Summary
In recent years, gas exploration and production (E&P) companies have
acknowledged that pressure boosting in close proximity to a reservoir can
accelerate production rates as well as increase the recovery of reserves beyond
that possible by conventional central compression alone. This paper
summarizes the key well and reservoir parameters that determine the production
enhancement potential of downhole gas compression (DGC).
An industry-funded joint industry project (JIP) has been established to
complete the development of this key enabling technology. Detailed design is
well under way, with the objective of completing a field trial in 2007. A
summary of progress to date on this project is included in this paper.
Introduction
As reported previously (Liley and Verbeek 2004), a feasible concept for
downhole gas compression (DGC) exists, that when fully developed, will add a
new gas production enhancement tool and leverage greater value from existing
gas assets. Having established technical and economic feasibility based
on a number of specific field studies, this paper sets out the key drivers that
determine the potential incremental production from DGC. With reference
to these drivers, operators may better identify well candidates for more
detailed appraisal.
DGC applies specifically to wet or dry gas fields where the tubing
performance is friction-dominated and where the reservoir is of average or
better deliverability. It has the potential to stabilize the wellbore
flow regime, increase wellbore tubing transport capacity, stimulate reservoir
inflow by increased drawdown, and lower the abandonment pressure.
From the reference cases studied, potential incremental production rate
improvements of over 40% have been predicted.
Parametric Study
To establish the key performance drivers, a parametric study has been
completed, the objectives of which were to establish the key parameters that
determine the production benefit of DGC, and to present these in such a way as
to enable operators to identify the best candidate wells and reservoirs for
this type of artificial lift.
To conduct the study, a model was created using Prosper and OpenServer from
Petroleum Experts’ Integrated Production Management (IPM) software suite, to
simulate well performance with and without DGC to determine its effects and
benefits. To isolate the key variables, a well and reservoir reference
case was built, with sensitivities run on selected parameters. The
Petex-2 flow correlation was used throughout, as it has been found to represent
the flow behavior accurately for a number of gas wells of the flow, pressure,
and liquid rates where DGC may find application. This was established by
comparison with well test data. The selection of this correlation is
relatively arbitrary, as the study is looking for trends rather than absolute
values.
© 2007. Society of Petroleum Engineers
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History
- Original manuscript received:
20 July 2005
- Revised manuscript received:
20 May 2006
- Manuscript approved:
22 July 2006
- Version of record:
20 May 2007
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