New technologies: completion, HPHT & MPD

Course Content

• ADVANCED COMPLETION - Duration : 1 Day

  • Subsea smart completion: objectives, technology description and implantation.
  • Multilateral completion.
  • Single trip multizone gravel pack system: introduction, dual string and single string, BJ & Halliburton comparison, offshore wells operation BJ MST system key components.
  • Tubingless completion: objectives, tubingless well architecture and equipment innovation.
  • Would it make sense to add a word about WABs? Cementless expandable lower completion?

• HPHPT WELLS - Duration : 1.5 Days

  • HPHPT definitions:
  • API.
  • Other standards.
  • TotalEnergie.
  • PP/FP profiles: narrow mud windows notion, reservoirs (geomechanics and effect of depletion), pressure transition zone (PTZ).
  • Basic design engineering:
  • Casing design specific to HPHT (thermal simulations/introduction to limit-state and reliability based design/survival loads).
  • OCTG choice (material grade, SSC, qualification).
  • OCTG connector choice (test and qualification).
  • Well equipment (liner, wellheads, casing hangers…).
  • Subsea HPHT specificities (wellhead fatigue, X-Mas tree choice, introduction to APB).
  • Annulus management systems (N₂ cushion, burst discs, crushable foams…).
  • Well architecture specificities of HPHT well. Real case presentation.
  • Advanced HPHT well engineering:
  • Casing wear (modeling, measurement, remedial).
  • Wellhead growth (modeling and impacts, heat island effect).
  • Fluids and cement aspects of HT environments (mud weight reference at 50°C).
  • Kick tolerance modeling (dispersed modeling w/drill bench or equivalent, limitations of single bubble in HPHT).
  • Hydraulic modeling in HPHT operations.
  • Logging (current HT limitations on MWD tooling).
  • Infill drilling.
  • Operational preparation
  • Rig inspection program for HPHT operations.
  • Importance of bridging document/JDM between contractor and operator.
  • Equipment specific to HPHT (mud coolers, kick assembly, dart sub, MPD…).
  • Hydrates (formation mechanisms, prevention).
  • HPHT checklists (example supplied).
  • HPHT procedures (pit management and discipline, breaking circulation, connections, Horner plot flow checks, tripping procedures, pump out of hole or stripping if MPD).
  • Operational execution
  • ECD management.
  • Wellbore breathing (breathing vs. influx, loss-gain scenarios, supercharging mechanisms, fracture…).
  • Well control aspects.
  • LOT/FIT in HPHT.
  • Mud weight management.
  • Fingerprinting (dummy) connections, swab and surge, compressibility test, drain back/flow volume…).
  • Case studies (HPHT train wrecks, database analysis of exploration and development wells).

• MANAGED PRESSURE DRILLING - Duration : 2 Days

  • Introduction:
  • Definition (IADC), history and objectives.
  • Why using MPD?
  • Surface back pressure (SBP) introduction.
  • Main components and layout:
  • Rotating control device (RCD).
  • Choke manifold including Coriolis mass flow meter (example of real layout).
  • Drill pipe non return valves.
  • MPD operations with RCD:
  • Drilling: difficulties to differentiate “well breathing-supercharge” and an “influx”; management of the surface back-pressure (manual, SBP mode, APC mode, “C” mode); use of PWD; kick detection (EKD, virtual trip tank); limitations and risks, well control matrix.
  • Tripping/stripping: POOH (adjusting SBP); temperature effect mud weight (static and dynamic temperatures), mitigation; mud cap, why and when, risks and limits; RIH; procedure example.
  • Dynamic fit/lot: principles, dynamic FIT with PWD, dynamic LOT with PWD and Coriolis flow meter, real time SBP setting.
  • Dynamic pore pressure (pp) assessment: principle, SBP and AFL, MW adjustment for drilling and tripping/stripping.
  • Casing RIH and cementing: case study.
  • Conclusion:
  • Advantages of MPD.
  • Risks and limitations.

• Knowledge assessment