Geomechanical analysis of pressure limits for gas storage reservoirs

Bruno, Michael S.; Dusseault, Maurice B.; Balaa, T.T.; Barrera, John

doi:10.1016/s0148-9062(98)00085-0

Cited by 16 publications

(10 citation statements)

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“…Injection of CO 2 causes the pressure near the injection point to exceed the initial pressure (32 MPa) by a factor of 1.1. Within gas storage operations, this is lower than the maximum value accepted indicating that the risk of geomechanical formation damage is still negligible [5]. The CO 2 phase change from the gas into the dissolved phase in liquid results in a pressure reduction because of the effect of volume change.…”

Section: Reservoir Pressurementioning

confidence: 92%

Numerical Modeling of a Potential Geological CO 2 Sequestration Site at Minden (Germany)

Beni

Kühn

Meyer³

et al. 2011

Environ Model Assess

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We study opportunities for CO 2 sequestration in geological formations of the state North Rhine Westphalia in Germany. Simulations are performed for evaluating a potential site within the Bunter sandstone formation near the town of Minden in a depth of around 3,000 m using the numerical simulator TOUGHREACT. Our focus is on three CO 2 storage mechanisms: (1) hydrodynamic trapping, (2) dissolution trapping, and (3) mineral trapping. The results show that due to buoyancy the injected CO 2 phase initially migrates towards the top of the reservoir and is hydrodynamically trapped beneath the confining layer of the cap rock. Then, the CO 2 spreads laterally and dissolves partially in the formation water. The dissolution of CO 2 results in an increase of the density of the brine causing a downward migration until it settles after 10,000 years at the bottom of the reservoir. The simulations indicate that after 10,000 years, 15% (17 Mt) from a total of 114 Mt injected CO 2 are trapped hydrodynamically, 20% (23 Mt) are trapped by disso- A. lution, and 65% (74 Mt) are fixed in newly formed carbonates such as dawsonite, ankerite, and siderite. Within our study pressure increases near the injection well by a factor of 1.1 which is lower than the upper limit usually accepted in gas storage operations. The mineral reactions cause a net decrease of porosity and in turn a decrease of permeability down to 9% of the initial value in parts of the reservoir.

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Section: Reservoir Pressurementioning

confidence: 92%

Numerical Modeling of a Potential Geological CO 2 Sequestration Site at Minden (Germany)

Beni

Kühn

Meyer³

et al. 2011

Environ Model Assess

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“…The feasibility study of the "P>Pi Projects" needs to collect new and detailed information about geological and structural features of the field (Bruno et al, 1998).…”

Section: Scope Of Workmentioning

confidence: 99%

Looking For Earlier Integration: An Application Example

Pampuri

Brignoli

Berto

et al. 2008

Europec/Eage Conference and Exhibition

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A "creative" approach to reservoir characterization is not always the best choice while integration should be the appropriate methodology, if properly planned and developed. This paper describes the integrated sedimentology-petrophysics-geomechanics methodology used to characterize the reservoir and cap-rock that will be interested by gas storage activity at overpressure conditions. The determined data are then used in the modelling phase aiming at evaluating the safe injection/storage maximum operating pressure.The analyzed sequence is located in Central Italy and is represented by sand-shale intervals. The available data are: conventional and high last technology logs, mini-frac tests, laboratory core analysis, sedimentological and fracture description on cores.The advantage of the approach relies in the use, during the different project tasks, of each provisional result to drive the work group for finding the solution which better honours the response of different disciplines, looking therefore for an 'integration on the job'.The two shales, bounding the reservoir, had similar geomechanical properties but different petrophysical ones (different sedimentological process). The overburden ("cap-rock") is mostly massive with maximum horizontal stress direction 155 N while acoustic logs showed also anisotropy surfaces. The underburden shales ("argille basali") show different sedimentological features and diffuse slumping surfaces. The stress direction is similar for both shales, therefore an unique stress profile was needed throughout the layers and the mini-frac/stress tests were used to constraint the minimum horizontal stress. The geomechanical data allowed to derive reliable mechanical and failure parameters. The sand reservoir shows laminations with few fractures. From a geomechanical standpoint, these results allowed a statistical analysis of the main parameters, for the use in the subsequent modelling activities.An earlier integration approach was the key for the quality of a reservoir/sealing sequence characterization for the appropriate and safe storage operation. Scope of workThe option of delta-pressuring, exceeding the discovery pressure in a depleted gas storage field, is one of the most costeffective ways used by Stogit to increase working gas capacity and deliverability. The feasibility study of the "P>Pi Projects" needs to collect new and detailed information about geological and structural features of the field (Bruno et al., 1998).A geognostic well was recently drilled by Stogit in a gas storage field located in Central Italy, expressly targeted to acquire geological information, both in the reservoir and in the cap-rock units. The well will be besides equipped with downhole permanent microseismic and geodetic monitoring network, aimed to check the cap-rock strain and integrity, in order to minimize the risk of gas leakage through the weakest parts of the cap-rock.An integrated petrophysical and geomechanical study has been finally achieved, which contributed, together with the new interpretation ...

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“…The growth of a tensile fracture, possibly into a shale caprock during gas injection would have a detrimental influence on the effectiveness of the reservoir for gas storage. Other risks resulting from high bottomhole pressures, such as shear failure at the reservoir-caprock interface (e.g., Bruno et al 13 ) and shear failure on pre-existing fracture or fault planes also exist, but these will not be discussed in this paper.…”

Section: Geomechanical Aspects Of Sand Productionmentioning

confidence: 99%

Sand Production Prediction for Horizontal Wells in Gas Storage Reservoirs

McLellan¹,

Hawkes²,

Read³

2000

SPE/CIM International Conference on Horizontal Well Technology

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractSand production and the sand control technique selected to mitigate or eliminate it can have a critical influence on the performance of horizontal wells in gas storage reservoirs. A completion that provides adequate sand control is usually required, but an overly conservative completion design can have an unnecessary, negative consequence on gas well productivity and injectivity. The selection of the appropriate sand control design depends on the characteristics of the reservoir formation, the in-situ stress state, the maximum and minimum values of the reservoir pressure during gas storage operations, the drawdown pressure, the near-well fluid saturations, the well trajectory and the capacity for handling sand in the well tubulars and surface facilities. This paper reviews the principal causes of sand production from borehole and perforation collapse, and demonstrates the application of commercial software programs for assessing sand production risks. The influence of formation damage, compressible and non-Darcy gas flow effects, reservoir pressure changes and rock strength reduction due to cyclic loading will be illustrated. Additional risks, such as exceeding the fracture breakdown pressure in the reservoir during injection, or collapsing weak, interbedded shale strata that are locally penetrated by the horizontal well, are also described. Numerical geomechanical modelling techniques suitable for more complex material behaviour and fluid flow phenomena are also described, as well as a novel procedure for estimating initial produced sand volumes.Several field examples are presented, illustrating results for reservoirs ranging from relatively strong rocks, in which no sand control is required, to poorly cemented sandstones which require gravel-packed or screened completions.

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Geomechanical analysis of pressure limits for gas storage reservoirs

Cited by 16 publications

References 0 publications

Numerical Modeling of a Potential Geological CO 2 Sequestration Site at Minden (Germany)

Numerical Modeling of a Potential Geological CO 2 Sequestration Site at Minden (Germany)

Looking For Earlier Integration: An Application Example

Sand Production Prediction for Horizontal Wells in Gas Storage Reservoirs

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