American Oil and Gas Reporter - January 2020 - 56
Unconventional Resource Science
RTD Analysis
Further probing the tracer response
within a single segment provides insights
into how that segment of the frac fluid
was being recovered. This type of analysis
can be seen visually with Segment 48K
and Segment 48G (Figures 3 and 4). The
response for Segment 48K exhibits a
mostly decreasing profile, with the highest
concentration occurring in the first sample.
On the other hand, Segment 48G increases
from a low number at the first sample
and peaks at the fifth sample and then
decreases over time. A more quantitative
characteristic of these types of responses
is necessary to be able to determine just
what each type means.
In an effort to better understand how
frac fluid in each segment was flowing
back, residence time distribution (RTD)
FIGURE 1
Water-Phase Tracer Concentration Normalized to 476 Barrels
140
120
100
80
60
40
20
0
48L
48K
48J
48I
48H
48G
48F
48E
48D
48C
48B
48A
FIGURE 2
Oil-Phase Tracer Concentration Normalized to 476 Barrels
35,000
30,000
25,000
20,000
15,000
10,000
5,000
0
48L
48K
48J
48I
48H
48G
48F
48E
48D
48C
48B
48A
FIGURE 3
Flowback Profile of Water-Phase Tracer Injected into Segment 48K
450
400
350
300
250
200
150
100
50
0
48L
48K
48J
48I
48H
48G
48F
48E
48D
48C
48B
48A
FIGURE 4
Flowback Profile of Water-Phase Tracer Injected into Segment 48G
450
400
350
300
250
200
150
100
50
0
48L
48K
48J
48I
48H
48G
56 THE AMERICAN OIL & GAS REPORTER
48F
48E
48D
48C
48B
48A
analysis was applied to the tracer data.
Residence time was calculated for each
tracer to indicate the average arrival
time of tracer. Since there was a significant increase in water tracer concentration on July 25, only data before that
date was used in the analysis. Applying
this analysis to the earlier segments
shows that the decreasing profile from
segment 48K means that the tracer is
recovered quicker than for the increasing
and then decreasing profile for segment
48G, evidenced by the lower residence
times for 48K.
Based on the RTD analysis, waterphase tracers for the pad-stage segment
(48A) flowed back faster even though
they were injected first (the pad-stage
frac fluid should flow farthest into the
formation). The tracers injected in 48A
could leach into the SRV, which was not
well propped near the wellbore. Such a
leaching process did not occur to the
fluid after pad segment with proppant
injection. During flowback, frac fluid as
well as tracer for segment 48K flowed
back faster than the other fluid segments.
The remaining water-phase tracers injected in the later linear gel segments
flowed back before the tracers injected
in early slickwater segments. Nevertheless,
no obvious piston-like displacement was
observed from tracer data. Similar tracer
flowback behavior also was observed for
the oil-phase tracers.
As this study illustrates, chemical
tracer technology is an effective, nonintrusive technique that can provide invaluable information about frac fluid
dynamics inside created fractures. All
tracers were detected in the flowback
samples, suggesting that no fluid segments were placed completely outside
of the propped fracture network. A high
degree of fluid mixing appeared to
occur during stimulation, which could
indicate high fracture complexity. This
could be caused by several factors, including the breakdown of primary, secondary and tertiary fractures; varying
cluster efficiency; or duning effects that
led to the diversion of frac fluid within
the fracture network.
❒
American Oil and Gas Reporter - January 2020
Table of Contents for the Digital Edition of American Oil and Gas Reporter - January 2020
Contents
American Oil and Gas Reporter - January 2020 - Intro
American Oil and Gas Reporter - January 2020 - 1
American Oil and Gas Reporter - January 2020 - 2
American Oil and Gas Reporter - January 2020 - Contents
American Oil and Gas Reporter - January 2020 - 4
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