American Oil and Gas Reporter - September 2021 - 68

SpecialReport: Gas Gathering
FIGURE 3
Change in IPR versus Time (Conventional Well Example)
Ptbg
both free gas and adsorbed gas. The free
gas volume is similar to the gas volumes
in conventional and tight sand reservoirs.
However, low reservoir pressures are required
to recover the adsorbed gas fraction,
similar to coalbed methane reservoirs.
System Architectures
A wide variety of GGS architectures
are possible given the number of variables
involved, including geographic dimensions,
well/pad location and spacing, well deliverability
and pressures, wellstream composition,
hydrate prevention strategy, liquids
handling strategy, compression, etc. Figure
4 shows a typical GGS layout for both
conventional and unconventional fields.
A shale gas GGS architecture is quite
Flow
life of unconventional wells because of
their rapid decline rates. While there are
various artificial lift options available to
deal with liquid loading, the impact of
surface facilities on flowing tubing pressure
is an important consideration. Lower
backpressure on the wells helps inflow
performance and increases gas velocity
in the tubing for a given mass or standard
volumetric gas flow rate.
Figure 3 shows an example of changing
IPRs over time from reservoir depletion
and the effect of backpressure
on deliverability. These curves show that
in order to maintain well deliverability,
it is generally necessary to reduce flowing
tubing pressure over time with comFIGURE
4
Conventional (Left) versus Unconventional (Right) GGS Layouts
Well pads
Gas plant
Low pressure gathering
100-300 psig
pression to offset the effect of reservoir
pressure depletion.
The effect of GGS pressure on flowing
well tubing pressure-and ultimately reservoir
pressure-on recovery is fairly straightforward
for conventional volumetric reservoirs
with minimal aquifer pressure support.
For these reservoirs, ultimate reserves
recovery is related directly to reservoir
abandonment pressure, dictated by minimum
economic production rates for individual
wells.
Tight gas reservoirs have pressure-reserves
relationships similar to conventional
reservoirs with lower gas volumes because
of lower porosity. Shale gas reservoirs
behave somewhat differently. They contain
different from a conventional GGS. Figure
4 is typical of many shale gas developments.
In this configuration, a glycol dehydrator
is located after the compression
discharge. Any liquids recovered by the
compressor station are stored in tanks
and shipped by truck. Fairly large slug
catchers are needed at the inlet to the
compressor station.
One of the main differences between
a GGS layout for shale gas versus conventional
gas is the use of field compressor
stations. Shale gas fields are large in
areal extent, which means longer distances
between wells and plants; too far for
plant inlet compression to be effective or
for low-pressure transport of gas and associated
liquids to be practical. Another
key difference is that in shale gas developments,
compression is often needed
Compressor
station
Gas plant
Future inlet
compression
High pressure trunkline
1,050-1,250 psig
68 THE AMERICAN OIL & GAS REPORTER
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American Oil and Gas Reporter - September 2021

Table of Contents for the Digital Edition of American Oil and Gas Reporter - September 2021

Contents
American Oil and Gas Reporter - September 2021 - Intro
American Oil and Gas Reporter - September 2021 - Cover1
American Oil and Gas Reporter - September 2021 - Cover2
American Oil and Gas Reporter - September 2021 - Contents
American Oil and Gas Reporter - September 2021 - 4
American Oil and Gas Reporter - September 2021 - 5
American Oil and Gas Reporter - September 2021 - 6
American Oil and Gas Reporter - September 2021 - 7
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American Oil and Gas Reporter - September 2021 - Cover3
American Oil and Gas Reporter - September 2021 - Cover4
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