Explain why narrow pore-to-fracture pressure margins occur and how they constrain drilling.
Oil, Gas & Energy
Managed Pressure Drilling for Narrow Margins between Pore and Fracture Pressure
Covers managed pressure drilling methods, equipment and well control integration for drilling engineers working narrow pore-to-fracture pressure margins in challenging wells.
🗓️Duration5 training days
📚Content4 modules · 8 sessions
🎓On completionAccredited attendance certificate
About the programme
Course Overview
Some wells offer so little margin between pore pressure and fracture pressure that conventional drilling with a static mud weight cannot keep the well simultaneously stable and free of losses. This course explains managed pressure drilling as the response to that problem, starting with why narrow margins occur in depleted reservoirs, deepwater shallow sections and high-pressure high-temperature wells, and how constant bottomhole pressure, pressurised mud cap and dual gradient variants each address a different version of it. Participants examine the surface equipment that makes managed pressure drilling possible, including the rotating control device, automated choke manifold and backpressure pump, and the hydraulic modelling used to plan surface backpressure through each stage of the well. Sessions on well control integration cover how influx detection and response change under managed pressure compared with conventional well control, since early kick signs appear as backpressure changes rather than pit gain alone. The course closes on candidate selection and planning, so participants can assess whether a well justifies managed pressure drilling and prepare the equipment, procedures and crew competency a safe operation requires.
Expected Learning Outcomes
Distinguish constant bottomhole pressure, pressurised mud cap and dual gradient drilling methods.
Describe the function of the rotating control device, choke manifold and backpressure pump.
Build a hydraulic model to plan surface backpressure through each stage of an MPD well.
Recognise how influx detection and response differ under managed pressure from conventional drilling.
Assess whether a well is a suitable candidate for managed pressure drilling.
Plan equipment, procedures and crew competency for a managed pressure drilling operation.
Who Should Attend
Drilling engineers planning wells with narrow pore-to-fracture pressure margins.
Well control and drilling supervisors operating managed pressure drilling equipment.
Drilling contractors' rig crews assigned to managed pressure drilling operations.
Completion and workover engineers evaluating managed pressure techniques for their wells.
HSE and well engineering staff who assess managed pressure drilling risk and readiness.
Petroleum engineering graduates specialising in drilling engineering and well control.
Course Modules
Select any module to see its sessions and points.
01Managed Pressure Drilling Concepts and Variants
2 sessions · 8 points
Session 1Why Narrow Margins Demand a Different Approach
- Explain how depletion narrows the margin between pore pressure and fracture pressure over field life.
- Identify narrow-margin challenges typical of deepwater shallow sections and HPHT wells.
- Explain why a static mud weight cannot always keep a narrow-margin well stable and loss-free.
- Relate applied surface backpressure to an equivalent circulating density at the bit.
Session 2Constant Bottomhole Pressure, Dual Gradient and Mud Cap Methods
- Explain how constant bottomhole pressure drilling holds downhole pressure steady through connections.
- Describe how dual gradient drilling manages pressure using two effective mud gradients.
- Explain when pressurised mud cap drilling is used in place of conventional circulation.
- Compare the well conditions that favour each managed pressure drilling variant.
02MPD Equipment and Surface Systems
2 sessions · 8 points
Session 1The Rotating Control Device and Choke Manifold
- Explain the function of the rotating control device in closing the annulus around the drill string.
- Describe how an automated choke manifold maintains a target surface backpressure.
- Identify the pressure and flow instrumentation used to monitor an MPD surface system.
- Relate rotating control device element wear to maintenance and change-out planning.
Session 2Backpressure Pumps and Automated Control
- Explain how a backpressure pump maintains circulation during a connection or pipe movement.
- Describe how an automated MPD control system adjusts choke position to a pressure setpoint.
- Identify failure modes of MPD surface equipment and their well control consequences.
- Plan equipment redundancy appropriate to the criticality of an MPD operation.
03Hydraulics and Well Control Integration
2 sessions · 8 points
Session 1Hydraulic Modelling for MPD
- Model annular friction pressure to predict equivalent circulating density along the well.
- Plan a surface backpressure schedule for connections, tripping and circulating breaks.
- Predict the hydraulic effect of cuttings loading and rheology changes on bottomhole pressure.
- Update a hydraulic model using real-time pressure-while-drilling data.
Session 2Influx Detection and Handling under MPD
- Recognise early influx indications from flow-out and backpressure trends under MPD.
- Distinguish an influx response under managed pressure drilling from a conventional well control response.
- Apply a constant bottomhole pressure influx control method to circulate out a kick.
- Decide when an MPD influx response should transition to conventional well control.
04Candidate Selection and Operations Planning
2 sessions · 8 points
Session 1Screening Wells and Assessing Risk
- Screen a well against pore pressure, fracture pressure and hole condition criteria for MPD suitability.
- Assess the incremental risk and cost of managed pressure drilling against a conventional design.
- Identify the operational limits within which the chosen MPD variant remains effective.
- Present an MPD candidate recommendation with supporting technical justification.
Session 2Operational Planning, Contingency and Competency
- Develop contingency procedures for equipment failure or loss of surface backpressure control.
- Plan crew competency and training requirements specific to managed pressure drilling.
- Coordinate MPD equipment mobilisation and rig-up with a drilling contractor's schedule.
- Review lessons from a completed MPD operation to improve the next candidate selection.
What the participant receives
4 course modules
A structured syllabus
8 training sessions
across 5 days
32 detailed points
Applied, detailed content
Accredited attendance certificate
On completing the programme
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