Arrow Bowen GAs Project - Arrow Energy

Arrow Bowen Gas Project EIS | Executive summary
Less preferred options are disposal to watercourses or to the
sea via an ocean outfall. These options address the situation
where there are no or insufficient beneficial uses or where
aquifers targeted for injection do not have the capacity to
accept the produced volumes of water. These options are still
being evaluated.
Arrow also expects to identify and evaluate further uses of
treated and untreated CSG water.
4.4.3 Management of Brine
The management strategy also includes options for the
treatment and disposal of brine, a by-product of water
treatment using reverse osmosis. The preferred management
option for brine is selective salt precipitation. This option allows
the beneficial use of the brine in the form of salt products,
which can be used in a variety of industrial processes. The main
products are salt (NaCl) and soda ash (NaCO 3 ). Arrow will
commission studies to understand the chemical composition
of the brine, methods for enhancing precipitation of the brine,
the chemical processes required to transform the brine into
commercial products, and the commercial viability of this in the
Bowen Basin.
Disposal of brine via an ocean outfall is a potential option for
some of Arrow’s areas of operation.
Another option is disposal to a suitably licensed landfill.
Investigations have confirmed that such facilities exist and it is
Arrow’s expectation that if commercial volumes of brine exist,
including as a consequence of other developments, then new
facilities might be developed to respond to demand.
Implementation of the above management options will,
depending on the options selected, require the development
of infrastructure including pipelines, water and/or brine pumping
stations, injection facilities and selective salt precipitation plants.
4.5 Power Supply
Power is required at the production wells and production
facilities. The facilities will consume electricity 24 hours a
day, 365 days a year, except for scheduled and unscheduled
maintenance shutdowns.
Power generation facilities will likely comprise a series of
high-efficiency, CSG-fired reciprocating engines with lean
burn technology, which will achieve high efficiency generation
(greater than 40%) with reduced emissions (low nitrogen
oxide combustion technology). Each engine will be coupled to
alternators generating directly at 11 kilovolts. Power generation
facilities will be located within or in close proximity to the
production facilities. An estimated 80 by 150 m footprint will
be required to accommodate a power generation facility. These
facilities will supply power for gas compression and water
treatment.
The number of electrical generators for each production facility
will be based on the facility load requirements, the size of each
generator and the required redundancy (normally expected
to be one engine). Power generation requirements will range
from a minimum of 2 MW for a FCF to a maximum of 60 MW
for an IPF. Other alternatives such as supply from the local
electrical network will be further explored.
Local gas powered electrical generators may be used to provide
power to the individual wellheads. In each case the generator
will supply power to drive the water pump and control
systems. Alternative solutions (such as distributing power
from the processing facilities to each individual wellhead via
overhead and/or underground lines) will also be investigated to
determine if there are practical, economic and environmentally
acceptable alternative solutions to the use of local generation
for each wellhead.
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