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Location
Title
Maps
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VWVulcan
is in the final phases of a comprehensive search of the
complex titles and rights that is one of the major challenges in development
of a large project such as this.
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The
link below goes to a page that will be updated regularly with current details
on the state of the title search.
Proximity to Gas Lines
Historic Overview
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Exploration conducted by BP in the mid 80's in the Nanaimo area.
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Over 500 cores drilled by coal owners seeking coal; all found gas, but no
measurements were properly taken.
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180 kilometers of 2D seismic data, some 3D available (BP and Hillsborough
seismic).
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Coal mines in this region have always had to vent gas to prevent explosions.
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B.C. Geological Survey has carried out an extensive evaluation of the
Vancouver Island coal resources and gas content analysis.
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Work was carried out in 1996 in the Tsable River area of the Comox Basin
(six wells drilled, gas content analysis).
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The Cedar, Yellow Point BP wells encountered Comox coals in Nanaimo Basin at
5,000 feet. One of the wells was plugged and abandoned as result of
excessive gas pressures.
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Survey results maintained by B.C. Geological Survey in Victoria, B.C. and
managed by Dr. Barry Ryan, Chief BC Coal Geologist.
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VWV has conducted an extensive geological analysis with the assistance of
Calgary-based geologist Gwyneth Cathyl-Bickford. She has extensive
knowledge and insight of Vancouver Island geology.
CBM Potential
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Coal rank is bituminous A & B.
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Geology, rank, and depth all favor CBM presence.
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Cumulative coal seam thickness is 23 feet.
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Gas content is 200 to 400 standard cubic feet per ton, most likely higher (PRB
coal’s gas content averages 30 SCF/ton).
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CBM values reported to date are from desorption tests, not sealed canister
tests, and therefore underestimate the CBM content.
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Quinsam and Tsable River lands may contain 0.5 TCF to 1.0 TCF of CBM gas,
very possibly more, at average depth of 1,000 feet.
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Drilling into deeper-lying coals (4,000 to 5,000 feet) may yield additional
CBM production (Yellow Point & Cedar BP wells).
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Approximately 80 BCF have been identified by VWV from existing Quinsam
Mine core holes.
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Estimated recoverable reserves 0.5 BCF/well, estimated life in excess of
fifteen years.
Test Phase
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Ten-well test drilling program to prove gas producing potential of the
Tsable River coals.
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180 km, 2D-seismic survey completed.
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Geologic and engineering assessment to determine:
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Isopachs and extent of major seams
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Faults and folds
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Coal bed reservoir (aquifer) water elevations
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Sorbed CBM values, SCF/ton of coal in place
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Permeability values of coals
Drilling
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If the initial test wells confirm production capacity, then: Drill, complete and set compression for 500-600 wells
Time to build-out: five to six years from first production well
Well depths from 800 to 3,000 feet, with an average depth of 1,600 feet
Well spacing: one well per 120 acres
Project development drilling to match gas demand
Drilling will be carried out by conventional water drilling rigs available
on Vancouver Island.
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The photograph at right (courtesy of the Bureau of Land Management, Buffalo,
Wyoming) shows a rotary/mud drilling rig. The project will use air drilling,
avoiding the mud pit and tailings pond.
Well Cross-Section
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After drilling, the casing is cemented in to prevent CBM from escaping from
the well or communicating with overlying aquifers.
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The tubing, tipped with a submersible electric water pump, is then inserted
to allow the water to flow from the bottom of the hole.
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CBM exits the well through the annulus formed by the casing and the tubing.
Trenches
A conventional trencher is used to prepare the trenches for gas lines and
water drainage lines.
Wellheads
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The well is fitted out with the required plumbing.
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The well pod is cleaned up and the wellhead protected by a fiberglass
enclosure. Electrical power to operate the pump is brought in and connected.
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In cold climates such as Calgary and Northern Wyoming, automatic wellhead
heaters are installed, fueled by the well’s CBM.
Gathering Pods
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The gathering lines meet at one of several pods, where the gas is metered
and routed into a header pipe for delivery to the compressors.
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The pod is shielded by a pre-fabricated enclosure which is color-coordinated
with the surroundings.
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Gas flow is monitored and recorded.
Gas Compression
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Gas flowing from the collection pods is delivered to a high-pressure
compression station or stations.
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Depending on the wellhead pressure, the CBM may be collect by a low-powered
screw compressor and passed on to an intermediate reciprocating compressor.
Production Phase
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On average, each well is anticipated to produce 150MCF of CBM per day.
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Anticipated peak daily gas production of 80 MMCF cubic feet.
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Through 2015, all wells expected to produce a total of 0.25 TCF of gas
– approximately a quarter to one half of the projected 0.5-1.0 TCF
recoverable CBM resource.
Water Production
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Initially, wells are anticipated to produce at a rate of 9 gallons of water
per minute (compared with a typical PRB well of 12 gallons per minute).
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Water production is anticipated to decline exponentially. This is a
characteristic found in most CBM wells.
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Actual water production curves will be refined on the basis of data from the
initial test wells.
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Water quality is currently being evaluated, and a water disposal method
compatible with the actual water chemistry will be implemented.
Closure Phase
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Each well, at the end of its economically viable life, will be de-activated
and plugged, and the wellhead area reclaimed.
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If desired, wells may be reconfigured into water wells for residential or
commercial use.
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At the end of the project’s life, anticipated to be at least fifteen years,
all infrastructure will be disassembled and removed, and building and well sites
will be reclaimed.
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Plugging and abandoning procedures will follow generally accepted industry
practices, differing only to accommodate community needs.
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