Quantitative In Situ Enhanced Oil Recovery Monitoring Using Nuclear Magnetic Resonance

Mitchell, Jonathan; Staniland, J. R.; Chassagne, Romain; Fordham, E.J.

doi:10.1007/s11242-012-0019-8

Cited by 47 publications

(43 citation statements)

References 54 publications

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“…[5][6][7] In previous work, displacing phase injection was suspended to avoid fluid content change during lengthy MRI measurements. [8,9] However, the oil and water pore scale distribution may change when fluid injection is suspended. Very low flow rates may be employed, but very long experimental times result.…”

Section: Introductionmentioning

confidence: 99%

Monitoring oil displacement processes with k‐t accelerated spin echo SPI

Xiao

Romero‐Zerón

et al. 2015

Magnetic Reson in Chemistry

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Magnetic resonance imaging (MRI) is a robust tool to monitor oil displacement processes in porous media. Conventional MRI measurement times can be lengthy, which hinders monitoring time-dependent displacements. Knowledge of the oil and water microscopic distribution is important because their pore scale behavior reflects the oil trapping mechanisms. The oil and water pore scale distribution is reflected in the magnetic resonance T2 signal lifetime distribution. In this work, a pure phase-encoding MRI technique, spin echo SPI (SE-SPI), was employed to monitor oil displacement during water flooding and polymer flooding. A k-t acceleration method, with low-rank matrix completion, was employed to improve the temporal resolution of the SE-SPI MRI measurements. Comparison to conventional SE-SPI T2 mapping measurements revealed that the k-t accelerated measurement was more sensitive and provided higher-quality results. It was demonstrated that the k-t acceleration decreased the average measurement time from 66.7 to 20.3 min in this work. A perfluorinated oil, containing no (1) H, and H2 O brine were employed to distinguish oil and water phases in model flooding experiments. High-quality 1D water saturation profiles were acquired from the k-t accelerated SE-SPI measurements. Spatially and temporally resolved T2 distributions were extracted from the profile data. The shift in the (1) H T2 distribution of water in the pore space to longer lifetimes during water flooding and polymer flooding is consistent with increased water content in the pore space. Copyright © 2015 John Wiley & Sons, Ltd.

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Section: Introductionmentioning

confidence: 99%

Monitoring oil displacement processes with k‐t accelerated spin echo SPI

Xiao

Romero‐Zerón

et al. 2015

Magnetic Reson in Chemistry

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“…But these analog methods cannot give the actual CO 2 miscible performance in oilfields. Magnetic resonance imaging (MRI) 15,[24][25][26] and computed tomography (CT) scanning 13,27,28 have been recognized as effective approaches to measure the in-situ mixing zone characteristics at reservoir pressures and temperatures. These methods have solved visual condition restrictions at reservoir elevated pressures and high temperatures in porous media.…”

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confidence: 99%

Magnetic resonance imaging analysis on the in-situ mixing zone of CO2 miscible displacement flows in porous media

Song

Yang

Wang

et al. 2014

Journal of Applied Physics

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Experimental investigations of heterogeneous effect on supercritical pressure CO 2 and water flow in sintered porous media AIP Conf.The in-situ mixing zone represents dynamic characteristics of CO 2 miscible displacement flows, which is important for carbon dioxide enhanced oil recovery (CO 2 -EOR) projects. However, the migration characteristics of the in-situ mixing zone under reservoir conditions has been neither well studied nor fully understood. The in-situ mixing zone with the flowing mixture of supercritical CO 2 and n-decane (nC 10 ) was investigated by using a magnetic resonance imaging apparatus at a reservoir condition of 8.5 MPa and 37.8 C in porous media. The experimental results showed that the CO 2 -frontal velocity was larger than the mixing-frontal velocity. The mixing zone length was linearly declined in the miscible displacement process. And the declining rate of the mixing zone length was increased with injection rate. It indicates that the mixing zone length is not constant in a vertically stable CO 2 misible displacement and a volume contraction due to phase behavior effects may occur. Then, an error function based on the convection-dispersion equation was fitted with CO 2 miscible displacement experiments. The error function was well fitted both at a series of fixed core positions and a series of fixed displacement times. Furthermore, the longitudinal dispersion coefficients (K lx and K lt ) and the longitudinal Peclet numbers (Pe d and Pe L ) were quantified from the fitting results. The evolutions of the longitudinal dispersion coefficient were reduced along the displacement time. And the declining rate was increased with injection rate. And with proceeding, the longitudinal dispersion coefficient was tending towards stability and constant. But the evolutions of the longitudinal Peclet numbers were increased along the displacement time. And the increasing rate was increased with injection rate. V C 2014 AIP Publishing LLC.

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“…One such approach is the inversion-nulling method in which species can be differentiated from one another based on their T 1 as has been demonstrated by Hall and Rajanayagam (1987) for the imaging of oil and water in sandstones. Chemically specific images of oil and water have also been obtained from T 1 or T 2 maps by integrating the signal intensity across different ranges of the relaxation time spectrum and assigning to a particular fluid phase Mitchell et al 2012Mitchell et al , 2013b. Liu et al (2015) have also successfully demonstrated the identification of oil and brine in a rock during a core flood using spatially resolved D − T 2 imaging in one spatial dimension.…”

Section: Introductionmentioning

confidence: 99%

“…Whilst it is well known that, in principle, the signal intensity in a magnetic resonance experiment is proportional to the number of NMR-active species present, consideration must be given as to how the data are acquired and analysed depending on the methods used if the quantitative nature of the measurement is to be retained; examples of such work in the field of fluids in porous media include Mantle (2011), Mitchell et al (2012 and Li et al (2016). The challenge arises because signal attenuation occurs in the dead time between excitation and detection of the nuclear spins due to spin relaxation.…”

Section: Introductionmentioning

confidence: 99%

In Situ Chemically-Selective Monitoring of Multiphase Displacement Processes in a Carbonate Rock Using 3D Magnetic Resonance Imaging

et al. 2017

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Accurate monitoring of multiphase displacement processes is essential for the development, validation and benchmarking of numerical models used for reservoir simulation and for asset characterization. Here we demonstrate the first application of a chemicallyselective 3D magnetic resonance imaging (MRI) technique which provides high-temporal resolution, quantitative, spatially resolved information of oil and water saturations during a dynamic imbibition core flood experiment in an Estaillades carbonate rock. Firstly, the relative saturations of dodecane (S o ) and water (S w ), as determined from the MRI measurements, have been benchmarked against those obtained from nuclear magnetic resonance (NMR) spectroscopy and volumetric analysis of the core flood effluent. Excellent agreement between both the NMR and MRI determinations of S o and S w was obtained. These values were in agreement to 4 and 9% of the values determined by volumetric analysis, with absolute errors in the measurement of saturation determined by NMR and MRI being 0.04 or less over the range of relative saturations investigated. The chemically-selective 3D MRI method was subsequently applied to monitor the displacement of dodecane in the core plug sample by water under continuous flow conditions at an interstitial velocity of 1.27 × 10 −6 m s −1 (0.4 ft day −1 ). During the core flood, independent images of water and oil distributions within the rock core plug at a spatial resolution of 0.31 mm × 0.39 mm × 0.39 mm were acquired on a timescale of 16 min per image. Using this technique the spatial and temporal dynamics of the displacement process have been monitored. This MRI technique will provide insights to structure-transport relationships associated with multiphase displacement processes in complex porous materials, such as those encountered in petrophysics research.

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Quantitative In Situ Enhanced Oil Recovery Monitoring Using Nuclear Magnetic Resonance

Cited by 47 publications

References 54 publications

Monitoring oil displacement processes with k‐t accelerated spin echo SPI

Monitoring oil displacement processes with k‐t accelerated spin echo SPI

Magnetic resonance imaging analysis on the in-situ mixing zone of CO2 miscible displacement flows in porous media

In Situ Chemically-Selective Monitoring of Multiphase Displacement Processes in a Carbonate Rock Using 3D Magnetic Resonance Imaging

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