Pressure‐transient experiments and the elastic characterization of fractures

Cardona, Reynaldo; Batzle, Michael; Özkan, Erdal

doi:10.1190/1.1817046

Cited by 4 publications

(9 citation statements)

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“…As result of Bakulin et al 17 and Cardona et al 13 works, seismic derived normal fracture compliance allows us to estimate the storage capacity ratio without well data. Where well data are available, another independent estimate of storage capacity ratio can be obtained, which allows us to link seismic and pressure transient data.…”

Section: Well Test Analysis and Elastic Behavior Of Naturally Fracturmentioning

confidence: 94%

“…Equation 13 provides a method to compute the reduction in fracture porosity due to changes in pore pressure.…”

Section: Effect Of Effective Stress On Fracture Porositymentioning

confidence: 99%

“…Then, Cardona et al 13 demonstrated that using Zimmerman's 14 rock compressibility relations and Schoenberg's linear slip theory (Schoenber and Douma 15 , Schoenberg and Sayers 16 ), the storage capacity ratio can be related to the normal compliance of the fracture system. Since in fractured rocks the bulk modulus is a function of the normal fracture compliance, relationships between the storage capacity and the normal fracture compliance can be derived.…”

Section: Well Test Analysis and Elastic Behavior Of Naturally Fracturmentioning

confidence: 99%

“…Using the equations presented by Zimmerman's 14 that relate the pore space compressibility to the bulk compressibility of the rock, Cardona et al 13 demonstrated that the total and fracture storage capacities can be expressed as:…”

Section: Storage Capacity Ratio and Normal Fracture Compliancementioning

confidence: 99%

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Effects of Stress on Fracture Properties of Naturally Fractured Reservoirs

Chacon¹,

Tiab²

2007

Proceedings of Latin American &Amp; Caribbean Petroleum Engineering Conference

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fax 01-972-952-9435. AbstractThis paper analyzes the effect of stress on the rock properties fracture and matrix compressibilities, fracture and matrix porosities, and permeability in naturally fractured reservoirs (NFRs).In NFRs, fluids are stored inside the matrix pore space and inside the fractures of the rock. The reservoir characterization parameter indicating the volumetric fraction of fluids deposited inside the fractures is the storage capacity ratio, which is function of the fracture and matrix porosity, and fracture and matrix total compressibilities. Due to the difficulty to obtain these values, in reservoir engineering computations such as pressure transient analysis and reservoir simulation, among others, it is generally assumed that the matrix and the fracture total compressibilities are equal. This induces a big uncertainty in the estimation of the storage capacity ratio and leads to a wrong estimation of the volume of fluids inside the fractured rock.Changes in pore pressure due to production or injection of fluids affect the effective reservoir in-situ stress. The mechanical behavior of the fractured rock and its effects on the rock properties permeability, porosity and compressibility in the matrix and fracture frames are analyzed using the elastic properties bulk modulus and normal compliance of the fracture. These properties can be obtained from petrophysical core analysis or multi-component seismic interpretation, and linked to pressure transient analysis through the storage capacity ratio equation. A step-by-step procedure of the analysis is presented and illustrated with an example for quantifying the effects of changes in effective stress on the fracture and matrix compressibilities.

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Section: Well Test Analysis and Elastic Behavior Of Naturally Fracturmentioning

confidence: 94%

“…Equation 13 provides a method to compute the reduction in fracture porosity due to changes in pore pressure.…”

Section: Effect Of Effective Stress On Fracture Porositymentioning

confidence: 99%

Section: Well Test Analysis and Elastic Behavior Of Naturally Fracturmentioning

confidence: 99%

Section: Storage Capacity Ratio and Normal Fracture Compliancementioning

confidence: 99%

See 2 more Smart Citations

Effects of Stress on Fracture Properties of Naturally Fractured Reservoirs

Chacon¹,

Tiab²

2007

Proceedings of Latin American &Amp; Caribbean Petroleum Engineering Conference

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“…As such, a multiplier, Φ, is applied to the right-hand-side of Eq.-2.1 to account for reduced water-rock contact; i.e., Φ << 1. A value of 5 x 10 -5 was assigned to Φ based on the in situ fracture porosity estimated by Cardona et al (2002).…”

Section: 4)mentioning

confidence: 99%

Final Report: Improved Site Characterization And Storage Prediction Through Stochastic Inversion Of Time-Lapse Geophysical And Geochemical Data

Ramirez¹,

McNab²,

Yu³

et al. 2011

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During the last months of this project, our project activities have concentrated on four areas: 1) performing a stochastic inversion of pattern 16 seismic data to deduce reservoir bulk/shear moduli and density; the need for this inversion was not anticipated in the original scope of work, 2) performing a stochastic inversion of pattern 16 seismic data to deduce reservoir porosity and permeability, 3) complete the software needed to perform geochemical inversions and 4) use the software to perform stochastic inversion of aqueous chemistry data to deduce mineral volume fractions. This report builds on work described in progress reports previously submitted (Ramirez et al., 2009(Ramirez et al., , 2011reports fulfilled the requirements of deliverables D1 -D4) and fulfills deliverable D5: Field-based single-pattern simulations work product.The main challenge with our stochastic inversion approach is its large computational expense, even for single reservoir patterns. We dedicated a significant level of effort to improve computational efficiency but inversions involving multiple patterns were still intractable by project's end. As a result, we were unable to fulfill Deliverable D6: Fieldbased multi-pattern simulations work product.

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