American Oil and Gas Reporter - September 2022 - 64

SpecialReport: Reservoir Diagnostics
FDIs involve complex interactions of
physical processes. Pressure depletion
around the parent well reduces stress and
causes propagation of the child fractures
toward the depleted region. Asymmetric
flow also may be driven by fluid diverting
into pre-existing hydraulic fractures from
the parent well. Asymmetry may be reduced
or eliminated if the parent well is
repressurized by preloading or inflow
from FDIs. As fluid flows into the parent
fracs, it may flow all the way into the
parent well, carrying proppant and potentially
causing damage and/or well
blockage. Fluid can crossflow through
the parent well, and then flow back out
of the well from other locations along
the lateral.
Of course, production also is impacted
by production interference. After infill
drilling, both the parent and child wells
compete to produce fluid from overlapping
volumes of rock.
Chemical and multiphase effects play
a major role in some parent/child interactions.
Because these effects are dependent
on formation properties, they
are highly variable by formation. FDI
damage can be diagnosed from a large,
persistent loss of production at the parent
well (once physical damage mechanisms
have been ruled out). The detailed mechanisms
are usually not known in detail,
so chemical mitigation treatments often
have taken a " kitchen sink " approach by
pumping surfactant, citric acid, aromatic
FIGURE 1
Child Well #1
Fracced 1 Year
After Parent
Well
Parent Well
Fracced First
Well Position and Frac Timing
DSU
Child Well #5
Child Well #2
Fracced First,
Two Years
After Parent
Well
Child Well #3
Fracced Second,
Two Years
After Parent
Well
619'
901'
901'
4729'
64 THE AMERICAN OIL & GAS REPORTER
1154'
1154'
Fracced Third,
Two Years
After Parent
Well
Child Well #6
Fracced Fourth,
Two Years
After Parent
Well
solvents and iron chelators to attack a
variety of types of damage.
STACK Pad
Devon Energy performed a comprehensive
modeling study, delivered by
ResFrac, that calibrated a coupled " true "
hydraulic fracturing and reservoir simulator
to a complex set of observations from a
five-well pad in the STACK play in the
Anadarko Basin. The model was constrained
by sealed wellbore pressure monitoring,
interference testing, pressure responses
during FDIs, production data
and responses to chemical treatment. It
was possible to match the full set of observations
in a single, continuous simulation
by calibrating the fracture toughness
and leak-off, the permeability and relative
permeability, a parameter related to proppant
transport, and parameters related to
a " fracture conductivity damage " mechanism
built into the simulator.
The fracture damage calculations mimic
the reaction of frac fluid with the formation
fluid as they mix in a hydraulic
fracture during and after a frac hit. The
interpretation of fracture conductivity
damage is corroborated by production
impacts after FDIs, positive response to
chemical mitigation treatments and direct
sampling of material from the wellbore.
Because of the volume and quality of
calibration data available, it is possible
to constrain the key uncertainties of the
model. It now can be used to design
strategies to mitigate negative impacts
from parent/child interactions.
The project targeted the upper and
lower Meramec formation. Four offsetting
child wells were drilled two years after
the parent well was drilled in the drill
spacing unit. In addition to the child
wells, another well was included in model
that was outside the DSU. This well was
located on the opposite side of the parent
and completed one year before the child
wells in the DSU. Parent well production
was significantly impaired following the
stimulation of all four child wells. Based
on work to remediate and restore the
parent well's production, evidence suggested
chemical damage to proppant pack
conductivity at least partially responsible
for production impairment.
A modeling study was performed to
investigate potential physical causes and
mitigation strategies. The hydraulic fracturing
and reservoir simulator used in
the study is well suited to describe
parent/child interactions because it fully
couples crack propagation and transport
with multiphase flow and production. It
is possible to perform detailed FDI simulations.
The model can simulate the displacement
of frac fluid into a hydrocarbon-filled
parent well fracture as it reopens
during an FDI, neighboring fractures
propagate and stress shadow one another,
proppant remobilizes, and fluid crossflows
through the well.
For this study, a simulation was constructed
and calibrated to match a complex
series of events with fracturing and production
across multiple generations of
wells. The simulator models FDI-related
damage as a process that causes conductivity
loss as damage material accumulates
in response to interaction of frac fluid
with the formation and hydrocarbons in
the fracture. Because the details of the
damage reactions are not known in detail,
damage is modeled as a generic process.
In addition, reduced fracture damage
from injecting a chemical mitigation treatment
is modeled.
Frac Sequencing
Figure 1 shows the well spacing and
frac sequence across the pad for all
250'
Zippered 1st
Zippered 2nd, 1 Month Later

American Oil and Gas Reporter - September 2022

Table of Contents for the Digital Edition of American Oil and Gas Reporter - September 2022

Contents
American Oil and Gas Reporter - September 2022 - Intro
American Oil and Gas Reporter - September 2022 - Cover1
American Oil and Gas Reporter - September 2022 - Cover2
American Oil and Gas Reporter - September 2022 - 3
American Oil and Gas Reporter - September 2022 - 4
American Oil and Gas Reporter - September 2022 - Contents
American Oil and Gas Reporter - September 2022 - 6
American Oil and Gas Reporter - September 2022 - 7
American Oil and Gas Reporter - September 2022 - 8
American Oil and Gas Reporter - September 2022 - 9
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American Oil and Gas Reporter - September 2022 - Cover3
American Oil and Gas Reporter - September 2022 - Cover4
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