NMR derived water content from high magnetic susceptibility rock cuttings

Carroll, Matthew R J; O’Neill, Keelan; Bristow, Nicholas W.; Hopper, Tim; Vogt, Sarah J.; Johns, Michael L.; Fridjonsson, Einar O.

doi:10.1016/j.mineng.2018.03.038

Cited by 10 publications

(3 citation statements)

References 27 publications

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“…Hence, it was possible that the mineralogy of the soil particles affected this trend. Carroll et al tested water-saturated synthetic samples (magnetite/maghemite/hematite mixed with borosilicate glass beads) as a function of iron content and showed a standard error of estimated water content of 6.4 wt %. Keating and Knight tested 1.4 wt % Fe synthetic magnetite samples at the highest concentrations and showed that diffusion relaxation significantly contributes to the overall relaxation rate.…”

Section: Results and Discussionmentioning

confidence: 99%

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Permeability Measurement and Prediction with Nuclear Magnetic Resonance Analysis of Gas Hydrate-Bearing Sediments Recovered from Alaska North Slope 2018 Hydrate-01 Stratigraphic Test Well

et al. 2022

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Permeability of porous media, such as oil and gas reservoirs, is the crucial material parameter for predicting their hydraulic behavior. A nuclear magnetic resonance (NMR) analyzer is widely used as a powerful tool to predict permeability of various media. NMR T 2 (transverse or spin−spin) relaxation time distribution, which is related to pore size distribution, gives the information to allow calculation of effective (initial) permeability. In this study, we investigate effective, intrinsic (absolute), and relative water and gas permeabilities of hydrate-bearing pressure core samples. These samples were recovered from the Alaska North Slope 2018 Hydrate-01 Stratigraphic Test Well by sidewall pressure coring and then analyzed in a laboratory using both fluid flow test and NMR analyzer. The peak of the NMR T 2 distribution was measured at 10−20 ms using a laboratory NMR analyzer, which compares well with in situ measurements obtained via logging while drilling NMR data for two samples with high gas hydrate saturations (S h = 76% and 74%). Further, comparison of laboratory NMR T 2 distribution after hydrate dissociation revealed that the hydrate existed in large pore spaces. Effective permeabilities predicted by the Timur-Coates (TC) model and the Schlumberger-Doll-Research (SDR) model, with T 2 cutoff 33 ms, were about an order of magnitude less than the laboratory measured values. Alternative TC model-based calculations with the T 2 cutoff reduced to 10 ms and a newly developed hydraulic radius model better matched the laboratory data. For the analysis of the intrinsic permeabilities, the TC model with a T 2 cutoff of 33 ms and SDR model were greater than the laboratory derived values, while the hydraulic radius model more closely matched the laboratory-derived values. In addition, permeability measurements were also made relative to gas and water under constant three-phase flow (water−gas−hydrate) conditions. After hydrate dissociation, a relative permeability curve was developed for each of the analyzed core samples based on the Corey petrophysical model. The results indicate that the gas permeability changed rapidly at high water saturation around 90%. Thus, we infer that the selection of relative reservoir parameters should focus on the higher water saturation conditions.

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Section: Results and Discussionmentioning

confidence: 99%

“…NMR analysis can guarantee the accuracy described above for capturing water contents. However, we should note that the presence of magnetic materials (e.g., iron, nickel, and chromium) increases the T 2 relaxation rate and decreases the magnitude of the NMR signal. − …”

Section: Methodsmentioning

confidence: 99%

Permeability Measurement and Prediction with Nuclear Magnetic Resonance Analysis of Gas Hydrate-Bearing Sediments Recovered from Alaska North Slope 2018 Hydrate-01 Stratigraphic Test Well

et al. 2022

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“…The accurate estimation of these two parameters is essential for the petrophysical characterization of porous rocks, reservoir evaluations, and productivity predictions in hydrocarbon exploration and development (Dunn et al, 2002;Testamanti & Rezaee, 2017;Zheng et al, 2019). Nuclear magnetic resonance (NMR) is an effective technique that has been widely used to investigate the properties of porous media (Carroll et al, 2018;Chen et al, 2011;Fridjonsson et al, 2013;Ge et al, 2018;Song & Kausik, 2019;Xiao & Balcom, 2019). An inversion process is typically required to determine the transverse relaxation time (T 2 ) distribution from the echo data acquired by NMR measurements (Gruber, Venkataramanan, Habashy, Singer, & Freed, 2013;Guo et al, 2018).…”

Section: Introductionmentioning

confidence: 99%

Nuclear Magnetic Resonance Characterization of Petrophysical Properties in Tight Sandstone Reservoirs

2020

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Permeability and bound water saturation (Swb) are key parameters reflecting the petrophysical properties of porous rocks. Nuclear magnetic resonance (NMR) has proved to be effective in investigating the properties of porous media. However, estimating Swb and the permeability in tight sandstone reservoirs based on conventional NMR methods, which requires the inversion of NMR echo data to obtain the transverse relaxation time (T2) distribution, proves to be a challenging task. In this study, a method is proposed to estimate Swb and the permeability in tight sandstone reservoirs based on the direct analysis of NMR echo data, thus avoiding the inversion process. A total of 20 tight sandstone samples from the Ordos Basin in China was taken for laboratory NMR measurements. The kernel function of the echo data was used to characterize the ratio distribution of bound water volume to pore volume for different pore sizes. Following this, an echo data calibration method was applied to estimate Swb without the inversion of the T2 distribution, and the window method was used to reduce the impact of noise in the echo data. Furthermore, models for estimating permeability were proposed based on the determined windows of the NMR echo data in the Swb estimation. The reliability of the proposed method for estimating Swb and permeability was verified by comparing the estimated and experimental results. Our study provides an efficient method for the estimation of petrophysical parameters in porous rocks based on the direct analysis of NMR echo data.

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Monitoring Lithology Variations in Drilled Rock Formations Using NMR Apparent Magnetic Susceptibility Contrast

Mitchell

2020

Appl Magn Reson

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NMR derived water content from high magnetic susceptibility rock cuttings

Cited by 10 publications

References 27 publications

Permeability Measurement and Prediction with Nuclear Magnetic Resonance Analysis of Gas Hydrate-Bearing Sediments Recovered from Alaska North Slope 2018 Hydrate-01 Stratigraphic Test Well

Permeability Measurement and Prediction with Nuclear Magnetic Resonance Analysis of Gas Hydrate-Bearing Sediments Recovered from Alaska North Slope 2018 Hydrate-01 Stratigraphic Test Well

Nuclear Magnetic Resonance Characterization of Petrophysical Properties in Tight Sandstone Reservoirs

Monitoring Lithology Variations in Drilled Rock Formations Using NMR Apparent Magnetic Susceptibility Contrast

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