Hydrostatic pressure and saturation profile restrict production and cause severe slugging.
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Hydrostatic pressure and saturation profile restrict production and cause severe slugging. When put on production, Fractures and horizontal section fill with fluids such that hydrodynamic equilibrium is achieved. 200 ft = 90 psia 90 psi + 10 ft = 95 psia Well is drilled, then Frac-ed with multiple Stages A typical lift scenario with tubing landed in the curve
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A typical lift scenario with tubing landed in the curve. Well is drilled, then Frac-ed with multiple Stages. When put on production, Fractures and horizontal section fill with fluids such that hydrodynamic equilibrium is achieved. - PowerPoint PPT Presentation
Transcript of Hydrostatic pressure and saturation profile restrict production and cause severe slugging.
Hydrostatic pressure and saturation profile restrict production and cause severe slugging.
When put on production,Fractures and horizontal section fill with fluids
such that hydrodynamic equilibrium is achieved.
200 ft = 90 psia 90 psi + 10 ft = 95 psia
Well is drilled, then Frac-ed with multiple Stages
A typical lift scenario with tubing landed in the curve
10 ft = 5 psia 5 psi + 1 ft = 6 psia
A FLATpak ™ multi-conduit is run in the well with intake ports at the liquid accumulation points
Tubing is pulled ….
Gas flows continuously from the liquid-free horizontal section up the casing
Liquid is removed to the surface by alternately charging and bleeding down the FLATpak ™
An Alternative Lift Method
But my well isn’t loaded up!
I’d see it on the production curves
if it was…
Yearly average Gas Rates (Light Blue Curve) = SMOOTH DECLINEWhite crosses are tubing pressure at 10-30 psig
Yearly average Gas Rates (Light Blue Curve) = SMOOTH DECLINEMonthly allocated Gas Rates (Red Dots) = SMOOTH DECLINE with some recent random noise
Yearly average Gas Rates (Light Blue Curve) = SMOOTH DECLINEMonthly allocated Gas Rates (Red Dots) = SMOOTH DECLINE with some recent random noiseDaily measured Gas Rates (3 years of Yellow crosses) = complex Sawtooth pattern
Daily measured Gas Rates (3 years of Yellow crosses) Complex loading and unloading pattern, repeating pattern every few weeks
So what!
A little liquid over the producing zone never hurt a well!
This well takes a year to clean-up after liquids are driven back into the formation during a Shut-in
This well loads, then unloads…depending on the day.But it is clear what the long term trend is…
Lost production, lost revenue, higher operating costs,…
and lost reserves…
From CSUG/SPE 149477
