American Oil and Gas Reporter - December 2017 - 60

FIGURE 4A

FIGURE 4B

Comparison of STP/Treatment Rate Ratios
For Initial Well versus Sidetrack

Post-Frac Differential Pressures
(ISIP/Five-Minute SIP) for Initial Well versus Sidetrack
2,000

450

Sidetrack Well

400

Initial Well

Ratio, STP/Rate (psi/bbl/min)

Ratio, STP/Rate (psi/bbl/min)

500

350
300
250
200
150
100

1,800

Sidetrack Well

1,600

Initial Well

1,400
1,200
1,000
800
600
400
200

50

0

0
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21
Stage No.

For the sidetrack, formation heterogeneity
and perforation cluster stress differentials
were accounted for in the petrophysical
model, and the perforation scheme was
optimized to minimize those effects.
The final aspect was accounting for
leak-off of stimulation fluid from the
hydraulically generated fractures into
the in-situ natural fractures and pre-existing hydraulically induced fractures
from the initial wellbore. This type of
leak-off can be classified as pressuredependent (PDL).
Leak-off can be assessed in the pres-

1

2

3

4

sure decline post-instantaneous shut-in
pressure (ISIP). As an indicator of leakoff inherent in the formation, post-fracturing differential pressures from the
ISIP and five-minute shut-in pressures
(SIPs) were calculated for each individual
stage in both wells and compared (Figure
4B). The greater the differential, the
more PDL a particular stage likely encountered. From the prevalence of the
breakdown patterns and the obvious difference in the sidetrack well's differential
pressures, the stimulation treatments appear to encounter more leak-off than

5

6

7

8

9 10 11 12 13 14 15 16 17 18 19 20 21
Stage No.

the initial well.
Between the stimulation treatment designs
from both wells, several design aspects remained constant, including proppant amount,
fluid system, treatment rate, perforation
clusters per stage, and diversion to further
assist with fluid and proppant distribution.
Two changes were made to the initial
treatment design. First, approximately
25 percent of the proppant was replaced
with 100-mesh sand. The logic was that
finer sand could behave as a fluid-loss
additive if any fluid were to leak off
into in-situ natural fractures and mitigate

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