American Oil and Gas Reporter - December 2015 - 72

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SpecialReport: Well Stimulation & Completion Technology
FIGURE 7
Pressure-Time Grid Display
From Multiwell 3-D DFN Planar Fracture Model

A

B

C

Pressure (psi)
3,000

PAOLO GROSSI is a geologist on the
Eagle Ford asset team at Talisman Energy USA Inc., a part of Repsol. Grossi
is part of a multidisciplinary team responsible for developing approximately
60,000 net acres of Talisman (Repsol)operated Eagle Ford assets in La Salle
and McMullen counties. He began his
career with Talisman Energy in Calgary
in 2007, and his professional focus has
been on the exploration, appraisal and
development of unconventional resources,
including deep basin tight gas in Canada,
as well as U.S. and international oil
and gas shale projects. Grossi holds a
B.S. in petroleum geology from the University of Calgary.

72 THE AMERICAN OIL & GAS REPORTER

8,000

DEVERY NEUMANN is a development
specialist at Talisman Energy USA, a
part of Repsol, where he leads a multidisciplinary asset team to develop the
company's Eagle Ford acreage. He began
his career in 2003 as a development
technologist at Talisman Energy, serving
for five years before joining Second Wave
Petroleum Inc., a junior oil and gas company operating in western Canada, as
vice president of operations. Neumann
rejoined Talisman Energy in his current
position in 2012. He holds a diploma in
mechanical engineering from the Northern
Alberta Institute of Technology.

upper and lower target wells (Figure 6).
Decline rates and drawdown are stable
and the average yearly decline rates are
estimated at 55-65 percent.
Of the two pads, pad 2 is displaying
better early-time productivity, interpreted
to be associated with the completion design. Both pads also are producing well
above expected condensate rates, with
condensate-to-gas ratios averaging 218
bbl/MMcf compared with 180 bbl/MMcf
for direct offsets and a computed field
average of 85 bbl/MMcf.

Improved Recovery Factor
DCA and RTA estimates indicate a
fourfold improvement in recovery factor
compared with the field average, assuming
similar area assumptions. Completion optimization yielding 185-foot staggered
well spacing (370-foot single zone spacing), as indicated by microseismic on
pad 2, would see an additional threefold
(seven times the field average) potential
improvement.
Future expected production behavior
was further investigated utilizing a multiwell 3-D DFN planar fracture model in
a commercial simulation software package.
The assumptions of the model included
two phase flow (gas and condensate),
pressure-dependent fracture permeability
through time, and no direct fracture communication (each well has independent
SRVs) with interwell communication
only being possible through the matrix.
A base-case model run was used to
gain insight into what the authors believe
is a representative drainage scenario: 200foot xf, 100-foot height and km of 80
nanodarcies in the x and y directions,
and 0.1 km in the z direction within a 20FARSHAD LALEHROKH is a senior
reservoir engineer at Talisman Energy
USA, a part of Repsol. He previously
worked as a consultant and reservoir
engineering team lead at Weatherford,
where he was involved in well performance analysis and type curve workflows,
reservoir modeling and characterization,
well spacing and completion optimization,
fracture modeling and field development
planning. Lalehrokh also has been involved with cutting-edge techniques to
model horizontal wells with multiple
transverse fractures in unconventional
reservoirs. He holds an M.S. and a
Ph.D. in petroleum engineering from
the University of Texas at Austin.
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