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PART-2: CBM EXPLORATION
PROGRAM OBJECTIVES
Dr Alan Bayrak
Managing Director
Coal Seam Gas Exploration & Production Services
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IDENTIFY THE CBM PROSPECTIVITY OF THE POTENTIAL
COAL SEAMS
Definition of prospective coal seam:
A prospective coal seam must hold a certain amount of
recoverable gas with high concentration of methane (95>)
to be extracted economically in current market and
technological conditions.
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Gas composition;
Gas content;
Coal thickness;
Coal Depth;
Permeability; and
Identify potential CBM production zones.
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Gas composition analysis is very
important in assessment of CBM
in coal reservoirs. CBM consists
predominantly of methane (90-
99%) with minor amounts ofother gases like carbon dioxide
and nitrogen.
Inert gases (carbon dioxide and
nitrogen) having content >5% isnot accepted in most of the
pipelines.
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Gas content testing is the most important stage in an
exploration program and needs high quality, reliable data
to evaluate the resource potential of CSG in a prospect
area. Gas content test includes three main gas estimation
stages as follows:
Q1-Lost Gas
Q2-Measurable Gas
Q3-Residual Gas
All measurements must be conducted at reservoir
temperature conditions. Desorption process is a
continuous event and sometimes it takes up to three
months (depends on natural permeability in the coal). It
starts right after coal sample is sealed off in the canister
(at the field) and continues till all gas is released from the
coal (at the lab). In this method, gas content is determined
by collecting and measuring the volume of gas released
from a sample of coal taken out from the coal seam by
drilling.
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Total net coal thickness is an
important parameter in
constraining the CBM resources,
however it is thickness of individual coal seams and their
proximity to each other that affects
the design and cost of the gas fielddevelopment. A minimum of 8-10
metres net coal can be considered a
potential reservoir.
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A practical depth range of
commercial CBM develop-
ments is 250 metres up to
1200metres under favourablepermeability and gas content.
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Total Test
1050
1100
1150
1200
1250
1300
Pressure(psi(a))
0
100
200
300
400
LiquidRate(bbl/d)
-12
-10
-8
-6
-4
-2
0
Error(%)
0.00 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60 1.80 2.00
Time (h)
pdata
pmodel
qwater
% Error
pi (syn) 1320.8 psi(a)
p*model 1320.8 psi(a)
Cumwater 0.00 MbblW IPmodel Mstb
kh 385.63 md.ft
h 34.449 ft
k 11.1944 md
sd -0.109
Xe ft
Ye ft
Xw ft
Yw ft
Total Test
1050
1100
1150
1200
1250
1300
Pressure(psi(a))
0
100
200
300
400
LiquidRate(bbl/d)
-12
-10
-8
-6
-4
-2
0
Error(%)
0.00 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60 1.80 2.00
Time (h)
pdata
pmodel
qwater
% Error
pi (syn) 1320.8 psi(a)
p*model 1320.8 psi(a)
Cumwater 0.00 MbblW IPmodel Mstb
kh 385.63 md.ft
h 34.449 ft
k 11.1944 md
sd -0.109
Xe ft
Ye ft
Xw ft
Yw ft
The most critical factor in CSG play is the presence of permeability.Properties of the natural fracture system (cleats) have the greatest
effect on gas and water production rates. Absolute permeability
and relative permeability are two of the most important naturalfracture system flow properties. Permeability of a coal bed is
determined by its fracture (cleat) system, which in turn is largelycontrolled by the tectonic/structural setting. Whilst permeability
testing provides useful information the key for any area is to
demonstrate production from the seams. Permeability testingdetermines the in-situ reservoir permeability of target coal seams
utilis-ing injection/falloff tests, which are very effective andefficient for testing water saturated coal seams.
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Define the composition and content
of the coal seam gas within the coals
attributable to economic gas
production;
Identify potential CBM targets;
To advance the understanding of the
extend of the coal seams;
To incorporate the borehole datainto the database program to
improve geological model for the
area;
To assist in geological correlation ofexisting seismic data in the prospect
area.