Multiphase Flow in Pipes
Gas-liquid flow in wells and pipelines from first principles: single-phase friction, holdup and slip, horizontal and vertical flow patterns and their maps, the homogeneous model and the components of the pressure gradient, empirical correlations such as Beggs-Brill and Hagedorn-Brown, mechanistic and transient models, gathering line sizing under 49 CFR Parts 192 and 195, and flow assurance for hydrates, wax, asphaltenes, slugging, liquid loading, corrosion and sand, applied to a Bakken gathering system tie-in under PHMSA and North Dakota gathering pipeline rules.
PET-380 Year 3 3 credits 12 lessons · 3 h 52 min ▶ Video lessons coming soon
Offered by HSM University · Petroleum Engineering
This is the American version of this course. See the Canadian version.
What you'll learn
- Describe the elements of a production and gathering system from wellbore to battery, the phases it carries and the codes and regulators that govern it.
- Calculate single-phase pressure drop with the Darcy-Weisbach equation, Colebrook and Swamee-Jain friction factors and the gas flow equations used for pipelines.
- Define superficial and mixture velocities, no-slip fraction, holdup and slip, and calculate in-situ mixture density and liquid inventory.
- Identify the flow patterns of horizontal and inclined pipes, explain the mechanisms of their transitions and use flow pattern maps and the Beggs-Brill boundaries.
- Identify the flow patterns of vertical and deviated wells, apply the Duns-Ros and Taitel-Barnea-Dukler transitions and the drift-flux model.
- Separate the pressure gradient into gravity, friction and acceleration terms and march a homogeneous no-slip calculation along a well or pipeline.
- Apply empirical correlations such as Hagedorn-Brown and Beggs-Brill, compare them with field data using bias and scatter, and choose and tune a method.
- Explain the structure of mechanistic models, solve the two-fluid stratified balance and the slug unit balance, and describe when transient simulation is needed.
- Size a multiphase gathering line over its production profile, check erosional and minimum velocities, calculate design pressure from the governing code and describe network effects.
- Predict hydrate, wax and asphaltene risks, estimate inhibitor dosing with the Hammerschmidt equation and pipeline cooling with the relaxation length, and plan prevention and remediation.
- Assess slugging, liquid loading, internal corrosion and sand, size for pig slugs, apply the Turner criterion and estimate uninhibited CO₂ corrosion rates.
- Prepare a tie-in recommendation that integrates hydraulics, flow assurance, cost, regulation and operations, with an operating plan and sensitivities.
Course content
12 lessons · 3 h 52 min total · final exam
- 1 Multiphase flow in petroleum systems 20 min · quiz
- 2 Single-phase pipe flow review 19 min · quiz
- 3 Holdup, slip and mixture properties 19 min · quiz
- 4 Flow patterns in horizontal and inclined pipes 19 min · quiz
- 5 Flow patterns in vertical pipes 19 min · quiz
- 6 The homogeneous model and pressure gradient components 19 min · quiz
- 7 Empirical correlations 19 min · quiz
- 8 Mechanistic models 19 min · quiz
- 9 Pipeline and gathering system design 18 min · quiz
- 10 Flow assurance: hydrates, wax and asphaltenes 21 min · quiz
- 11 Flow assurance: slugging, liquid loading, corrosion and sand 20 min · quiz
- 12 Capstone: the Tamarack Lake gathering system tie-in 20 min · quiz
- E Final exam 20 questions
Requirements
Recommended background. You can start any course at any time.
Description
Gas-liquid flow in wells and pipelines from first principles: single-phase friction, holdup and slip, horizontal and vertical flow patterns and their maps, the homogeneous model and the components of the pressure gradient, empirical correlations such as Beggs-Brill and Hagedorn-Brown, mechanistic and transient models, gathering line sizing under 49 CFR Parts 192 and 195, and flow assurance for hydrates, wax, asphaltenes, slugging, liquid loading, corrosion and sand, applied to a Bakken gathering system tie-in under PHMSA and North Dakota gathering pipeline rules.
Part of the Engineering stream, typically taken in year 3.