You open a gas well's choke wider and the wellhead temperature rises. Why?
A) Joule-Thomson heating at the choke
B) Higher rate carries more reservoir heat up the tubing
C) Gas composition changes
D) Pressure increases upstream
A) Joule-Thomson heating at the choke
B) Higher rate carries more reservoir heat up the tubing
C) Gas composition changes
D) Pressure increases upstream
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In gas reservoir engineering, what is the purpose of utilizing real gas pseudopressure (m(p)) instead of standard pressure (p) when analyzing gas well test data?
A.
To account for the pressure dependency of gas viscosity and gas compressibility factor (z)
B.
To simplify calculations assuming ideal gas behavior at high pressures
C.
To eliminate the need for skin factor corrections
D.
To convert dry gas metrics directly into black oil volumetric equivalents
A.
To account for the pressure dependency of gas viscosity and gas compressibility factor (z)
B.
To simplify calculations assuming ideal gas behavior at high pressures
C.
To eliminate the need for skin factor corrections
D.
To convert dry gas metrics directly into black oil volumetric equivalents
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Why is the pore pressure and fracture gradient window narrow in deepwater?
A) Seawater has high density
B) Formations are always overpressured
C) Seawater replaces rock in the overburden, lowering fracture gradient
D) Mud weight is always too low
A) Seawater has high density
B) Formations are always overpressured
C) Seawater replaces rock in the overburden, lowering fracture gradient
D) Mud weight is always too low
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Core porosity is 20% but density log reads 28%. A valid non-tool-failure reason is:
A) Wrong matrix density assumed in the log
B) Core is always more accurate
C) Log measures permeability
D) Mud filtrate has no effect
A) Wrong matrix density assumed in the log
B) Core is always more accurate
C) Log measures permeability
D) Mud filtrate has no effect
A well flows naturally, yet the operator adds gas lift. The most likely reason is:
A) To increase reservoir pressure
B) To raise oil viscosity
C) To lighten the fluid column and increase drawdown and rate
D) To reduce GOR
A) To increase reservoir pressure
B) To raise oil viscosity
C) To lighten the fluid column and increase drawdown and rate
D) To reduce GOR
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Pr = 3000 psi, Pb = 2500 psi, J = 2 stb/d/psi, Pwf = 1500 psi. Total rate using the Vogel combined IPR is closest to:
A) 1000 stb/d
B) 1644 stb/d
C) 2644 stb/d
D) 3500 stb/d
A) 1000 stb/d
B) 1644 stb/d
C) 2644 stb/d
D) 3500 stb/d
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Which well is more sensitive to tubing size?
A) Dry gas well
B) High-GOR oil well, because tubing size affects both friction and hydrostatic gradient
C) Both equally
D) Neither
A) Dry gas well
B) High-GOR oil well, because tubing size affects both friction and hydrostatic gradient
C) Both equally
D) Neither
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