9 Darcy's law and steady-state radial flow 19 min · quiz
- 10 Transient and pseudosteady-state radial flow 19 min · quiz
- 11 Immiscible displacement and fractional flow 19 min · quiz
- 12 Decline curve analysis and the reservoir study 18 min · quiz
- E Final exam 20 questions
Requirements
Recommended background. You can start any course at any time.
Description
How much oil and gas a reservoir holds, how it is driven and how fast it can be produced: volumetric estimates with Monte Carlo ranges, PVT and rock properties for reservoir work, the general material balance and the Havlena-Odeh method, solution-gas, gas-cap and water drive with aquifer models, the gas p/z method, steady, transient and pseudosteady radial flow, Buckley-Leverett displacement, and Arps decline curves, applied in a reservoir study of an Alberta Cardium pool.
Part of the Engineering stream, typically taken in year 3.