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Title: Assessment of CO 2 Storage Potential in Naturally Fractured Reservoirs With Dual-Porosity Models

ORCiD logo [1]; ORCiD logo [1]; ORCiD logo [1]
  1. Institute of Petroleum Engineering, Heriot-Watt University, Edinburgh UK
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Journal Article: Publisher's Accepted Manuscript
Journal Name:
Water Resources Research
Additional Journal Information:
Related Information: CHORUS Timestamp: 2018-03-08 06:43:47; Journal ID: ISSN 0043-1397
Wiley Blackwell (John Wiley & Sons)
Country of Publication:
United States

Citation Formats

March, Rafael, Doster, Florian, and Geiger, Sebastian. Assessment of CO 2 Storage Potential in Naturally Fractured Reservoirs With Dual-Porosity Models. United States: N. p., 2018. Web. doi:10.1002/2017WR022159.
March, Rafael, Doster, Florian, & Geiger, Sebastian. Assessment of CO 2 Storage Potential in Naturally Fractured Reservoirs With Dual-Porosity Models. United States. doi:10.1002/2017WR022159.
March, Rafael, Doster, Florian, and Geiger, Sebastian. 2018. "Assessment of CO 2 Storage Potential in Naturally Fractured Reservoirs With Dual-Porosity Models". United States. doi:10.1002/2017WR022159.
title = {Assessment of CO 2 Storage Potential in Naturally Fractured Reservoirs With Dual-Porosity Models},
author = {March, Rafael and Doster, Florian and Geiger, Sebastian},
abstractNote = {},
doi = {10.1002/2017WR022159},
journal = {Water Resources Research},
number = ,
volume = ,
place = {United States},
year = 2018,
month = 3

Journal Article:
Free Publicly Available Full Text
This content will become publicly available on March 8, 2019
Publisher's Accepted Manuscript

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  • Models for fluid flow in naturally fractured reservoirs have been developed by the oil industry for at least the last three decades. Although a variety of techniques have been attempted to simulate these complex systems, the most efficient approach appears to be the dual porosity model. In dual porosity models, transfer functions are critical components that describe fluid flows between matrix blocks and surrounding fractures. Model results are very sensitive to the matrix/fracture transfer function, and it is usually these transfer functions that distinguish different models. In this paper, the authors classify transfer functions reported in the literature into fivemore » categories: basic transfer functions (BTF), transfer functions with explicit gravitational effects, transfer flow calculations based on discretization of matrix blocks, such as multiple interacting continua (MINC), transfer functions with pseudo-curves, and other models. A comprehensive review of these transfer functions is presented, followed by a discussion of their differences and similarities.« less
  • This paper describes the application of the method of ''Multiple Interacting Continua'' (MINC) to the simulation of oil recovery in naturally fractured reservoirs. A generalization of the double-porosity technique, the MINC method permits a fully transient description of interporosity flow by numerical methods. The authors present examples to demonstrate the utility of the MINC method for modeling oil-recovery mechanisms by water imbibition and field applications for five-spot waterflooding and water coning problems in fractured reservoirs. All results show that the MINC method provides accurate predictions of the behavior of naturally fractured reservoirs, while requiring only a modest increase in computationmore » work compared with the double-porosity method. The double-porosity method may result in large errors for matrix blocks of low permeability or large size.« less
  • This study develops an improved model for analysis of pressure transient tests of naturally fractured reservoirs. The development was prompted by observations of actual well tests that showed anomalous slope changes during the transition period and where the behavior could not be explained by dual-porosity models. Geometrical configurations studied include both the strata model, where horizontal matrix layers are separated by fractures, and the uniformly distributed blocks, which are separated by an orthogonal set of fractures. These systems were assumed to be under gradient flow conditions. In both cases, two separate sets of matrix properties were assumed. The formulation ofmore » response was solved semianalytically. The solutions included the early-time effects of both the afterflow and skin. Observations made from the theoretical predictions are that the fracture-controlled early times and portions of the transition period will resemble the behavior of a dual-porosity system. The latter part of the transition zone, however, exhibits slope changes; the duration is a function of lambda/sub 1//lambda/sub 2/ (ratio of interporosity flow coefficients for the two matrix types) and 1// 2/ (ratio of fluid capacitance coefficients). A correlation developed on the basis of numerous sensitivity runs allows the estimation of 1// 2/ and lambda/sub 1//lambda/sub 2/ with the times that correspond to the onset of anomalous slope changes. Because an infinite-acting slope may develop before the matrix blocks of the lowest lambda show their existence during the anomalous slope changes, recognition of the various matrix properties emphasized in this study will also safeguard against extrapolation of incorrect late-time curves.« less
  • Fractured shales have produced gas since the early 1900s along the western margin of the Appalachian basin. The amount of gas in fractured shales has been estimated at 460 quadrillion SCF. An extensive area of fractured shales also is present in the lowlands of Quebec, which appears to have a good gas potential based on limited information available. Since gas production is usually low, the economics of producing these reservoirs has been generally regarded as marginal. However, increases in gas price and a potential energy shortage have provided new incentives for extensive research and development involving fracture shales. Some 3000more » productive fractured shale wells have been drilled in Southwestern West Virginia. Estimated ultimate recovery from the wells is 1 trillion SCF as most wells are completed open-hole. It is possible that some gas attributed to the Devonian shale has actually come from shallower Mississippian beds. Preliminary evaluation of Ordovician shales in the lowlands of Quebec indicates that there is a good potential for gas production from the fractured Lorraine and Utica groups. 19 references.« less
  • In recent years many research results, both theoretical experimental, have been published to improve the accuracy of dual porosity modeling. Most of these studies dealt with the accuracy of matrix-fracture transfer flow (MFTF) calculations (so-called transfer functions). Some studies concentrated on creating empirical transfer functions through single matrix block modeling, while others incorporated MFTF calculations in dual porosity model by using some type of sub-gridding or averaging technique. However, flow in fractures and its effects on MFTF have not been fully studied in the literature. In this paper, the authors first compare methods for MFTF calculations under static fracture conditions,more » followed by results of numerically modeling fluid flow in matrix blocks with adjoining fractures undergoing dynamic conditions. The system studied is an oil-saturated matrix block surrounded by fractures in which water is injected to generate dynamic flow conditions. Hence, there are two dynamic flow systems. One is counter-current imbibition inside the matrix block, and the other is two-phase flow in the fractures. Results show that the usual assumption of phase saturation continuity between matrix block and fracture in a conventional dual porosity model generates erroneous results, especially breakthrough time at producers. The approach is also successfully used to model published experimental data without any adjustment to measured rock and fluid data.« less