American Oil and Gas Reporter - June 2022 - 66

SpecialReport: Permian Comeback Kings
partially explain why Stage 18 received
more proppant than Stage 16, but it experienced
less fracture extension as the
BHP built up.
The analysis indicates larger fracture
aperture reduction and possible productivity
decay in extended stages with more PCs
per stage after seven months of production.
This may be attributable to the low SDE
during the treatment of extended stages,
where the calculated proppant distribution
metric appears to be below 0.2.
Key Conclusions
The project's workflow quantitatively
evaluated SDE for different completion
designs using diagnostic results and could
help optimize completion strategy for future
development projects. The analysis
and interpretation of results demonstrate
the technical feasibility of using permanent
FO cable for stimulation and production
monitoring and indicate a strong correlation
between proppant/fluid allocation
and time-lapse near-wellbore fracture
property changes.
Among the key conclusions of the
study are:
· Even distribution of proppant and
fluid was best achieved with geometric
PC schemes that targeted 2.5-3.0 barrels
per minute/perf and 10.0-12.5 bpm/PC.
· Based on the statistical analysis of
hydraulic fracturing profiles with effective
limited entry practices, RPC during proppant
slurry placement appears to be a primary
completion design variable rather
than the typical default consideration, RPP.
· If RPC is not maintained above 10
bpm/PC, the likelihood of uneven distribution
increases dramatically. The stage
configurations that created low RPC while
they maintained high RPP did not show
improved SDE.
· All stages on the Boxwood-3H and
4H wells were treated with an average
rate of 60-70 bpm, regardless of PC
count. Higher RPC values (10.0-12.5
bpm/PC) may help improve SDE, especially
for extended stages.
· No obvious effect of tapered PC
schemes or perforation orientation/phasing
was observed during the treatment of the
Boxwood-3H and 4H.
· Based on near-field DAS/DTS data,
completion operational issues (such as
poor cement bonding behind casing, midstage
shutdowns and plug failures) add
the risk of degradation of SDE.
66 THE AMERICAN OIL & GAS REPORTER
· The strain change results based on
DSS data acquired during production
clearly indicate near-wellbore fracture
property changes (such as aperture changes
during well shut-in and flow periods)
and align with near-wellbore DAS signals
acquired during stimulation.
· Fracture property changes based
on DSS data acquired during two tests
seven months apart showed high consistency
and good alignment with near-wellbore
hydraulic fracturing profiles. ❒
Editor's Note: The preceding is the
second in a two-part article on a completion
design study at the HFTS-2. Part I
NANCY ZAKHOUR is a business
development manager with Oxy Low
Carbon Ventures. Previously, she was
a Permian Basin well design lead at
Occidental, managing drilling, completion,
and production engineering
design and optimization. Zakhour
chaired the HFTS-2 completion engineering
subcommittee. Prior to that,
she was a completion engineering adviser.
Before joining Occidental, Zakhour
was Callon Petroleum's completion engineering
adviser and served in technical
and field operational roles at Schlumberger.
A recipient of the SPE Regional
Completions Optimization & Technology
Award, she holds a B.S. in electrical
and computer engineering from the
American University of Beirut and an
MBA from Rice University.
MATT JONES is member of Occidental's
unconventional reservoir stimulation
design team, focusing on fracture modeling
and field development. From 2014 to
2019, he served at Anadarko first as a
production engineer in the Eagle Ford
and then as a completions engineer in
the Delaware Basin. When Occidental
acquired Anadarko in 2019, Jones transitioned
to completions engineering supervisor
for the Delaware Basin asset.
He also has served as a completions engineering
adviser for Occidental's worldwide
drilling & completions team. Jones
holds a B.S. in petroleum engineering
from Texas A&M University.
YU ZHAO is a reservoir engineer at
Occidental, where he mainly conducts
appeared in AOGR's May issue.
This material is based on work supported
by the U.S. Department of Energy
under Award Number DE-FE0031577.
For more detailed information on the results,
see URTeC 5242, a technical paper
prepared for presentation at the 2021 Unconventional
Resources Technology Conference,
held July 26-28 in Houston.
The authors thank Richard Sullivan,
Robert Anderson, Vikram Sen and Alan
Reynolds for their diligence in planning
and executing this project, and thank all
field personnel and vendors who ensured
efficient operational execution and data
acquisition of the rich dataset.
integrated unconventional simulation to
support primary and EOR development
in the Delaware and Midland basins.
He also evaluates new unconventional
technology for practical applications,
and has extensive interests and experience
in fiber optic data analysis and interpretation.
Zhao is a technical reviewer
for " SPE Journal, " " SPE Reservoir
Evaluation & Engineering, " and " Journal
of Petroleum Science & Engineering. "
He holds a Ph.D. in petroleum engineering
from the University of Tulsa.
KATE ORSINI is a production engineer
at Oxy. Since joining the company
in 2019, she has worked in the Delaware
Basin in Loving and Reeves County,
Tx., focusing on production optimization,
artificial lift design, and well stimulation
and remediation. Orsini holds a B.S.
in petroleum engineering from The University
of Texas at Austin.
VINAY SAHNI works for Oxy's Permian
EOR business to develop field
development plans for carbon capture,
utilization and storage/carbon capture
and sequestration projects. Permian
EOR development responsibilities also
include longer-term planning and portfolio
optimization via acquisitions and
trades. Sahni previously provided technical
support to help optimize primary
and EOR development plans for Occidental's
unconventional resources business
units. Sahni holds a B.S. in petroleum
engineering from Pune University
and an M.S. in petroleum engineering
from the University of Texas at Austin.
American Oil and Gas Reporter - June 2022

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