Oil & Natural Gas Projects
Exploration and Production Technologies
Integrated, Multi-Scale Characterization of Imbibition and Wettability Phenomena
Using Magnetic Resonance and Wide-Band Dielectric Measurements
The petrophysical properties of rocks, particularly their relative permeability and wettability, strongly influence the efficiency and the time-scale of all hydrocarbon recovery processes. However, the quantitative relationships needed to account for the influence of wettability and pore structure on multi-phase flow are not yet available, largely due to the complexity of the phenomena controlling wettability and the difficulty of characterizing rock properties at the relevant length scales. This project brings together several advanced technologies to characterize pore structure and wettability. Grain-scale models are developed that help to better interpret the electric and dielectric response of rocks. These studies allow the computation of realistic configurations of two immiscible fluids as a function of wettability and geologic characteristics. These fluid configurations form a basis for predicting and explaining macroscopic behavior, including the relationship between relative permeability, wettability and laboratory and wireline log measurements of NMR and dielectric response. Dielectric and NMR measurements have been made show that the response of the rocks depends on the wetting and flow properties of the rock. The theoretical models can be used for a better interpretation and inversion of standard well logs to obtain accurate and reliable estimates of fluid saturation and of their producibility.
University of Texas, Austin, TX
Rice University, Houston TX
T2 relaxation time distributions were generated by implementing the rapid acquisition with relaxation enhancement (RARE) pulse sequence. RARE experiments were performed on a vuggy Yates core sample. Generation of a T2 map revealed a slight heterogeneity even within a core sample with a height of 1 inch. A porosity profile constructed from the RARE results yielded a porosity of 0.146 which was in good agreement with the gravimetric porosity (0.147) and the porosity determined via CPMG.
By simulating longitudinal and transversal magnetizations for specific bulk fluid properties and fluid/solid boundary geometries, the random-walk approach can be used to generate parametric multidimensional T1/T2/D NMR maps to improve the characterization of pore structures and saturating fluids from NMR.
A new geometrical concept to simulate DC electrical conductivity in arbitrary rock models was proposed. The assumed geometry considers 3D grain and pore objects that include intra-granular porosity, clay inclusions, non-wetting fluid blobs, thin films, and pendular rings. This provides a simple way to parameterize the three-dimensional space and to simulate the electrical conductivity of porous media saturated with two immiscible fluid phases. This work emphasizes the importance of thin films, pendular rings and snap-offs to capture the correct electrical behavior of dense media using granular models. We introduce a new approach to quantify the effects of pore geometry and connectivity on the kHz-GHz frequency dispersion of dielectric permittivity and electrical conductivity of clay-free porous rocks. The simulation procedure provides a systematic method to assess the sensitivity of a multitude of pore-scale properties to the macroscopic wide-band dielectric dispersion of saturated rocks.
A comprehensive pore-scale numerical framework was introduced that incorporates explicit geometrical distributions of grains, fluids and clays constructed from core pictures, and that reproduces the WBEM saturated-rock response on the entire kHz-GHz frequency range. WBEM measurements are verified to be primarily sensitive (a) in the kHz range to clay amounts and wettability, (b) in the MHz range to pore morphology (i.e., connectivity and eccentricity), fluid distribution, salinity, and clay presence, and (c) in the GHz range to porosity, pore morphology and fluid saturation. Our simulations emphasize the need to measure dielectric dispersion in the entire frequency spectrum to capture the complexity of the different polarization effects. In particular, it is crucial to accurately quantify the phenomena occurring in the MHz range where pore connectivity effects are confounded with clay polarization and pore/grain shape effects usually considered in dielectric phenomena. These different sensitivities suggest a strong complementarity between WBEM and NMR measurements for improved assessments of pore size distribution, hydraulic permeability, wettability, and fluid saturation.
Electrical impedence measurements were made over a broad spectrum of frequencies (10 Hz to 10 MHz) with fully brine saturated rock samples of varying permeability (grain size). It is shown that a systematic shift in loss tangent (both peak frequency and magnitude) occurs as the grain size is varied. This suggests that the loss tangent, derived from broadband dielectric measurements, may be used to measure the formation grain size and hence estimate the permeability.
This project brings together several advanced technologies for better interpretations of laboratory and wireline data to obtain petrophysical properties. New NMR techniques and dielectric measurements results in more accurate and less uncertain estimates of hydrocarbon saturations and rock flow properties. Advanced modeling of NMR and dielectric response for the first time brings a microscopic justification for the effective-medium response of complex rock formations. This effective-medium response provides new ways to quantify types of fluids and their saturation in complex pore structures. Finally, the project performers will interpret laboratory and field measurements in terms of physically representative models of the processes that form sedimentary rocks. The latter, recently demonstrated, approach offers an unprecedented capability method for quantitatively and predictively linking grain-scale geometry and surface chemistry to core-scale behavior.
The ultimate benefit of this combined theoretical/empirical approach for reservoir characterization is that rather than reproducing the behavior of any particular sample or set of samples, it can explain and predict trends in behavior that can be applied at a range of length scales, including correlation with wireline logs, seismic, and geologic units and strata. This approach can substantially enhance wireline log interpretation for reservoir characterization and provide better descriptions, at several scales, of crucial reservoir flow properties that govern oil recovery.
The project was initiated in 2004 as a joint effort between the University of Texas and Rice University. A lack of measurements and pore-scale understanding and the opportunity of combining two measurements, NMR and dielectric response of rocks, led to the formation of this team.
This project brings together several advanced technologies for better interpretations of laboratory and wireline data to obtain petrophysical properties. New NMR techniques and dielectric measurements will result in more accurate and less uncertain estimates of hydrocarbon saturations and rock flow properties. Advanced modeling of NMR and dielectric response will for the first time bring a microscopic justification for the effective medium response of complex rock formations. This effective medium response will provide new ways to quantify types of fluids, and their saturation in complex pore structures. Finally, we interpreted laboratory and field measurements in terms of physically representative models of the processes that form sedimentary rocks. The latter recently demonstrated approach offers an unprecedented capability method for quantitatively and predictively linking grain–scale geometry and surface chemistry to core scale behavior.
Current Status (February 2008)
The project was initiated in October 2004.Due to lack of available funds, budget period 3 was not funded. Final report was completed by 9/30/07.
This project was selected in response to DOE’s Oil Exploration and Production, Reservoir Efficiency Processes, Solicitation DE-PS26-04NT15450-3A, February 2, 2004.
Project Start: October 1, 2004
Project End: September 30, 2007
Anticipated DOE Contribution: $797,685
Performer Contribution: $395,626 (33 percent of total)
NETL - Chandra Nautiyal (email@example.com or 918-699-2021)
U. of Texas - Mukul Sharma (firstname.lastname@example.org or 512-471-3257)
Prodanovic, M. and Bryant, S. “A level set method for determining critical curvatures for drainage and imbibition,” Journal of Colloid and Interface Science, Volume 304, Issue 2, 15 December 2006, Pages 442-458.
Prodanovic, M. and Bryant, S., “Investigating Pore Scale Configurations of Two Immiscible Fluids Via The Level Set Method,” Proceedings of Computational Methods in Water Resources Conference XVI, Copenhagen, June 19-22, 2006.
Motealleh, S. and Bryant, S. “Predictive Model for Permeability Reduction by Small Wetting Phase Saturations,” Proceedings of the Computational Methods in Water Resources Conference XVI, Copenhagen, June 19-22, 2006.
Gladkikh, M. and Bryant, S., “Prediction of Imbibition in Unconsolidated Granular Materials,” Journal of Colloid and Interface Science, Vol. 288, No. 2, pp. 526-539, April 2005.
Gladkikh, M., and Bryant, S. “Influence of Wettability on Petrophysical Properties During Imbibition In A Random Dense Packing of Equal Spheres,” Journal of Petroleum Science and Engineering, 2006, in press.
Gladkikh, M. and Bryant, S., “Prediction of Imbibition from Grain-Scale Interface Movement,” Advances in Water Resources, in press.
Gladkikh, M. N., Bryant, S.L., and Herrick, D. C., “Mechanistic Basis for Hysteresis in Multiphase Transport Properties,” SPE 95738, Proceedings of 2006 Society of Petroleum Engineers/Department of Energy Symposium on Improved Oil Recovery, Tulsa, Oklahoma, April 22-26, 2006.
Gladkikh, M., Bryant, S. L., and Herrick, D. C., “Influence of Wettability on Resistivity of Sedimentary Rocks,” Proceedings of the International Symposium of the Society of Core Analysts, Toronto, Canada, August 21-25, 2005.
Gladkikh, M. and Bryant, S., “Prediction of Imbibition in Simple Porous Media,” Proceedings of the XVth International Conference on Computational Methods in Water Resources, Vol. 1, pp. 175-186, Chapel Hill, North Carolina, June 13-17, 2004.
Gladkikh, M. and Bryant, S., “Mechanistic Prediction of Capillary Imbibition Curves," SPE 90333, Proceedings of the Society of Petroleum Engineers Annual Technical Conference and Exhibition (ATCE) 2004: A World of Evolving Technology, Houston, Texas, September 26-29, 2004.
Toumelin, E., and Torres-Verdín, C., 2006, Pore-scale methodology for the simulation of DC electrical conductivity of saturated rocks in the presence of variable grain morphology and mixed wettability: submitted for publication, Water Resources Research.
Toumelin, E., and Torres-Verdín, C., 2006, Two-dimensional pore-scale simulation of wide-band dielectric dispersion of saturated rocks: in press, Geophysics.
Workshops held / presentations to promote the technology developed:
The research on using NMR to measure profiles of saturation in cores was presented at the 2006 and 2007 meeting on the Rice University Consortium on Processes in Porous Media.
Several presentations made to the Joint Industry Research Consortium on Formation Evaluation, Austin Texas, 2004, 2005, 2006 and 2007.
Bryant, S. L., Prodanovic, M. and Motealleh, S., “Grain-Scale Modeling of Petrophysical Properties of Clastics,” Baker Hughes Research Center, Houston, Texas, December 9, 2005.
Gladkikh, M. and Bryant, S., “Predicting Realistic Fluid Configurations in Porous Media and Their Influence on Petrophysical Properties,” University of Trinidad and Tobago, Port of Spain, Trinidad, November 18, 2005.
Gladkikh, M. and Bryant, S., “Influence of Wettability on Pore-Level Fluid Configurations and Their Macroscopic Properties,” Joint Industry Research Consortium on Formation Evaluation, Austin Texas, August 19-20, 2004.
Gladkikh, M. and Bryant, S., “Influence of Wettability on Petrophysical Parameters during Imbibition in Simple Porous Media,” 8th International Symposium on Reservoir Wettability, Rice University, Houston, Texas, May 17-19, 2004.
Gladkikh, M., Bryant, S., Jain, V., and Sharma, M., “Influence of Wettability on Interfacial Areas and Relative Permeabilities in Porous Media,” 8th International Symposium on Reservoir Wettability, Rice University, Houston, Texas, May 17-19, 2004.
Experimental and Theoretical Basis for a Wettability-Interfacial Area-Relative Permeability Relationship, SPE 84544 presented at the SPE Annual Technical Conference and Exhibition held in Denver, Colorado, October 5 – 8, 2003, M. Gladkikh, V. Jain, S. Bryant, M.M. Sharma.
Phd & MS degrees awarded in this project:
Gladkikh, M. "A Priori Prediction of Macroscopic Properties of Sedimentary Rocks Containing Two Immiscible Fluids", Ph.D. dissertation, The University of Texas at Austin, 2005.
Toumelin, Emmanuel, “Pore-Scale Petrophysical Models for the Simulation and Combined Interpretation of Nuclear Magnetic Resonance and Wide-Band Electromagnetic Measurements of Saturated Rocks”, Ph.D. dissertation, The University of Texas at Austin, May 2006.
Motealleh, S. Ph.D in progress.
Nelson Hu. “Measurements of the Dielectric Properties of Rocks”, MS Thesis, May 2007.
Conductivity and dielectric constant of fully water-saturated Berea sandstone with varying core sample thickness.
Loss tangent for 0.03 percent NaCl saturated Berea sandstone for different core sample thicknesses.
CT scan of Berea sample saturation profile.
Saturation profile in radial and x directions.
Conductivity of Berea sample at partial saturation. The conductivity drops dramatically for the first 10 percent saturation drop. Notice the change in conductivity with saturation at different frequencies.
Conductivity of Berea sample at partial saturation. The conductivity shows a relatively slower decrease as the sample has less than 0.9 water saturation. The change of curvature with frequency at different water saturation can be seen clearly.
Above, illustration of Melrose criterion for imbibition. The simplest configuration
of fluids in a non-imbibed pore is shown. Below, a smaller value of curvature
than in the adjoining illustration, the ring and meniscus first comes into contact
at point J. This results in the instability of the interface and leads to the
imbibition event: All NW phase withdraws, and W phase completely fills the pore.
Above, example of 2-D NMR map, in the case where only water is present in the
pores. Below, example of 2-D NMR map, in the case where water is the wetting
phase (right spot) and oil plus non-wetting oil (left spot) phases.