Quantitative 1D saturation profiles on chalk by NMR

Olsen, Dan; Topp, Simon; Stensgaard, Anders; Nørgaard, J.V.; Reffstrup, Jan

doi:10.1016/s0730-725x(96)00214-7

Cited by 9 publications

(9 citation statements)

References 3 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…These properties were also measured in several slices along the core (1‐D saturation profiles, see e.g., Olsen et al . [] and Chen et al . []): the thickness of these slices depends on the system properties and has been estimated to 4.9 mm using the following formula [ McRobbie et al ., ]:

T h i c k n e s s = \frac{R F b a n d w i d t h}{γ * G}

, where

R F b a n d w i d t h

is the radiofrequency pulse bandwidth (Hz),

γ

is the gyromagnetic ratio of hydrogen atom (42.58 MHz/T after Mohr et al .…”

Section: Methodsmentioning

confidence: 99%

Two‐phase flow properties of a sandstone rock for the CO₂/water system: Core‐flooding experiments, and focus on impacts of mineralogical changes

Manceau

Ma²,

Li³

et al. 2015

Water Resources Research

View full text Add to dashboard Cite

The two-phase flow characterization (CO 2 /water) of a Triassic sandstone core from the Paris Basin, France, is reported in this paper. Absolute properties (porosity and water permeability), capillary pressure, relative permeability with hysteresis between drainage and imbibition, and residual trapping capacities have been assessed at 9 MPa pore pressure and 28 C (CO 2 in liquid state) using a single core-flooding apparatus associated with magnetic resonance imaging. Different methodologies have been followed to obtain a data set of flow properties to be upscaled and used in large-scale CO 2 geological storage evolution modeling tools. The measurements are consistent with the properties of well-sorted water-wet porous systems. As the mineralogical investigations showed a nonnegligible proportion of carbonates in the core, the experimental protocol was designed to observe potential impacts on flow properties of mineralogical changes. The magnetic resonance scanning and mineralogical observations indicate mineral dissolution during the experimental campaign, and the core-flooding results show an increase in porosity and water absolute permeability. The changes in two-phase flow properties appear coherent with the pore structure modifications induced by the carbonates dissolution but the changes in relative permeability could also be explained by a potential increase of the water-wet character of the core. Further investigations on the impacts of mineral changes are required with other reactive formation rocks, especially carbonate-rich ones, because the implications can be significant both for the validity of laboratory measurements and for the outcomes of in situ operations modeling.

show abstract

T h i c k n e s s = \frac{R F b a n d w i d t h}{γ * G}

, where

R F b a n d w i d t h

is the radiofrequency pulse bandwidth (Hz),

γ

is the gyromagnetic ratio of hydrogen atom (42.58 MHz/T after Mohr et al .…”

Section: Methodsmentioning

confidence: 99%

Two‐phase flow properties of a sandstone rock for the CO₂/water system: Core‐flooding experiments, and focus on impacts of mineralogical changes

Manceau

Ma²,

Li³

et al. 2015

Water Resources Research

View full text Add to dashboard Cite

show abstract

“…Bi-exponential or stretched exponential models are commonly necessary to produce reliable models, 10,11 but a cleaned chalk sample, like the actual sample, is usually confidently modelled by a single-exponential model. [12][13][14] In the present work single-exponential modelling is used, i.e. (Fig.…”

Section: Spe 63226mentioning

confidence: 99%

Imbibition Processes in Fractured Chalk Core Plugs with Connate Water Mobilization

Nielsen

Olsen

Bech

2000

Proceedings of SPE Annual Technical Conference and Exhibition

View full text Add to dashboard Cite

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractA displacement process in a chalk core plug with an induced axial fracture uses the fluid system H 2 O-D 2 O-n-decane. Initially the plug contains a mixture of D 2 O and n-decane with oil saturation equal to 88 %. The plug is flooded with H 2 O. The displacement process is monitored by NMR with a chemical shift technique enabling spatial resolution of the H 2 O and oil signals. The D 2 O component is not directly detected, but is calculated from the difference between the actual signal intensities and the signal intensities in a situation where the pore space is completely saturated with H 2 O and oil.H 2 O-D 2 O-oil constitutes a partly miscible fluid system which is an analogy to the injection water-formation water-oil system of a hydrocarbon reservoir under waterflooding.The injected H 2 O traverses the sample as a well-defined front together with capillary uptake from the fracture plane. Ahead of the H 2 O front the D 2 O of the sample is mobilized and travels as a bank in front of the H 2 O. Though the initial concentration of D 2 O is only 12 % the D 2 O concentration reaches 50 % at the bank.The experiment was simulated by means of ECLIPSE with a fair match of the displacement process.The injected H 2 O has only made limited contact with the produced oil of the sample. In case of chemical EOR processes connected to waterflooding of hydrocarbon reservoirs a similar displacement situation could seriously affect the efficiency of the EOR process.

show abstract

“…A one-dimensional ͑1D͒ nuclear magnetic resonance ͑NMR͒ imaging technique is used for quantification of the fluid distribution. 15 This technique is restricted to rocks with NMR spin-spin relaxation constants above approximately 6 ms, encompassing many types of limestone, but excluding nearly all types of sandstone. Fortunately, the computational method is not dependent on a specific technique for quantifying the fluid distribution.…”

Section: Experimental Techniquementioning

confidence: 99%

“…The material used in the experimental work is chalk of Maastrichtian age from the Dan field in the Danish sector of the North Sea known to comply with the NMR requirements. 15 Results are presented for two samples. Both are cylindrical 38 mm plug samples, drilled with the cylinder axis parallel to any visible bedding or layering, to minimize effects of sample inhomogeneity on the flooding experiments.…”

Section: Sample Materialmentioning

confidence: 99%

See 1 more Smart Citation

Determination of Oil/Water Saturation Functions of Chalk Core Plugs From Two-Phase Flow Experiments

Bech

Olsen

Nielsen

2000

SPE Reservoir Evaluation &Amp; Engineering

Self Cite

View full text Add to dashboard Cite

A new procedure for obtaining oil/water saturation functions, i.e., capillary pressure and relative permeability, of tight core samples uses the pronounced end effect present in flooding experiments on such material. In core material with high capillary pressure, the end effect may allow determination of the saturation functions for a broad saturation interval. A complex coreflooding scheme provides the fluid distributions and production data from which the saturation functions are computed for both drainage and imbibition by a least-squares technique. A chemical shift NMR technique is used for fluid distribution determination. An undesirable interdependency of the saturation functions is avoided by their calculation from different data sets. Killough's method is employed to account for the scanning effect in hysteresis situations for both capillary pressure and relative permeability. The procedure is demonstrated on chalk samples from the North Sea. The experimental time is intermediate between the centrifuge and porous plate methods. ᭹ Step 1: Threshold pressure experiment. ᭹ Step 2: Transient flow drainage experiment. ᭹ Step 3: Stationary flow drainage experiment. ᭹ Step 4: Stationary flow internal imbibition experiment. ᭹ Step 5: Forced flow imbibition experiment.

show abstract

Quantitative 1D saturation profiles on chalk by NMR

Cited by 9 publications

References 3 publications

Two‐phase flow properties of a sandstone rock for the CO₂/water system: Core‐flooding experiments, and focus on impacts of mineralogical changes

Two‐phase flow properties of a sandstone rock for the CO₂/water system: Core‐flooding experiments, and focus on impacts of mineralogical changes

Imbibition Processes in Fractured Chalk Core Plugs with Connate Water Mobilization

Determination of Oil/Water Saturation Functions of Chalk Core Plugs From Two-Phase Flow Experiments

Contact Info

Product

Resources

About

Quantitative 1D saturation profiles on chalk by NMR

Cited by 9 publications

References 3 publications

Two‐phase flow properties of a sandstone rock for the CO2/water system: Core‐flooding experiments, and focus on impacts of mineralogical changes

Two‐phase flow properties of a sandstone rock for the CO2/water system: Core‐flooding experiments, and focus on impacts of mineralogical changes

Imbibition Processes in Fractured Chalk Core Plugs with Connate Water Mobilization

Determination of Oil/Water Saturation Functions of Chalk Core Plugs From Two-Phase Flow Experiments

Contact Info

Product

Resources

About

Two‐phase flow properties of a sandstone rock for the CO₂/water system: Core‐flooding experiments, and focus on impacts of mineralogical changes

Two‐phase flow properties of a sandstone rock for the CO₂/water system: Core‐flooding experiments, and focus on impacts of mineralogical changes