DEEP7 2017 - Subsea 7 - page 15

50 km for oil fields and 100 km for
gas fields) conventional flow assurance
methods to control hydrate and wax
prevention are no longer applicable, either
because technology reaches a limit (thermal
insulation thickness) or because the cost
of ancillaries (for example chemical
injection lines) prohibits resource
development.
Using the technologies profiled in this
article, field architecture is now possible that
enables production via very long-tie-backs,
typically over 50 km for oil-dominated
flowlines.
This enhanced subsea capability will allow
the future development of brown-field and
remote green-field reservoirs which have
previously been regarded as uneconomic
prospects using traditional platform-based
or vessel-based production facilities.
Olivier Lodeho started his engineering career in the
automotive and diesel engine industries before moving into
oil and gas R&D. His early projects with Subsea 7 involved
the design of pipe-laying equipment including friction clamps
and PLET handling systems. He now leads the Technology
Department in our Global Project Centre in Paris and the
Strategic Flowline Technology Development Program.
Sigbjørn Daasvatn started his offshore career as a diver
and field engineer before progressing to project engineering.
He also has extensive experience from various positions
in both onshore and offshore operations from an operator´s
perspective. He founded and managed a prefabricated
construction company before returning to offshore
engineering with Subsea 7, where he now leads the strategic
development of subsea processing from our Stavanger office.
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