Hydraulic characterization of fractured carbonates for CO 2 geological storage: Experiences and lessons learned in Hontomín Technology Development Plant

Dios, J. Carlos de; Delgado, Miguel; Martínez, Carol; Ramos, Alberto; Álvarez, Iñaki; Marín, Juan Andrés; Salvador, Ignacio

doi:10.1016/j.ijggc.2017.01.008

Cited by 27 publications

(41 citation statements)

References 10 publications

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“…On the other hand, the values of some petrophysical properties determined by laboratory tests, as effective porosity, gas permeability and injections of CO2 and brine in reservoir conditions to assess the hydrodynamic and geochemical effects, revealed that fluid transmissivity is dominated by carbonate fractures, while the matrix does not appear to significantly contribute to the storage capacity. Results from subsequent tests conducted at field scale on site during the hydraulic characterization phase supported this assumption [de Dios et al, 2017].…”

Section: Geological Contextmentioning

confidence: 80%

“…A study on fractures characteristics in both wells was conducted during the well logging campaigns, which particularly focused on the reservoir strata [de Dios et al, 2017]. Data gained from acoustic televiewer during the performance of these works provided information about the type of fractures and their distribution [Collier and Ridder, 1992].…”

Section: Fracture Characterization and Modelingmentioning

confidence: 99%

“…The grid and its properties (facies, porosity, and permeability) for the matrix, the main horizons (Top Dogger, Top Lias, Top Calcareous Sopeña, and Top Keuper), the fault maps at Top Calcareous Sopeña and the well trajectories and logs (facies, porosity) are imported into FracaFlow™. All the fractures characteristics for HI and HA from televiewer log [de Dios et al, 2017] were also imported as fracture logs (type, dip and azimuth as a function of depth). As shown in Figure 4, 5 types of fractures (0,10,14,16,18) were identified from the Dogger to the well shoes (Sopena/Carniolas formations).…”

Section: Dfn Modelingmentioning

confidence: 99%

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Characterizing a Naturally-Fractured Carbonate Formation for a CO<sub>2</sub> Storage Operation

Gallo¹,

Dios²

2018

Preprint

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Investigation into geological storage of CO2 is underway at the Technology Development Plant (TDP) at Hontomín (Burgos, Spain), the only current onshore injection site in the European Union. The storage reservoir is a deep saline aquifer located within Low Jurassic Formations (Lias and Dogger), formed by fractured carbonates with low matrix permeability. Understanding the processes involved in CO2 migration within this kind of low-primary permeability carbonates influenced by fractures and faults is key to ensure safe operation and reliable plume prediction. During the hydraulic characterization tests, 2300 tons of liquid CO2 and 14000 m3 of synthetic brine were co-injected on site in various sequences to characterize the pressure response of the seal-storage pair [de Dios et al, 2017] The injection tests were analyzed with a compositional dual media model which accounts for both temperature effects (as the CO2 is liquid at the bottom of the wellbore) and multiphase flow hysteresis (to effectively simulate the alternating brine and CO2 injection tests that were performed). The pressure and temperature responses of the storage formation were history-matched mainly through the petrophysical characteristics of the fracture network [Le Gallo et al, 2017]. The dynamic characterization of the fracture network dominates the CO2 migration while the matrix does not appear to significantly contribute to the storage capacity. This initial modeling approach was improved using the characterization workflow developed within the European FP7 CO2ReMove project for sandstone fractured reservoirs [Ringrose et al., 2011; Deflandre et al., 2011]. Fractured reservoirs are challenging to handle because of their high level of heterogeneity that conditions the reservoir behaviour during the injection. In particular, natural fractures have a significant impact on well performance [Ray et al, 2012]. Furthermore, the understanding of the processes involved in CO2 migration within relatively low-permeability storage influenced by fractures and faults is essential for enabling safe storage operation [Iding and Ringrose, 2010]. As part of the European H2020 ENOS project, the site geological model is updated by integration of the recently acquired data such as the image log interpretations from injection and observation wells. The geological model is generated through the analysis and integration of data including borehole images and well test data. Following a methodology developed for naturally fractured hydrocarbon reservoirs [Ray et al., 2012], the image log analysis identified two sets of diffuse fractures. A Discrete Fracture Network [Bourbiaux et al., 2005] was built around both wells which encompass the caprock, storage and underburden formations. The fracture characteristics of the two sets of diffuse fractures, such as orientations, densities and conductivities, are calibrated upon the interpretation of the injection tests [Le Gallo et al, 2017]. For each facies, the DFN characteristics were then upscaled and propagated to the full-field reservoir simulation model as 3D fracture properties (fracture porosity, fracture permeability and equivalent block size).

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Section: Geological Contextmentioning

confidence: 80%

Section: Fracture Characterization and Modelingmentioning

confidence: 99%

Section: Dfn Modelingmentioning

confidence: 99%

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Characterizing a Naturally-Fractured Carbonate Formation for a CO<sub>2</sub> Storage Operation

Gallo¹,

Dios²

2018

Preprint

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“…Por seguridad de la operación, la presión y caudal de inyección deberán estar limitados por el valor que genere una respuesta que sea superior al umbral sísmico admisible (de Dios et al 2017). Determinar dicho umbral no es sencillo, ya que se requiere identificar dicho nivel en el entorno de la planta de almacenamiento geológico de dióxido de carbono.…”

Section: 23-tipología De Ensayos De Inyección a Escala Industrialunclassified

“…Este incremento apoya la suposición de que efectos de reactividad geoquímica producidos por la inyección de mezclas de salmuera y CO2, probablemente por migración iónica, se han producido en el reservorio tal como sugerían los análisis de pH y cromatografía iónica del agua de formación. La permeabilidad en la matriz de poros calculada es de 2 mD, lo que refleja una clara tendencia de entrampamiento en las fracturas (de Dios et al 2017)  Se ha desarrollado un modelo dinámico 3D preliminar que requiere de futuros ajustes para que tenga capacidad de predecir distintos escenarios realistas de migración de la pluma de CO2 en la Planta Piloto de Hontomín.…”

Section: -Discusiónunclassified

Criterios para el diseño, la ejecución y el control de técnicas de inyección de CO2 en almacenes geológicos carbonatados fracturados de baja permeabilidad en la matriz de poros

González¹,

de²

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The geological storage of carbon dioxide is a technology under development, being its main goal the gas sequestration in deep geological formations. CO2 is captured from industrial sites where fossil fuel combustion is used in the processes, transported by pipe line, ship or container truck to the storage sites, in order to be injected in the geological formations in a permanent trapping. Criteria for the design of efficient and safe CO2 injection strategy in fractured carbonates with low matrix permeability are discussed in this thesis. Information for the industrial process development and its monitoring to ensure safety is provided (National Patent nº 201500151) CO2 migration occurs mainly through the existing fracture networks and those ones induced by the effects of injection of several fluids in the reservoirs with low matrix porosity. These effects occur during the hydraulic characterization and operation, producing a high anisotropy level in the reservoir behavior. Moreover, for geological formations like carbonates, the mixture of carbon dioxide and brine chemically reacts with the rock in the reservoir producing relevant changes on injection parameters. The injection of brine and CO2 induces changes on geomechanical properties of fractures and in the composition of materials of their fillings. Permeability increases due to hydrodynamic effects produced by the injection and the geochemical reactivity among this mixture and the rock of the deep saline aquifer, producing a dynamic behavior of the reservoir which involves different operational conditions for each stage of the project life. The design, operation and monitoring of a CO2 injection strategy in conditions of transport by pipeline are discussed in the thesis, considering the results from the well drilling and logging tests, petrophysical laboratory works, hydraulic characterization campaigns and CO2 injections in real life conditions. The model refining and the development of new codes for interpreting the multiphase flow effects in the fractures and the associated chemical reactivity in the reservoir are analyzed as well. The criteria exposed have been established according to the results of experimental works conducted by the Ph.D student in the Technology Development Plant for CO2 Geological Storage located in Hontomín (Burgos), owned by Fundación Ciudad de la Energía (CIUDEN).

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The effect of Biot coefficient and elastic moduli stress–pore pressure dependency on poroelastic response to fluid injection: laboratory experiments and geomechanical modeling

2020

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Biot coefficient and elastic moduli are typically assumed to have a constant value for analyzing poroelastic effects of fluid injection. To investigate the stress-pore pressure dependency of Biot coefficient and elastic moduli, we conducted a series of laboratory experiments on a porous dolomite core sample from a reef in Michigan basin. We varied the confining stress as well as the pore pressure in the experiments. Then, modeling was performed using analytical poroelastic solutions and a coupled two-phase flow-geomechanical numerical simulation (for CO 2 injection). The modeling results show that the variability of Biot coefficient and elastic moduli should be included in the geomechanical modeling to accurately predict the poroelastic responses of injection (i.e., stress changes and surface uplift). Using a constant stress-independent Biot coefficient elastic moduli, which is the assumption in poroelastic modeling, leads to underestimation of the stress change and surface uplift due to injection compared to a realistic stress-pore pressure dependent Biot coefficient, which is updated at each time step of injection modeling. Modeling results indicate that decreasing elastic modulus combined with Biot coefficient increase due to the fluid injection could lead to a larger surface uplift and stress changes in the reservoir. In addition, the stress changes and uplift due to injection are a function of initial in situ stress due to Biot coefficient and elastic modulus stress-pore pressure dependency.

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Hydraulic characterization of fractured carbonates for CO 2 geological storage: Experiences and lessons learned in Hontomín Technology Development Plant

Cited by 27 publications

References 10 publications

Characterizing a Naturally-Fractured Carbonate Formation for a CO<sub>2</sub> Storage Operation

Characterizing a Naturally-Fractured Carbonate Formation for a CO<sub>2</sub> Storage Operation

Criterios para el diseño, la ejecución y el control de técnicas de inyección de CO2 en almacenes geológicos carbonatados fracturados de baja permeabilidad en la matriz de poros

The effect of Biot coefficient and elastic moduli stress–pore pressure dependency on poroelastic response to fluid injection: laboratory experiments and geomechanical modeling

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