American Oil and Gas Reporter - January 2017 - 78

Production Technology
FIGURE 2
Well Locations and Predicted Remaining Reserves
In Eagle Ford Study Area
37 MMbbl

39 MMbbl

41 MMbbl

20 MMbbl

76 MMbbl

37 MMbbl

49 MMbbl

312 MMbbl
100+ MMbbl
170 MMbbl

53 MMbbl

214 MMbbl

26 MMbbl
170 MMbbl

61 MMbbl

55 MMbbl
63.9 MMbbl

grates through the horizontal wellbore
(linear flow) after traveling through the
fracture system (bilinear) flow. Second,
the very-low-permeability matrix rock
drainage area often is defined as the stimulated reservoir volume (SRV), with a
drainage boundary that usually is oval
shaped in nature and defined in the x and
y directions as the aspect ratio.
The y component is a function of the
extent of the SRV boundary. The aspect
ratio defines directional contribution of
the flow system trending from bilinear
(ultralow) permeability SRV to pseudo
radial (low to moderate) permeability
reservoir rock.
Figure 1 presents the directional relation
for the aspect ratio. Note the possibilities
of contributions of each component in
the total flow system. Is the flow system
mainly confined directionally along and
adjacent to the fracture (x direction), or
does fluid flow eventually spread significantly in the y direction? The "Xe" and
"Ye" variables define the half-lengths of
the drainage area in the x and y directions.
If the aspect ratio is equal to 1.0, the
drainage pattern will be square (i.e., x and
78 THE AMERICAN OIL & GAS REPORTER

y drainage distances are equal). This shape
will not occur for ultralow-permeability
reservoirs. If the aspect ratio is less than
1.0, the drainage length will be greater
along the x direction than in the y direction.
This invariably is the case for a hydraulic
fracture or a horizontal well penetrating a
very-low-permeability interval.
Well histories seldom exhibit a smooth
decline because mechanical or reservoir
effects often alter the relative volumes of
the oil, water and gas production phases.
Therefore, most production histories
should be divided into producing segments
when projecting future performance with
any degree of certainty. Future performance should be predicated on the latest
characteristics, and not necessarily on an
average of the total history.
Analysis Method
The analysis method begins by plotting
production records in four coordinate
systems for mutual analyses. Each plot
may or may not furnish a portion of the
final cohesive picture. Comparing plots
often reinforces or dismisses initial conclusions about a well's production potential, and the number and meaning of

interpreted segments.
Four basic production plots form the
basis for the interpretation technique:
* Semi log rate versus time performance reviews the performance history of
the rate decline characteristics and associated gas-to-oil and water-to-oil ratios.
If possible, the history should be divided
into producing segments. This analysis
also should be coupled with the review
of well records.
* Log-log rate versus time determines
whether it is possible to identify transient
and boundary-dominated flow regimes.
* Flow rate versus time provides an
estimate of fracture flow properties, and
aids in defining transient and boundarydominated flow for a linear system, and
in assessing the extent of formation damage.
* Real time (t) versus material balance
time (tmb) ratio uses an approximation
technique to smooth erratic production
fluctuations without needing superposition.
Studies were conducted on the impact
of the Arps b-exponent value on the shape
of the tmb versus t plot. Curves range
from exponential to boundary-dominated
(b = 0) and transient (b = 20) conditions.
The shape of the curve defines the overall
well flow system, and it is dramatically
different for exponential (concave upward
curve) and transient (concave downward
curve) conditions.
With exponential conditions, a well
operates under pseudoradial flow, indicating a good communicating wellbore
and fracture system, and slightly greaterthan-normal matrix permeability (in other
words, an expanded drainage volume). A
hyperbolic curve signifies minimal contribution of the matrix flow system either
from marginally effective fractures or
low-matrix oil permeability.
In this study, the Arps curve flattened
as a function of increasing b-exponent
values. The flow system ranges in quality
from extreme pseudoradial to extreme
linear, according to the location of the
curve between the two boundaries.



American Oil and Gas Reporter - January 2017

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