American Oil and Gas Reporter - September 2022 - 67

SpecialReport: Reservoir Diagnostics
five wells. All five wells were modeled
in one continuous simulation that included
all fracture injection sequences,
offset frac hits, initial production responses,
production responses from
FDIs hits, production responses from
chemical treatments and pressure interference
testing.
A sixth well (child No. 1) is just
outside the DSU and was used only to
simulate an FDI from an offset operator's
pad. Three stages were modeled in the
parent well and two stages were modeled
in each child well. Actual production was
scaled down accordingly. All fractures
and diagnostic data indicate that these
fractures are planar in nature and were
modeled as such.
One year after the parent was completed,
child well No.1 was drilled and completed
higher in the column relative the parent
well. The parent experienced a severe FDI
during the completion of this child well.
To simplify the simulation, only the initial
FDI from the first child well was modeled.
To account for production interference between
child No. 1 and the parent well, a
no-flow boundary was activated halfway
between both wells at the time that the
child came on production.
Two years after the parent well was
completed, the four child wells (nos. 2,
3, 5 and 6) were fractured. They were
FIGURE 2
FDIs on Parent Well (Majority of Small-Magnitude FDIs from Child No. 2)
100.00
80.000
60.000
40.000
20.000
0.0000
10,000
8,000
6,000
4,000
2,000
Lane 3
10,000
completed in pairs and each pair was
zippered. The second pair was completed
one month after the first pair.
Eight major observations characterize
the interactions of the parent with the
four child wells. These observations are
drawn from data, including sealed wellbore
data that had been correlated to fiber
strain data from offset pads, pressure observations
during frac operations, pressure
interference testing during production,
and actual production data.
Fracture Lengths
Fracture lengths were matched with
fracture propagation rates using a method
developed by Devon Energy that uses a
sealed wellbore pressure with no perforations
and filled with a low-compressibility
fluid. As fractures cross the wellbore,
deflections in the pressure can be observed.
The timing of the pressure responses has
been correlated to actual distributed strain
sensor fiber measurements, confirming
that they are caused by fracture intersections.
By using sealed wellbores at different
distances from the wells being fractured,
both the lengths and propagation rates
can be discerned. Within the model, fracture
lengths and propagation rates are
tuned using a combination of parameters,
such as fracture toughness and pressure
dependent permeability.
The model allows specification of an
initial fracture toughness, and then a relative
fracture toughness scaling parameter.
The latter parameter allows fracture
toughness to increase with the square
root of fracture length or height (whichever
is smaller). Greater toughness requires
more fluid pressure to propagate fractures,
and so they become shorter with larger
apertures. Therefore, toughness is a key
parameter in determining propagation
velocity and total length.
Pressure-dependent permeability (PDP)
describes the apparently increased leakoff
associated with propagating fractures.
It may be caused by multiple fracture
strands propagating from a single cluster
or the partial, temporary dilation of natural
fractures at elevated pressure. In the
model, this process was approximated
by applying a reversible permeability
multiplier as a function of pressure. The
apparent permeability to leak-off is assumed
to increase significantly as pressure
begins to exceed the minimum horizontal
stress (Shmin).
As the fracture area increases, the
total fracture leak-off increases, which
has the effect of slowing fracture propagation
as time progresses and it grows
larger. PDP is useful for modeling water
flowback at the beginning of production.
Without PDP, the fractures may close
50,000
2H
1,160
1,140
1,120
1,100
3H
2H
3H
2H
3H
2H
3H
2H
Lane 4
3:00 a.m.
Child
Well 2
6:00 a.m.
9:00 a.m.
Child
Well 3
Child
Well 2
12:00 p.m.
3:00 p.m.
Child
Well 3
6:00 p.m.
Child
Well 2
9:00 p.m.
Child
Well 3
Dec 23rd
Child
Well 2
3:00 a.m.
Child
Well 3
6:00 a.m.
Child
Well 2
SEPTEMBER 2022 67
H Parent VFR (bbl)
Clean Rate
IH Smooth (psi)
Treating Pressure (psi)

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
American Oil and Gas Reporter - September 2022 - 10
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American Oil and Gas Reporter - September 2022 - Cover3
American Oil and Gas Reporter - September 2022 - Cover4
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