American Oil and Gas Reporter - June 2024 - 55

SpecialReport: Artificial Lift Technology
reservoir characteristics, such as high
permeability or porosity, their output is
considerably diminished by the challenges
associated with managing high water
production. The presence of water with
high specific gravity increases the load
on the ESP, requiring it to work harder
to achieve the same level of fluid lifting,
thereby directly impacting the efficiency
of hydrocarbon production.
In terms of mitigating the effects of a
frac hit in which fracturing fluid invades
an adjacent well, the primary objective
is to expediently extract the influx of
water from the formation to resume hydrocarbon
production. To this end, deploying
an ESP is a strategic choice,
given the higher fluid lifting capacities
and ability to enhance recovery rates.
Figure 3 shows the favorable performance
of ESPs relative to gas lift systems across
varying degrees of water saturation within
the reservoir.
The efficiency of ESPs becomes particularly
pronounced as the water cut escalates,
substantiating their effectiveness
in minimizing the recovery time required
for a well to regain its productive capacity
after a frac hit. This advantage is attributable
to the ESP's inherent ability to
handle substantial volumes of water and
expedite the removal process, allowing
oil production to be restored.
The design and selection of an ESP
in oil wells with high water cuts necessitates
careful consideration of the specific
gravity of the water to ensure the
system can handle the anticipated fluid
densities. This entails not only choosing
a pump with adequate pressure-generating
capacity but also implementing
strategies to manage or minimize water
production to optimize overall well production
performance.
FIGURE 3
Gas Lift and ESP Performance Comparison
(Reservoir with High Water Cuts)
4,000
3,500
3,000
2,500
2,000
1,500
1,000
500
50
95
Gas LIft
50
Water Cut (%)
Target Rate (FBHP=2441 psi)
Source: SPE-185773-MS (Suat Bagci, et. al., 2017)
Proactive Approach
While temporarily shutting in wells
as a precautionary measure during offset
well frac treatments presents both benefits
and drawbacks, a spectrum of performance
impacts can become evident quickly when
production is resumed. These impacts
are attributed to a complex interplay of
factors, but primarily include reservoir
pressure alterations and cross-well migration
of reservoir and frac fluids.
The phenomenon of increased postfrac-hit
water production spotlights the
critical role of ESPs in navigating these
challenges. With their robust design for
handling substantial fluid volumes, ESPs
can play an invaluable role in mitigating
frac hits' adverse effects by efficiently
removing the influx of water to shorten
the recovery period and minimize downtime-allowing
production to resume as
swiftly as possible.
The operational challenges associated
with well shut-ins and frac hits demand
sophisticated management strategies.
Adopting ESPs represents a proactive
approach to addressing these challenges.
As the industry continues to navigate the
complexities of reservoir management
and production optimization, the insights
gained from using ESPs to manage postfrac-hit
recovery illuminate a path forward.
By leveraging advanced technologies and
an integrated approach to well management,
operators can enhance production
resilience and safeguard the long-term
productivity of their assets.
❒
Editor's Note: This article was adapted
from " How are ESP-lifted Wells Affected
by Shut-ins for Offset Hydraulic Fracturing
Treatments? " a paper originally presented
at the Southwestern Petroleum Short
Course, which was held April 15-18 in
Lubbock, Tx.
ESP (FBHP=2441 psi)
95
50
95
PRESENT
Pr = 3,660 psi
GOR = 700 scf/bbl
MIDDLE
Pr = 3,160 psi
GOR = 700 scf/bbl
LATE
Pr = 2,660 psi
GOR = 1,400 scf/bbl
MARIAN
PEREZ SALAZAR
Marian Perez Salazar holds a B.S. in petroleum engineering from Texas Tech University.
During an internship with Diamondback Energy in the summer of 2023, she studied how
Midland Basin wells' production curves change after being shut in during nearby hydraulic
fracturing operations, tracking how location and artificial lift technique influence recovery
times. The previous summer, she interned at ProPetro Services Inc., gaining both field and
office experience with hydraulic fracturing, including a project related to dynamic gas
blending pumps.
JUNE 2024 55
Produced Liquid Rate (bbl/day)

American Oil and Gas Reporter - June 2024

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