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SUMMARY:The influence of Capillary Trapping on Dynamic CO2 Storage Capacit
y and Long Term Storage Integrity
DTSTART;VALUE=DATE-TIME:20180515T163500Z
DTEND;VALUE=DATE-TIME:20180515T165000Z
DTSTAMP;VALUE=DATE-TIME:20220119T004439Z
UID:indico-contribution-144-616@events.interpore.org
DESCRIPTION:Speakers: Muhammad Zulqarnain (Louisiana State University)\nCo
ntainment of injected CO2 is of prime importance for long term integrity o
f CO2 geological storage projects. Structural/stratigraphic\, dissolution\
, residual\, capillary and mineral trapping mechanisms play significant ro
les on different time scales to keep the injected CO2 within the storage z
one boundaries. In heterogeneous media the impact of capillary trapping me
chanism becomes significant. Overlooking the capillary trapping contributi
on may result in underestimating the dynamic storage capacity\, and overes
timating the leakage risk. In this study the significance of capillary tra
pping mechanism for a heterogeneous storage zone is highlighted. Publicall
y available well log and petrophysical data is used to construct a represe
ntative model of a 1\,000 ft thick storage zone in Louisiana\, USA. This z
one has significant locally interbedded sand and shale intervals that are
not continuous over the entire areal extent of the zone. Reservoir simulat
ion is used to model different injection scenarios and resultant movement
of CO2 plume. The CO2 is injected for a period of 50 years and then monito
red for additional 50 years for its plume movement. In order to capture th
e contribution of capillary trapping\, the capillary pressure for each gri
d block is scaled by its porosity and permeability values. Therefore each
grid block have its own capillary pressure curve\, in comparison to a case
in which a single capillary pressure curve is used for the entire storage
zone. Sensitivity analysis shows that the upward movement of buoyant CO2
plume is substantially impeded by the capillary forces when separate capil
lary pressure curve is used for each grid block that honors the permeabili
ty and porosity of respective block. This results in significant local cap
illary trapping. This phenomenon has significant implications for dynamic
storage capacity and long term stability of CO2 plume. For the studied cas
e\, it is observed that capillary trapping mechanism results in enhancing
the dynamic storage capacity by a factor of nearly 1.5. It is also observe
d that the capillary trapping also effects the lateral movement of CO2 plu
me and CO2 is contained in the storage zone more effectively. The results
strongly suggests that for heterogeneous storage zones\, ignoring the capi
llary trapping mechanism can result in significant errors in determining d
ynamic storage capacity and long term storage integrity.\n\nhttps://events
.interpore.org/event/2/contributions/616/
LOCATION:New Orleans
URL:https://events.interpore.org/event/2/contributions/616/
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SUMMARY:Multiresolution Operator Decomposition for Flow Simulation in Frac
tured Porous Media
DTSTART;VALUE=DATE-TIME:20180515T161700Z
DTEND;VALUE=DATE-TIME:20180515T163200Z
DTSTAMP;VALUE=DATE-TIME:20220119T004439Z
UID:indico-contribution-144-614@events.interpore.org
DESCRIPTION:Speakers: Qingfu Zhang (China University of Petroleum (East Ch
ina))\nFractures should be simulated accurately given their significant ef
fects on whole flow patterns in porous media. But such high-resolution sim
ulation imposes severe computational challenges to numerical methods in th
e applications. Therefore\, the demand for accurate and efficient techniqu
e is widely increasing. A near-linear complexity multiresolution decomposi
tion is proposed for solving flow problems in fractured porous media. In t
his work\, discrete fracture model (DFM) is used to describe fractures\, i
n which the fractures are explicitly represented as (n-1) dimensional elem
ent. The solution space is decomposed into several subspaces and we then c
ompute the corresponding solutions of DFM in each subspace. The pressure d
istribution of fractured porous media is obtained by combing the DFM solut
ions of all subspaces. Numerical results are presented to demonstrate the
accuracy and efficiency of the proposed multigrid method. The comparisons
with standard method show that the proposed multigrid method is a promisin
g method for flow simulation in fractured porous media.\n\nhttps://events.
interpore.org/event/2/contributions/614/
LOCATION:New Orleans
URL:https://events.interpore.org/event/2/contributions/614/
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SUMMARY:Adaptive Online Multiscale Model Reduction for Heterogeneous Probl
ems in Perforated Domains
DTSTART;VALUE=DATE-TIME:20180515T171100Z
DTEND;VALUE=DATE-TIME:20180515T172600Z
DTSTAMP;VALUE=DATE-TIME:20220119T004439Z
UID:indico-contribution-144-611@events.interpore.org
DESCRIPTION:Speakers: Yating Wang (Texas A&M University)\nIn this work\, w
e develop and analyze an adaptive multiscale approach for Stokes problems
in heterogeneous perforated domains. In many applications\, these problems
have a multiscale nature arising because of the perforations\, their geom
etries\, the sizes of the perforations\, and configurations. Typical model
ing approaches extract average properties in each coarse region\, that enc
apsulate many perforations\, and formulate a coarse-grid problem. In some
applications\,the coarse-grid problem can have a different form from the f
ine-scale problem\, e.g.\, the coarse-grid system corresponding to a Stoke
s system in perforated domains leads to Darcy equations on a coarse grid.
In this work\, we present a general offline/online procedure\, which can a
dequately and adaptively represent the local degrees of freedom and derive
appropriate coarse-grid equations. Our approaches start with the offline
procedure\, which constructs multiscale basis functions in each coarse reg
ion and formulates coarse-grid equations. We then develop an adaptive stra
tegy in the online procedure\, which allows adaptively incorporating globa
l information and is important for a fast convergence. We present online a
daptive enrichment algorithms for the three model problems mentioned above
. Our methodology allows adding and guides constructing new online multisc
ale basis functions adaptively in appropriate regions. We present the conv
ergence analysis of the online adaptive enrichment algorithm for the Stoke
s system. In particular\, we show that the online procedure has a rapid co
nvergence with a rate related to the number of offline basis functions\, a
nd one can obtain fast convergence by a sufficient number of offline basis
functions\, which are computed in the offline stage. To illustrate the pe
rformance of our method\, we present numerical results with both small and
large perforations. We see that only a few (1 or 2) online iterations can
significantly\nimprove the offline solution.\n\nhttps://events.interpore.
org/event/2/contributions/611/
LOCATION:New Orleans
URL:https://events.interpore.org/event/2/contributions/611/
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SUMMARY:A novel transient diffuse source algorithm for multiscale simulati
on in porous media
DTSTART;VALUE=DATE-TIME:20180515T165300Z
DTEND;VALUE=DATE-TIME:20180515T170800Z
DTSTAMP;VALUE=DATE-TIME:20220119T004439Z
UID:indico-contribution-144-613@events.interpore.org
DESCRIPTION:Speakers: Krishna Nunna (Texas A&M University)\nFluid flow in
porous media occurs on varied scales from pore to reservoir\, where the fi
ne scale heterogeneity may have a significant impact on large scale fluid
flow. Resolving all pertinent scales in modeling and flow simulation is an
arduous task limited by the availability of data and computational resour
ces. Therefore\, it is customary to use an upscaling procedure\, in which
the fine scale reservoir properties are represented on the coarse scale by
some kind of averaging procedure. Existing local upscaling methods rely o
n steady state incompressible flow\, which fail to capture transient multi
scale effects. Particularly\, they cannot preserve the dynamic connectivit
y while coarsening between multiple scales. This results in overly homogen
ized simulation models with systematically biased results. This same bias
can be observed in multiscale flow simulation where large scale changes in
pressure are resolved on the coarse scale\, and multiphase fluid transpor
t simulation is performed on the fine scale using a subgrid velocity field
generated from the coarse problem. This precludes the need to upscale sat
urations and relative permeability which are highly non-linear and strongl
y dependent upon flow history. The current work combines the upscaling of
pressure with multiscale multiphase simulation to generate high resolution
velocity fields that capture the subgrid heterogeneity\, fluid compressib
ility\, and multiphase flow.\n\nThe upscaling step draws upon its similari
ty to pressure transient well testing concepts to set up local flow proble
ms. Instead of a wellbore\, each local problem is performed from a coarse
cell face. This enables us to distinguish between well-connected and weakl
y connected pay while upscaling. This approach is similar to the multiscal
e mixed finite element literature where we have a basis function for a coa
rse face. After upscaling\, superposition principle allows us to downscale
the coarse flow\, generating the fine scale velocity field. Finally\, the
transport problem is solved on the fine scale giving fluid saturations.\n
\nThe proposed method is validated on the high contrast SPE10 synthetic mo
del with over 8 orders magnitude variance in permeability\, and demonstrat
ed on a full field tight gas reservoir model.\n\nhttps://events.interpore.
org/event/2/contributions/613/
LOCATION:New Orleans
URL:https://events.interpore.org/event/2/contributions/613/
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