9: 30 A.M. – 10: 30 A.M. COFFEE BREAK – Exhibit Hall
10: 30 A.M. – 12:00 P.M. SESSION 1 - FLOW ASSURANCE / Moody Ballroom
Chair: Antonio Critsinelis, Pipelines & Installation Engineering Team Manager
Co-Chairs: Bob Carter, President; Vaela Resources
Chuck Horn, Sr. Advisor; NanoRidge Materials, Inc.
Methanol Injection in Subsea Systems
Fouad Fleyfel, FA Subject Matter Expert; Shell
Methanol is currently used to treat a tree/jumper and wellbore prior to well start up and at shutdown to prevent hydrate formation,
in this example. Data collated over the years confirmed that the well could stay for about 2 -3 days without treatment with methanol
after shutdown. Though during shutdown, the fluid temperature was in the hydrate zone, no plug was observed during restart of the
wells. The explanation for this phenomenon was that there is segregation of the gas, oil, and water phases that prevent a full growth of
hydrate plugs. It is found that methanol is only critical just prior to startup than at the beginning of shutdown. This results in significant
reduction in methanol consumption should the no –touch time be extended (period of no well treatment with methanol or blowdown/
dead oil of the flowline after shutdown) from 3hrs to 24hrs. A field test with a production well was conducted to further validate the
theory in 2015. The well was shut-in for 36hrs with the tree, jumper, and wellbore not treated with methanol. The well was restarted with
methanol and there was no evidence of hydrate restriction or a plug. To ensure no agitation of fluid in the jumper for a shut-in well that
is hooked up to a live flowline, it is required that the well selector valves be in closed position to ensure no live fluid ingress into the
well jumper. This presentation will discuss the results of the field test.
Dr. Fleyfel has 27 years of experience in the upstream production business, particularly in flow assurance and subsea systems. His
experience extends from R&D, to project delivery and operation support. He is currently the FA Subject Matter Expert for Shell
Technologies for Maintaining Blockage-free Tiebacks
Melissa Gould, Principal; Stress Engineering Services, Inc.
As the length of flowline tiebacks increase, there is greater interest in single flowlines vs. the dual, “looped” flowline approach. The
presentation will address historical GoM blockage data and highlight key existing technologies that can be employed to provide
hydrate and paraffin management. The presentation will also address some of the emerging technologies and technology gaps that
Melissa Gould has worked as a subsea pipeline engineer for over 26 years and is a Principal at Stress Engineering Services, where
she has worked for the past 14 years. She currently leads the subsea pipeline, equipment and controls group in Stress Engineering’s
Upstream Practice. Melissa holds a Bachelor of Science degree in Maritime Systems Engineering from Texas A&M University and is a
registered Professional Engineer in the state of Texas.
Hurry Up & Wait: Executing Successful Hydrate Remediation Projects and Effective Mitigation of
Hydrate Formation in Subsea Flowlines
Bryan Arciero, Process Engineer; Murphy E&P Company - USA
This presentation will outline lessons learned from three separate hydrate remediation projects in subsea flowlines, including planning
and developing an effective execution strategy in order to minimize costs and production impacts. It also provides a basis for potential
improvements in subsea design for future projects.
Bryan Arciero is an engineer with over 10 years’ experience in the upstream oil and gas industry. He is responsible for flow assurance,
production chemistry and process engineering for Murphy’s Gulf of Mexico assets. Bryan is a registered professional engineer in Texas,
Canada, and the UK.