Constraining stress magnitudes using petroleum exploration data in the Cooper–Eromanga Basins, Australia

Reynolds, Scott; Mildren, Scott D.; Hillis, Richard R.; Meyer, Jeremy J.

doi:10.1016/j.tecto.2005.12.005

Cited by 74 publications

(43 citation statements)

References 22 publications

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“…Nevertheless, observations of in situ stress orientations and magnitudes demonstrate that these expressions do not fully explain crustal stresses (McGarr and Gay, 1978;Zoback et al, 1980;Brudy et al, 1997;Reynolds et al, 2006). The actual state of stress in the lithosphere differs from these two reference states, for example, as a result of tectonic stresses arising from interactions at the boundaries of lithospheric plates (Turcotte and Schubert, 1982;Engelder, 1993;Caputo, 2005).…”

Section: Elastic Rheology and Stress Magnitudesmentioning

confidence: 99%

“…Carminati et al, 2004 ). On the other hand, in situ measurements in deep boreholes indicate higher horizontal than vertical stresses ( McGarr and Gay, 1978;Brudy et al, 1997;Reynolds et al, 2006 ), and both reference states represent, at best, incomplete approaches to lithospheric stresses. Several natural processes can modify the reference state, such as tectonic stresses arising from plate boundaries, topographic loading, unloading due to erosion, lithospheric bending, thermoelastic loads, and pore fluid pressure ( Turcotte and Schubert, 1982;Twiss and Moores, 1992;Engelder, 1993;Caputo, 2005 ).…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Intraplate stress state from finite element modelling: The southern border of the Spanish Central System

Martín-Velázquez¹,

Muñoz²,

Elorza³

2009

Tectonophysics

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Section: Elastic Rheology and Stress Magnitudesmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Intraplate stress state from finite element modelling: The southern border of the Spanish Central System

Martín-Velázquez¹,

Muñoz²,

Elorza³

2009

Tectonophysics

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“…This test, referred to as minifrac in the petroleum industry, is pumping test usually conducted in the design and execution of large scale fracture stimulation jobs [Reynolds at al., 2006]. A minifrac test creates a fracture perpendicular to the minimum principal stress (the minimum horizontal stress in either a strike-slip or normal stress regime) by increasing the pressure in an isolated section of the wellbore.…”

Section: Acquirement Of Minifrac Test Datamentioning

confidence: 99%

“…This fact is due to the leak-off pressures do not yield as reliable an estimate of the minimum horizontal stress magnitude as those determined from minifrac tests. This is largely because the disturbed stress field at the wellbore wall controls the leak-off pressure, and because the leak-off pressure must overcome any tensile strength of the formation [Reynolds et al, 2006]). For this study, closure pressures from minifrac tests were provided as shown in Figure 6b.…”

Section: Es4004mentioning

confidence: 99%

Estimation of in-situ horizontal stresses using the linear poroelastic model and minifrac test results in tectonically active area

Hayavi¹,

Abdideh²

2016

Russ. J. Earth Sci.

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Accurate estimation of in situ stresses of a subsurface formation is important to get a basic knowledge of formation structure and position of anomalies, groundwater flows, performing fracturing operations, drilling operations, oil and/or gas production stimulation, wellbore stability analysis, and coupled geomechanics-reservoir simulation in petroleum engineering. In this paper, at first a new method for estimation of minimum and maximum horizontal stresses in tectonically active area based on the modification of linear poroelastic model and minifrac test results is presented. The rock mechanical properties used in poroelastic model are determinded using the artificial neural networks. Then, this method is applied to field data in order to verify the applicability of the modified linear poroelastic model. The results indicated that the agreement between the results of minifrac test and modified linear poroelastic model is satisfactory. Furthermore, application of artificial neural networks in this methodology increases the accuracy of linear poroelastic model for estimation of horizontal stresses. KEYWORDS: Minifrac tests; linear poroelastic model; horizontal stress; tectonically active area.Citation: Hayavi, Mohammad Tabaeh and Mohammad Abdideh (2016), Estimation of in-situ horizontal stresses using the linear poroelastic model and minifrac test results in tectonically active area, Russ.

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“…The Cooper and Eromanga sedimentary basins (~3.6 km thick) act as an insulating cap over the granitic EGS reservoir (Holl and Barton 2015). The project area is characterized by a compressive stress field oriented approximately in E-W direction (Reynolds, et al 2006, Reynolds, et al 2005. In November 2012, the Habanero-4 well was stimulated by injecting 36.5 ML of near-surface aquifer-sourced water (13 Ωm at 25°C) over 14 days (Hogarth, et al 2013, Holl and Barton 2015, McMahon and Baisch 2013.…”

Section: Introductionmentioning

confidence: 99%

Magnetotelluric monitoring of hydraulic fracture stimulation at the Habanero Enhanced Geothermal System, Cooper Basin, South Australia

Didana

Thiel²,

Heinson

et al. 2016

ASEG Extended Abstracts

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SUMMARYMagnetotelluric (MT) data were collected across the Habanero Enhanced Geothermal System project in the Cooper Basin, South Australia. A baseline regional MT survey consisting of two profiles was collected to delineate the pre-injection resistivity structure. Two dimensional inversions of the MT data reveal three main resistivity structures to a depth of 5 km. The low resistivity surface layer (about 1.5 km thick) is interpreted as poorly consolidated sediments of Lake Eyre and Eromanga Basins. Below the conductive layer, a zone with relatively high resistivity with thickness of 2 km can be correlated to consolidated Cooper Basin sediments. A high resistivity zone below depths of 3.5 km is interpreted as the hot intrusive granodiorite (granite) of the Big Lake Suite with low porosity and permeability. This deep structure is also related to the Habanero EGS reservoir. The second MT survey was conducted during stimulation of Habanero-4 well by Geodynamics Ltd, where 36.5 ML of water with a resistivity of 13 Ωm (at 25°C) was injected at a relatively continuous rate of between 27-53 L/s over 14 days at a depth of almost 4 km. Analysis of pre-and post-injection residual phase tensors for periods greater than 10 s indicate conductive fractures oriented in a N/NNE direction. Apparent resistivity maps also revealed that injected fluids possibly propagated towards N/NNE direction. This result is in agreement with the micro-seismic events with an area of 4 km 2 observed during fluid injection, as well as orientation of pre-existing N-S striking sub-horizontal fractures susceptible to slip due to stimulation. The MT responses close to injection show on average 5% decrease in apparent resistivity at periods greater than 10 s. The main reasons for observing subtle changes in resistivity at Habanero EGS is the screening effect of the conductive thick sedimentary cover (about 3.6 km thick) and the presence of preexisting saline fluids with resistivity of 0.1 Ωm (equivalent to salinity of 16.1 g/L at 240°C) in the natural fractures. Overall, the MT monitoring at Habanero EGS highlights the need for favourable geological settings to measure significant changes in resistivity in EGS reservoirs.

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Constraining stress magnitudes using petroleum exploration data in the Cooper–Eromanga Basins, Australia

Cited by 74 publications

References 22 publications

Intraplate stress state from finite element modelling: The southern border of the Spanish Central System

Intraplate stress state from finite element modelling: The southern border of the Spanish Central System

Estimation of in-situ horizontal stresses using the linear poroelastic model and minifrac test results in tectonically active area

Magnetotelluric monitoring of hydraulic fracture stimulation at the Habanero Enhanced Geothermal System, Cooper Basin, South Australia

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