最基础的盆地流体动力学英文讲义
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Distance along strike (km)
140
120
(b) Induced heads
100
Distance along dip (km)
80
60
-10
+10
40
-20
+20
20
0
-20
-40
-60 -40 -20 0 20 40 60 80 100 120 140
Distance along strike (km)
Groundw2akmter associated
Salinity (ppm)
with evapo1r00itkems
2e4
1.8e5
t = 0 years
3.4e5 Louann Salt
Organic maturation
• Time temperature index (TTI) TTI tn 2n
Biblioteka Baidu m
1 m
w1
w2
w3
gz
v2 2
p dP
p0
m
gz
P
(hyd. potential per unit mass)
gz P (hyd. potential per unit volume)
Elevation Pressure
Heads at point A
The timing of oil generation is not the same for all source rocks
kerogen with low EA and high A0 tend to reach peak generation earlier
Higher EA and lower A0 allow Slow thermal cracking
Z = 0, P = P0
• work to lift fluid
w1 = mgz
• work to compress
fluid
w2 =
p
VdP m
p dP
p0
p0
• Work to accelerate
fluid
mv 2
W3 =
2
Hydraulic potential ()
~0
Slope (dip) of tilted oil-water interface dz w dh dl w o dl
If no hydraulic gradient
dh 0 dl dz 0 dl
(no water movement) Horizontal interface
Hydrodynamics of oil migration
Shale
Red shale
TTI = 15-160
0
100 200
200 100 300 400
3 km 50 km
Overpressure, atm
0
325
650
Ro = 0.65-1.3%
0
100 200
200 100 300 400
3 km 50 km
Overpressure, atm
0
325
650
Hydrodynamics and FluidsSediments-Bacteria Interaction in the
The VR is expressed as Ro%, the percentage of light reflected from the sample, calibrated against a material with ~100% reflectance (i.e. a mirror)
Oil window: Ro = 0.65-1.3%
Permian Basin, West Texas:
Mechanisms for Sulfur Ore Genesis
Permian Basin
Why oil and mineral reservoirs are located along basin’s margins far away from their deep sources? How overpressures are maintained in this tectonically stable basin?
n
– n= 0, T = 100-110C – n = 1, T= 110-120C – n = 2, T= 120-130C – TTI = 15-160, oil generation window – TTI = 500-1000, deadline for preserving oil – TTI =1,500, deadline for preserving wet gas
Bioepigenetic sulfur (Culberson mine)
MVT mineralization, Bird mine (Glass Mt.)
Calcite Galena/Sphalerite
2.5 cm
(from Hill, 1996)
Dolomite
Limestone
Sandstone
Oil-water interface dips in the same direction as hydraulic gradient
Faster gw flow (dh/dl increases), steeper oil-water interface
Required conditions to trap oil
Density-driven flow (hydrothermal convection)
Temperature, °C 20 105 190
well 1
well 2 well 3
well 4
well 5 well 6
well 7
ƒ
ƒƒ
ƒ
ƒƒ
ƒ
.1 km 10 km
Salinity, molal 0 3.25 6.5
Gw moves from areas with high potential energy to areas with low potential energy
Physical Quantities define hydraulic potential
Elevation
Fluid pressure
Organic maturation
• Arrhenius model – track the fraction Xo (or %) of oil generated by a source rock
k
A e EA / RTk 0
– A0 is the pre-exponential factor (hr-1) – EA is the activation energy (kJ/mol) – R is the gas constant (8.31432 J K-1 mol-1)
Topographic-driven flow
Hydraulic potential, atm
0
50 100
Compaction-driven flow (Gulf of Mexico)
Rock type: sh, fraction
0
.5
1
Groundwater flow and overpressure in the Gulf of Mexico Basin
Geologic structure dip in the same direction as the hydraulic gradient (or oil-water interface)
dip of geologic structure > dip of oil-water interface
p
g
Real flow direction
Gravity (elevation effect)
Hubbert analysis (How much work required to lift fluid from a standard state to a new elevation z)
P, v z
dX o dt
k1
Xo
Organic maturation
Ao and Ea differ among various source rocks
Obtained by hydrous pyrolysis experiments
Woodford Shale (EA = 218, A0 = 6.511016)
Multiphase Flow
h P z
g
DNAPL w gas
P PP
DNAPL
w
gas
DNAPL (sinker)
Gas (floater)
Water
g
Mechanisms of basin-scale fluid migration
Gravity (topographically-driven) Compaction Density-driven Tectonic-driven
1 Colbert Franklin
2
Lamar 3
4 Pickens
5 Greene
Sumter 6
Choctaw
7 8 Washington
Mobile 9
0
10
40 mi.
Louann Salt
12
3
45
6
78
9
10
Meteoric water affected by mixing
N
S
carbonate groundwater
Hubbert Analysis (1940)
Gw flow porous media is a mechanic process that overcomes frictional forces along a flow path
Hydraulic potential is defined as the mechanic energy per unit mass or per unit volume of fluid
Organic maturation
Vitrinite reflectance (VR)
Vitrinite is not strongly prone to oil and gas formation, is common as a residue in source rocks
the vitrinite becomes increasingly reflective as thermal rank increases. Therefore, the % reflection of a beam of white light from the surface of polished vitrinite is a function of the rank (maturity)
Piezometer
h
A
Sea level
z
P g g(h z)
gh P gz
• Hydraulic head h
– Water table surface to sea level
• Elevation head z
– Bottom of piezometer (point A) to sea level
Fraction of Oil and Gas Generation
1 (B)
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0-10
-8
AGg a=s4x1012
Oil
Gas
Ag= 4x109
Gas
Ag=4x106
-6
-4
-2
0
Time (m.y.)
Organic maturation of Niger basin
• Pressure head
– Water table surface to point A
Relationship between and h
gh
gh P gz
h P z
g
Hydrodynamics of oil migration (Hubbert, 1954)
N
S
2 km 100 km
Pressure, atm 0 750 1500
.2 5
cm/yr
140
120
(a) Volumetric Strain
100
Dsitance along dip (km)
80
+2e-6
60
+4e-6
-2e-6 -4e-6
40
20
0
-20
-40
-60 -40 -20 0 20 40 60 80 100 120 140
140
120
(b) Induced heads
100
Distance along dip (km)
80
60
-10
+10
40
-20
+20
20
0
-20
-40
-60 -40 -20 0 20 40 60 80 100 120 140
Distance along strike (km)
Groundw2akmter associated
Salinity (ppm)
with evapo1r00itkems
2e4
1.8e5
t = 0 years
3.4e5 Louann Salt
Organic maturation
• Time temperature index (TTI) TTI tn 2n
Biblioteka Baidu m
1 m
w1
w2
w3
gz
v2 2
p dP
p0
m
gz
P
(hyd. potential per unit mass)
gz P (hyd. potential per unit volume)
Elevation Pressure
Heads at point A
The timing of oil generation is not the same for all source rocks
kerogen with low EA and high A0 tend to reach peak generation earlier
Higher EA and lower A0 allow Slow thermal cracking
Z = 0, P = P0
• work to lift fluid
w1 = mgz
• work to compress
fluid
w2 =
p
VdP m
p dP
p0
p0
• Work to accelerate
fluid
mv 2
W3 =
2
Hydraulic potential ()
~0
Slope (dip) of tilted oil-water interface dz w dh dl w o dl
If no hydraulic gradient
dh 0 dl dz 0 dl
(no water movement) Horizontal interface
Hydrodynamics of oil migration
Shale
Red shale
TTI = 15-160
0
100 200
200 100 300 400
3 km 50 km
Overpressure, atm
0
325
650
Ro = 0.65-1.3%
0
100 200
200 100 300 400
3 km 50 km
Overpressure, atm
0
325
650
Hydrodynamics and FluidsSediments-Bacteria Interaction in the
The VR is expressed as Ro%, the percentage of light reflected from the sample, calibrated against a material with ~100% reflectance (i.e. a mirror)
Oil window: Ro = 0.65-1.3%
Permian Basin, West Texas:
Mechanisms for Sulfur Ore Genesis
Permian Basin
Why oil and mineral reservoirs are located along basin’s margins far away from their deep sources? How overpressures are maintained in this tectonically stable basin?
n
– n= 0, T = 100-110C – n = 1, T= 110-120C – n = 2, T= 120-130C – TTI = 15-160, oil generation window – TTI = 500-1000, deadline for preserving oil – TTI =1,500, deadline for preserving wet gas
Bioepigenetic sulfur (Culberson mine)
MVT mineralization, Bird mine (Glass Mt.)
Calcite Galena/Sphalerite
2.5 cm
(from Hill, 1996)
Dolomite
Limestone
Sandstone
Oil-water interface dips in the same direction as hydraulic gradient
Faster gw flow (dh/dl increases), steeper oil-water interface
Required conditions to trap oil
Density-driven flow (hydrothermal convection)
Temperature, °C 20 105 190
well 1
well 2 well 3
well 4
well 5 well 6
well 7
ƒ
ƒƒ
ƒ
ƒƒ
ƒ
.1 km 10 km
Salinity, molal 0 3.25 6.5
Gw moves from areas with high potential energy to areas with low potential energy
Physical Quantities define hydraulic potential
Elevation
Fluid pressure
Organic maturation
• Arrhenius model – track the fraction Xo (or %) of oil generated by a source rock
k
A e EA / RTk 0
– A0 is the pre-exponential factor (hr-1) – EA is the activation energy (kJ/mol) – R is the gas constant (8.31432 J K-1 mol-1)
Topographic-driven flow
Hydraulic potential, atm
0
50 100
Compaction-driven flow (Gulf of Mexico)
Rock type: sh, fraction
0
.5
1
Groundwater flow and overpressure in the Gulf of Mexico Basin
Geologic structure dip in the same direction as the hydraulic gradient (or oil-water interface)
dip of geologic structure > dip of oil-water interface
p
g
Real flow direction
Gravity (elevation effect)
Hubbert analysis (How much work required to lift fluid from a standard state to a new elevation z)
P, v z
dX o dt
k1
Xo
Organic maturation
Ao and Ea differ among various source rocks
Obtained by hydrous pyrolysis experiments
Woodford Shale (EA = 218, A0 = 6.511016)
Multiphase Flow
h P z
g
DNAPL w gas
P PP
DNAPL
w
gas
DNAPL (sinker)
Gas (floater)
Water
g
Mechanisms of basin-scale fluid migration
Gravity (topographically-driven) Compaction Density-driven Tectonic-driven
1 Colbert Franklin
2
Lamar 3
4 Pickens
5 Greene
Sumter 6
Choctaw
7 8 Washington
Mobile 9
0
10
40 mi.
Louann Salt
12
3
45
6
78
9
10
Meteoric water affected by mixing
N
S
carbonate groundwater
Hubbert Analysis (1940)
Gw flow porous media is a mechanic process that overcomes frictional forces along a flow path
Hydraulic potential is defined as the mechanic energy per unit mass or per unit volume of fluid
Organic maturation
Vitrinite reflectance (VR)
Vitrinite is not strongly prone to oil and gas formation, is common as a residue in source rocks
the vitrinite becomes increasingly reflective as thermal rank increases. Therefore, the % reflection of a beam of white light from the surface of polished vitrinite is a function of the rank (maturity)
Piezometer
h
A
Sea level
z
P g g(h z)
gh P gz
• Hydraulic head h
– Water table surface to sea level
• Elevation head z
– Bottom of piezometer (point A) to sea level
Fraction of Oil and Gas Generation
1 (B)
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0-10
-8
AGg a=s4x1012
Oil
Gas
Ag= 4x109
Gas
Ag=4x106
-6
-4
-2
0
Time (m.y.)
Organic maturation of Niger basin
• Pressure head
– Water table surface to point A
Relationship between and h
gh
gh P gz
h P z
g
Hydrodynamics of oil migration (Hubbert, 1954)
N
S
2 km 100 km
Pressure, atm 0 750 1500
.2 5
cm/yr
140
120
(a) Volumetric Strain
100
Dsitance along dip (km)
80
+2e-6
60
+4e-6
-2e-6 -4e-6
40
20
0
-20
-40
-60 -40 -20 0 20 40 60 80 100 120 140