Towards a Simplified Petrophysical Model for the Vaca Muerta Formation

Cuervo, Sergio; Lombardo, Ezequiel; Vallejo, Dolores; Crousse, Luisa; Hernández, Carlos Martínez; Mossé, Laurent

doi:10.15530/urtec-2016-2437257

Cited by 8 publications

(2 citation statements)

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“…The effective porosity was calibrated by using both well log (black crosses in Figure 9) and gas‐filled porosity (red dots in Figure 9) data (YPF database). Results are consistent with previous studies (Askenazi et al., 2013; Cuervo et al., 2016; Ortiz et al., 2020) and show that the effective porosity increases towards the lower VM (Figure 9). In Well A, this parameter ranges from 5.5% to 12.16% (9.1% average), whereas in Well C effective porosity ranges from 3.24% to 8.44% (6.25% average).…”

Section: Basin and Petroleum System Modelling (Bpsm)supporting

confidence: 93%

Integrated source rock evaluation along the maturation gradient. Application to the Vaca Muerta Formation, Neuquén Basin of Argentina

Spacapan

Comerio

Brisson³

et al. 2021

Basin Research

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The Vaca Muerta Formation (Tithonian-early Valanginian) is the main source rock in the Neuquén Basin and the most important unconventional shale resource in South America. In the present study, organic geochemistry, electron microscopy and basin and petroleum system modelling (BPSM) were combined to evaluate source rock properties and related processes along a transect from the early oil (east) to the dry gas (west) window. The unit is characterized by high present-day (1%-8% average) and original (2%-16% average) total organic carbon contents, which increase to-

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Section: Basin and Petroleum System Modelling (Bpsm)supporting

confidence: 93%

Integrated source rock evaluation along the maturation gradient. Application to the Vaca Muerta Formation, Neuquén Basin of Argentina

Spacapan

Comerio

Brisson³

et al. 2021

Basin Research

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“…Athy's compaction law (Athy, 1930) and a multipoint model (Hantschel and Kauerauf, 2009) were considered for the Vaca Muerta Formation, with porosity values derived from the literature and gasfilled porosity data (Askenazi et al, 2013;Cuervo et al, 2016;Ortiz et al, 2020). The model presented by Spacapan et al (2021) incorporated a Terzaghi-type model to predict the fluid pressure evolution; however, in the present paper, a poro-elastic model was used that incorporates the effects of tectonic compression on the pore pressure calculation.…”

Section: X-ray Diffraction (Xrd) and Scanning Electron Microscopy (Sem)mentioning

confidence: 99%

DEVELOPMENT OF FIBROUS CALCITE VEINS RELATED TO HYDROCARBON GENERATION AND OVERPRESSURING IN ORGANIC‐RICH SHALE SOURCE ROCKS: THE VACA MUERTA FORMATION, NEUQUÉN BASIN, ARGENTINA

Spacapan

Comerio

Ruiz

et al. 2022

Journal of Petroleum Geology

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Fibrous calcite bed-parallel veins (BPVs) are a typical feature of the Upper Jurassic -Lower Cretaceous Vaca Muerta Formation in the subsurface of the Neuquén Basin (Argentina). The formation is considered to be the main source rock in the basin as well as an important unconventional play. This study examines the growth of BPVs through an analysis of core from three wells located along a transect extending for some 150 km from the NE Platform near the basin margin in the east to the Agrio fold-and-thrust belt at the Andean deformation front in the west. The main objective is to integrate fluid inclusion data with the palaeothermal and palaeopresure evolution obtained from a regional-scale 2D basin and petroleum systems model to examine the timing of fracture development and its relationship with hydrocarbon generation in the Vaca Muerta Formation through time.The apertures of BPVs were measured in more than 360 m of core from three wells (wells A, D and E). This data was combined with optical petrography to investigate the number of calcite cementation events, and the temperature of cement precipitation based on fluid inclusion data. The organic geochemical and mineralogical characteristics of the Vaca Muerta source rock were also analysed. The integrated results were incorporated into a poro-elastic basin model to investigate the impact of horizontal shortening due to Andean compression on pore pressure development and fracturing in the Vaca Muerta Formation. This framework allowed the timing of BPV formation to be determined together with possible mechanisms governing overpressure conditions through time.Near the Andean deformation front in the west of the modelled section where the Vaca Muerta Formation is in the wet gas window (well D) and dry gas window (well A), BPVs are characterized by two or more generations of calcite fibres indicating multiple growth phases. Calcite which precipitated during cementation event 1 (E1) in the internal zones of BPVs consists of crystals oriented perpendicular to fracture walls, indicating perpendicular vein opening. Calcite precipitated during cementation event 2 (E2) in the outer zones of BPVs includes curved and oblique crystals. During this phase, shear occurred between the 1 YPF-Tecnología S.A. (Y-TEC-CONICET), Av. del Petróleo Argentino (RP10) S/N, Berisso (CP 1923),

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Quantifying Water Saturation in a Source Rock Gas Play Using Multi-Frequency Dielectric Measurements

Raina

Dasgupta

Mossé

et al. 2017

Day 4 Thu, November 16, 2017

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One of the challenges in exploring tight source rock plays is accurately estimating water saturation using downhole measurements. The conventional approach of using resistivity along with a saturation equation has many uncertainties, especially in the exploration setting when the treasure chest of core measurements is still lacking. Even with core data available, non-standard core handling practices often lead to misleading interpretations and incorrect calibrations. Multi-frequency dielectric dispersion measurements provide a great way to overcome the challenges faced by the conventional resistivity based methods. These tools measure formation dielectric permittivity and conductivity at multiple frequencies. The large contrast between the permittivity of water and permittivity of rock, hydrocarbon and kerogen enables the tool to measure water volume. The dispersion observed in permittivity and conductivity with frequency is a function of the water textural parameters and salinity. Thus, this measurement does not need external textural and salinity parameters as inputs, but rather, computes these as outputs which can be used in the conventional resistivity based approach. Multi-frequency dielectric measurements were carried out on the Diyab source rock gas play in Abu Dhabi. Comparisons to the resistivity based method led to an initial uncertainty in identifying zones of low water saturation in the source rock play, however, a core analysis program was designed to address these uncertainties. Core NMR, core dielectric permittivity, retort, total organic carbon (TOC) were among the several measurements that were carried out to characterize the formation and compute the fluid volumes in the rock. Despite the uncertainties associated with heterogeneity seen in the source rock gas play, a better match was observed between the dielectric measured water volumes and core results as compared to the resistivity based water volumes. This was due to high textural variation in the rock which was confirmed by dielectric dispersion measurements. Relative permittivity of the rock matrix was recognized as a key parameter influencing dielectric dispersion results. Core measurements were used to calibrate the calcite matrix permittivity for the Diyab formation. Limitations were recognized (and addressed) with certain core measurement sample preparation techniques which could lead to confusing results in the absence of other measurements. Core NMR was recognized as an essential measurement to quantify water volume in this study. This is the first time that a source rock gas play has been analyzed in Abu Dhabi with such an extensive core and log program, and it is imperative that best practice methods be established to improve and add value to future interpretations. Dielectric dispersion measurement has proved to be immensely valuable in quantifying the water saturation in the source rock gas play in Abu Dhabi, overcoming several challenges we face with conventional resistivity based methods.

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Towards a Simplified Petrophysical Model for the Vaca Muerta Formation

Cited by 8 publications

References 0 publications

Integrated source rock evaluation along the maturation gradient. Application to the Vaca Muerta Formation, Neuquén Basin of Argentina

Integrated source rock evaluation along the maturation gradient. Application to the Vaca Muerta Formation, Neuquén Basin of Argentina

DEVELOPMENT OF FIBROUS CALCITE VEINS RELATED TO HYDROCARBON GENERATION AND OVERPRESSURING IN ORGANIC‐RICH SHALE SOURCE ROCKS: THE VACA MUERTA FORMATION, NEUQUÉN BASIN, ARGENTINA

Quantifying Water Saturation in a Source Rock Gas Play Using Multi-Frequency Dielectric Measurements

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