American Oil and Gas Reporter - February 2015 - 84

SpecialReport: Improved Oil Recovery
FIGURE 1A

FIGURE 1B

Relative Volume
Curve

Liquid Drop-Out Curve
90
1.2

70

3.5

1.0

60

0.8

50

3.0
2.5
2.0

80

40

0.6
Liquid Volume
0.4

1.5

30

Gas Production

20

0.2

1.0
0.5
1,000

2,000

3,000
Pressure

4,000

5,000

oil phase as chemical equilibrium is established.
Model Description
The description of reservoir fluid composition and phase behavior is from data
published by the Society of Petroleum
Engineers (Pope et al; Wu et al; Wang et
al), which are intended to model the behavior of a gas condensate fluid using
six hydrocarbon components. Table 1
presents the pseudo-component description
and input for the Peng-Robinson equation
of state calculations. Initial reservoir oil

0
1,000

10
0
1,500

2,000

2,500

4,000

4,500

5,000

The initial reservoir pressure for this
field is 6,425 psi. The producer is subject
to minimum bottom-hole pressure constraint of 500 psi, and is produced for
1,800 days (five years) under natural depletion. Our operational, flowing bottom-hole pressure of 500 psi is far below
the dew-point pressure, which results in
condensate drop-out.
CO2 recovery mechanisms include
CO2 dissolution in the oil leading to an
increase in its volume, oil viscosity reduction, vaporization of intermediate to
heavy hydrocarbons, and development

FIGURE 2B

Effect of Numerical Dispersion
On C1 Recovery Factor versus Time

Effect of Numerical Dispersion
On Gas Recovery Factor versus Time
90

90
6X21X2

80

22X21X2

70
Gas Recovery (%)

10X21X2

60

6X21X2

80

22X21X2

70

C1 Recovery

3,000
3,500
Pressure

compositions are given in Table 2, which
represent gas condensate. The reservoir
properties used in this model are based
on published Eagle Ford Shale data.
The dimension of the shale reservoir
is 2,000 feet long by 1,000 feet wide by
200 feet thick. The producer is located
beneath the reservoir domain and the injection well is placed in the upper layer.
The producing horizontal well is stimulated
with 10 transverse fractures placed 200
feet apart, as is the injection well. Fracture
spacing between the injector and producer
is 100 feet.

FIGURE 2A

50
40
30

10X21X2

60
50
40
30

20

20

10

10
0

0
0

2,000

4,000
Time (Days)

84 THE AMERICAN OIL & GAS REPORTER

6,000

Gas Production (%)

Liquid Drop-Out

1.4

4.0

Relative Volume

4.5

0

2,000

4,000
Time (Days)

6,000



American Oil and Gas Reporter - February 2015

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American Oil and Gas Reporter - February 2015 - Cover1
American Oil and Gas Reporter - February 2015 - Cover2
American Oil and Gas Reporter - February 2015 - Contents
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