1 / 11

Advanced Well Control

Advanced Well Control. NOIA 2019 Fall Meeting Wednesday, October 9, 9:30 a.m. – 10:30 a.m. Objective / Prize. Objective Evaluate two innovative technologies for well control – seawater injection and polymer plugs to reduce the risk of a blowout

reason
Download Presentation

Advanced Well Control

An Image/Link below is provided (as is) to download presentation Download Policy: Content on the Website is provided to you AS IS for your information and personal use and may not be sold / licensed / shared on other websites without getting consent from its author. Content is provided to you AS IS for your information and personal use only. Download presentation by click this link. While downloading, if for some reason you are not able to download a presentation, the publisher may have deleted the file from their server. During download, if you can't get a presentation, the file might be deleted by the publisher.

E N D

Presentation Transcript

  1. Advanced Well Control NOIA 2019 Fall Meeting Wednesday, October 9, 9:30 a.m. – 10:30 a.m.

  2. Objective / Prize Objective Evaluate two innovative technologies for well control – seawater injection and polymer plugs to reduce the risk of a blowout • Longer-term focus: Commercialize the technologies • Near-term focus: Test technical maturity Prize • Safety & environment protection

  3. Well-Control Bow Tie Well Hydrocarbon Release Subsurface evaluation and proper well design Drilling practices and oversight Drilling fluid and cement Competency / training BOP Polymers Polymers ROV Survey Capping stack Oil spill response Relief well Seawater Seawater Prevention Mitigation Benefit / Development Challenges Greater Smaller

  4. Polymer Plug Concept Technology Highlights • Surface or Subsea mounted finite volume fast set resin/catalyst injection (customized to secs) • Activated with or without riser attached • Kill well by injecting mud below plug

  5. Polymer Plug Concept • Current Status: • Demonstrated mechanical integrity for up to 20% mud contamination and piston loads of 15,000+ psi • Demonstrated reaction kinetics meets needs • Completed tests in a simulated BOP EXP-1778 tested specimen EXP-1778 untested specimen

  6. Polymer Plug Concept • Studied polymer plug formation in a simulated BOP • Kerosene used as surrogate for reservoir liquids also tested drilling mud and water • Scaled flow rates matched residence time of fluids in a BOP with a failed blind shear ram • 100 second matches a 10 k bbl/day release • 20 seconds matches a 50 k bbl/day release • Mud temps were 50°C Leak orifice 2/3 up BOP Polymer plug formed within the BOP and stopped the flow of drilling mud into Hopper 2 Simulated BOP leaking fluid Pilot System

  7. Seawater Injection concept Technology Highlights • Injection of high-rate seawater to create sufficient backpressure to allow bullheading of KWM • Possible use of cement/mud pumps if employed early • Dynamic balance of seawater and mud injection during final kill operation

  8. SWI: Initial Results • Current Status: Steady state and transient analysis suggest that rig equipment likely sufficient to handle leak if caught early. Frac pumps available for larger leaks. • Next phase: Erosion of blind shear ram (BSR), Model leaks in the wellbore Steady State Analysis (URC) Transient Analysis (Add Energy)

  9. Forward Plans • Complete notional designs for deepwater systems • Accumulator driven system • Battery driven system • Complete scale testing to determine minimum resin / catalyst volumes • Model seawater injection to control leaks in well bore • Promote Industry Interest • SPE ATCE 2017 paper describing polymer plugs (Paper 187318) • Submit peer-reviewed publications • Second phase feasibility of polymers plugs • Dynamic modeling of seawater injection • Establish Industry Participation • Form JIP to fund and mature concept • OOC agreed to promote and administer • Evaluating interest from industry / government

  10. Phase 3 Funding Levels • Core participant ($250K / year) – Steering committee voting • Associate participant ($100K / year) – non voting • Industry group core participant ($500K / year) • Industry group associate participant ($200K / year) • JIP Term: 1 year periods until terminated by steering committee

  11. Questions?

More Related