Streaming potentials at hydrocarbon reservoir conditions

Saunders, J. H.; Jackson, Matthew D.; Gulamali, M. Y.; Vinogradov, Jan; Pain, Christopher C.

doi:10.1190/geo2011-0068.1

Cited by 29 publications

(35 citation statements)

References 42 publications

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“…When a second fluid phase is present in the pore space, the magnitude of the streaming potential coupling coefficient becomes dependent on a number of factors including the wettability of the rock, the composition of the pore fluids, and the saturation of each phase Saunders et al, 2012). According to Saunders et al (2012), in the simplest case, the nonwetting phase is nonpolar and its flux causes no streaming current.…”

Section: The Helmholtz-smoluchowski Equation In the Steady Statementioning

confidence: 99%

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Geophysical Properties of the Near Surface Earth: Electrical Properties

Glover

2015

Treatise on Geophysics

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113

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Section: The Helmholtz-smoluchowski Equation In the Steady Statementioning

confidence: 99%

“…A number of relative streaming potential coefficient functions C i have been proposed Saunders et al, 2012), three of which are given in Figure 27. A number of relative streaming potential coefficient functions C i have been proposed Saunders et al, 2012), three of which are given in Figure 27.…”

Section: The Helmholtz-smoluchowski Equation In the Steady Statementioning

confidence: 99%

Geophysical Properties of the Near Surface Earth: Electrical Properties

Glover

2015

Treatise on Geophysics

121

113

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“…The best productivity occurs in the location with the highest microseismic activity. (b) Exploring the potential use of spontaneous potential to detect water encroachment (from Saunders et al 2012). The two plots represent results from a simulation of a heterogeneous reservoir model at two different times, showing water moving towards a horizontal well.…”

Section: Discussionmentioning

confidence: 99%

“…As water approaches the well (high saturation in the lower plot), but is still several tens of metres away, the SP signal increases (lower plot). Modelling and experiments by Saunders et al (2012) suggest that this method can be used for several monitoring objectives, including: early detection of a waterfront approaching a well; mapping a moving waterfront from multiple wells; identifying and tracking injected fluids during EOR processes and monitoring steam flooding.…”

Section: Discussionmentioning

confidence: 99%

Fundamental controls on fluid flow in carbonates: current workflows to emerging technologies

Agar

Geiger

2014

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The introduction reviews topics relevant to the fundamental controls on fluid flow in carbonate reservoirs and to the prediction of reservoir performance. The review provides research and industry contexts for papers in this volume only. A discussion of global context and frameworks emphasizes the value yet to be captured from compare and contrast studies. Multidisciplinary efforts highlight the importance of greater integration of sedimentology, diagenesis and structural geology. Developments in analytical and experimental methods, stimulated by advances in the materials sciences, support new insights into fundamental (pore-scale) processes in carbonate rocks. Subsurface imaging methods relevant to the delineation of heterogeneities in carbonates highlight techniques that serve to decrease the gap between seismically resolvable features and well-scale measurements. Methods to fuse geological information across scales are advancing through multiscale integration and proxies. A surge in computational power over the last two decades has been accompanied by developments in computational methods and algorithms. Developments related to visualization and data interaction support stronger geoscience-engineering collaborations. High-resolution and real-time monitoring of the subsurface are driving novel sensing capabilities and growing interest in data mining and analytics. Together, these offer an exciting opportunity to learn more about the fundamental fluid-flow processes in carbonate reservoirs at the interwell scale.

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“…Recent theoretical and experimental studies found that considerable signals of streaming potential, which respond to approaching water, are detectable in a production well, and the investigation distance ranges from tens of meters up to a few hundred meters (Vinogradov and Jackson, 2011). However, the measured magnitude is limited by the production rate, formation water salinity, and coupling coefficient between fluids and electric potential, among which the latter two are poorly understood (Saunders et al, 2012). These reservoir imaging techniques, even though some of them are under development, are suited only for large-scale (tens to hundreds of meters) water flooding monitoring with a low-resolution requirement.…”

Section: Introductionmentioning

confidence: 99%

Reservoir monitoring using borehole radars to improve oil recovery: Suggestions from 3D electromagnetic and fluid modeling

et al. 2018

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The recently developed smart well technology allows for sectionalized production control by means of downhole inflow control valves and monitoring devices. We consider borehole radars as permanently installed downhole sensors to monitor fluid evolution in reservoirs, and it provides the possibility to support a proactive control for smart well production. To investigate the potential of borehole radar on monitoring reservoirs, we establish a 3D numerical model by coupling electromagnetic propagation and multiphase flow modeling in a bottom-water drive reservoir environment. Simulation results indicate that time-lapse downhole radar measurements can capture the evolution of water and oil distributions in the proximity (order of meters) of a production well, and reservoir imaging with an array of downhole radars successfully reconstructs the profile of a flowing water front. With the information of reservoir dynamics, a proactive control procedure with smart well production is conducted. This method observably delays the water breakthrough and extends the water-free recovery period. To assess the potential benefits that borehole radar brings to hydrocarbon recovery, three production strategies are simulated in a thin oil rim reservoir scenario, i.e., a conventional well production, a reactive production, and a combined production supported by borehole radar monitoring. Relative to the reactive strategy, the combined strategy further reduces cumulative water production by 66.89%, 1.75%, and 0.45% whereas it increases cumulative oil production by 4.76%, 0.57%, and 0.31%, in the production periods of 1 year, 5 years, and 10 years, respectively. The quantitative comparisons reflect that the combined production strategy has the capability of accelerating oil production and suppressing water production, especially in the early stage of production. We suggest that borehole radar is a promising reservoir monitoring technology, and it has the potential to improve oil recovery efficiency.

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Streaming potentials at hydrocarbon reservoir conditions

Cited by 29 publications

References 42 publications

Geophysical Properties of the Near Surface Earth: Electrical Properties

Geophysical Properties of the Near Surface Earth: Electrical Properties

Fundamental controls on fluid flow in carbonates: current workflows to emerging technologies

Reservoir monitoring using borehole radars to improve oil recovery: Suggestions from 3D electromagnetic and fluid modeling

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