An image-based equation for estimating the prospective CO2 storage resource of organic-rich shale formations

Azenkeng, Alexander; Mibeck, Blaise A.F.; Kurz, Bethany A.; Gorecki, Charles D.; Myshakin, Evgeniy M.; Goodman, Angela; Azzolina, Nicholas A.; Eylands, Kurt E.; Butler, Shane K.; Sanguinito, Sean

doi:10.1016/j.ijggc.2020.103038

Cited by 14 publications

(11 citation statements)

References 20 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…69 According to Azenkeng et al, there are several challenges regarding storage capacity estimation based on shale reservoirs. 70 Factors that control the CO 2 storage in organic-rich shales are matrix pore spaces, and natural and induced fractures, which are not easily differentiated. 70 Table 3 summarizes the variables engaged for the storage capacity estimation in the organic-rich shale Unit E of Irati Formation within Block 4.…”

Section: Capacity Estimation and Classificationmentioning

confidence: 99%

“…70 Factors that control the CO 2 storage in organic-rich shales are matrix pore spaces, and natural and induced fractures, which are not easily differentiated. 70 Table 3 summarizes the variables engaged for the storage capacity estimation in the organic-rich shale Unit E of Irati Formation within Block 4. The calculated porosity of 6.1% based on well 1) connotes the natural fractures and pore spaces.…”

Section: Capacity Estimation and Classificationmentioning

confidence: 99%

“…The DOE NETL's equation for shales was utilized for the estimation of the CO 2 mass storage (Levine et al 2016). Nevertheless, several challenges regarding the storage resource estimation of shale reservoirs are pointed out by Azenkeng et al (2020). The key factors that control the CO 2 storage in organic-rich shales are matrix pore spaces, and natural and induced fractures, and it is very di cult to differentiate them (Azenkeng et al 2020).…”

Section: Capacity Estimation and Classificationmentioning

confidence: 99%

See 2 more Smart Citations

3D implicit modeling applied to the evaluation of CO₂ geological storage in the shales of the Irati Formation, Paraná Basin, Southeastern Brazil

et al. 2021

View full text Add to dashboard Cite

The Paris Agreement established global ambitious targets for reducing carbon dioxide (CO 2 ) emissions, requiring the rapid and extensive development of low carbon technologies, and one of the most efficient is CO 2 geological storage. Among the deep geological formations used for CO 2 storage, the shale layers have been a new emerging field with higher efficiency because they are abundant and have a high content of organic matter that is favorable for CO 2 retention. However, one of the challenges in evaluating a location for potentials reservoirs is the adequate geological characterization and storage volume estimation. The study evaluates the Irati Formation of the Paraná Basin based on wireline logs information within Southeastern Brazil, where most stationary sources of carbon emissions are located. Three-dimensional (3D) implicit modeling techniques were applied not only for volume calculation purpose, but also in the site selection stage, generating thematic 3D models indicating thickness, depth, structures, and distance to aquifer systems. The limestones, shales, and black shales of the Irati Formation were locally grouped into six units considering the geological composition and spatial continuity. Based on the 3D model and reservoir parameters, the organic-rich shale Unit E with a theoretical capacity of 1.85 Gt is considerable for CO 2 storage. The estimated CO 2 storage capacity is promising because it is higher than the total CO 2 locally produced, and it could support the implantation of new projects in this region.

show abstract

Section: Capacity Estimation and Classificationmentioning

confidence: 99%

Section: Capacity Estimation and Classificationmentioning

confidence: 99%

Section: Capacity Estimation and Classificationmentioning

confidence: 99%

See 1 more Smart Citation

3D implicit modeling applied to the evaluation of CO₂ geological storage in the shales of the Irati Formation, Paraná Basin, Southeastern Brazil

et al. 2021

View full text Add to dashboard Cite

show abstract

Section: Capacity Estimation and Classificationmentioning

confidence: 99%

“…70 Factors that control the CO 2 storage in organic-rich shales are matrix pore spaces, and natural and induced fractures, which are not easily differentiated. 70 Table 3 summarizes the variables engaged for the storage capacity estimation in the organic-rich shale Unit E of Irati Formation within Block 4. The calculated porosity of 6.1% based on well 2-TB-1-SP within the Unit E (Table 1) connotes the natural fractures and pore spaces.…”

Section: Capacity Estimation and Classificationmentioning

confidence: 99%

3D implicit modeling applied to the evaluation of CO2 geological storage in the shales of the Irati Formation, Paraná Basin, Southeastern Brazil

Oliveira

Tassinari

A-A.

et al. 2021

Preprint

View full text Add to dashboard Cite

The Paris Agreement established global ambitious targets for reducing carbon dioxide (CO2) emissions, requiring the rapid and extensive development of low carbon technologies, and one of the most efficient is CO2 geological storage. Among the deep geological formations used for CO2 storage, the shale layers have been a new emerging topic showing to be efficient because they are abundant and have a high content of organic matter, being favorable for CO2 retention. However, one of the challenges in evaluating a location for possible reservoirs is the adequate geological characterization and storage volume estimates. This research evaluated the Irati Formation of the Paraná Basin, through the information from hydrocarbon exploration wells in Southeastern Brazil, where most stationary sources of carbon emissions are located. Three-dimensional (3D) implicit modeling techniques were applied not only for the volume calculation purpose, but also in the site selection stage, generating thematic 3D models of thickness, depth, structures, and distance to aquifer systems. The limestones, shales, and black shales of the Irati Formation were locally divided into six units according to geological composition and spatial continuity. The E black shale unit was considered for CO2 geological storage indicating a theoretical capacity of 1.85 Gt of CO2. The potential of the achieved capacity is promising not only for been greater than the total of CO2 locally produced but also for supporting the implantation of new projects in this region.

show abstract

Pore morphology effect on elastic and fluid flow properties in Bakken formation using rock physics modeling

Ozotta

Saberi²,

Kolawole

et al. 2022

Geomech. Geophys. Geo-energ. Geo-resour.

View full text Add to dashboard Cite

Unconventional geo-resources are critical due to their important contributions to energy production. In this energy transition and sustainability era, there is an increased focus on CO2-enhanced oil recovery (CO2-EOR) and geological CO2 storage (GCS) in unconventional hydrocarbon reservoirs, and the extraction of hot fluid for energy through enhanced geothermal systems. However, these energy solutions can only be achieved through efficient stimulation to develop a complex fracture network and pore structure in the host rocks to extract heat and hydrocarbon, or for CO2 storage. Using Bakken formation well data and rock physics models, this study aimed to identify the post-depositional effect of pore structure on seismic velocity, elastic moduli, and formation fluid; and further predict the best lithofacies interval for well landing, and the implications for fluid (gas, oil, and water) recovery in naturally- and often systematically-fractured geosystems. The KT and DEM models' predictions show distinct formation intervals exhibiting needle-like pores and having higher seismic velocities (Vp and Vs) and elastic moduli (K and µ), relative to other formation intervals that exhibit moldic pores. At the same fluid concentration, the needle-like pores (small aspect ratios) have a higher impact on elastic moduli, Vp, and Vs than on the moldic spherical pores with all other parameters held constant. Vp is affected more than Vs by the properties of the saturating fluid (gas, oil, or water) with Vp being greater in Bakken formation when it is water-saturated than when it is gas-saturated. Vs exhibit the reverse behavior, with Vs greater in the gas-saturated case than in the water-saturated case. Further, analyses suggest that the middle Bakken formation will have a higher susceptibility to fracturing and faulting, and hence will achieve greater fluid (oil and water) recovery. Our findings in this study provide insights that are relevant for fluid production and geo-storage in unconventional reservoirs. Article highlights Integrated well log data and rock physics models. Investigated the effect of changes in pore structure on elastic properties and fluid flow in shale. Increase in porosity causes a reduction in elastic moduli and seismic velocities. Vp is more affected by pore geometry than Vs depending on density and properties of saturating fluid. Lithofacies with needle−like pores are more susceptible to fracturing than lithofacies with intragranular pores.

show abstract

An image-based equation for estimating the prospective CO2 storage resource of organic-rich shale formations

Cited by 14 publications

References 20 publications

3D implicit modeling applied to the evaluation of CO₂ geological storage in the shales of the Irati Formation, Paraná Basin, Southeastern Brazil

3D implicit modeling applied to the evaluation of CO₂ geological storage in the shales of the Irati Formation, Paraná Basin, Southeastern Brazil

3D implicit modeling applied to the evaluation of CO2 geological storage in the shales of the Irati Formation, Paraná Basin, Southeastern Brazil

Pore morphology effect on elastic and fluid flow properties in Bakken formation using rock physics modeling

Contact Info

Product

Resources

About