scholarly journals Compositional characterization and storage capacity of shale samples from La Luna and Conejo Formations (Middle Magdalena basin and the Eastern Cordillera): Implications for evaluation of cretaceous shale gas in Colombia

2015 ◽  
pp. 45-53 ◽  
Author(s):  
Paula Andrea Pacheco Sintura ◽  
Agustín Cardona Molina ◽  
Farid B. Cortés
Keyword(s):  
Shale Gas ◽  
Storage Capacity ◽  
Total Porosity ◽  
Organic Content ◽  
Gas Reservoir ◽  
Eastern Cordillera ◽  
And Storage ◽  
Compositional Characterization ◽  
Petroleum Source Rock ◽  
La Luna

Shale gas has become a major non-conventional energetical resource. La Luna Formation which is commonly considered as the main petroleum source rock, have also shown to be a major reservoir for shale gas resources. In order to understand the "real" potential of this unit and define exploration strategies, the correlation between compositional and petrophysical patterns. We have analyzed 11 shale samples from La Luna and Conejo Formation in the Middle Magdalena basin and the Eastern Cordillera in order to established its composition, total organic contents, thermal maturity, as well as its total porosity and adsorption capacity. Obtained results suggest that due to its organic content, the presence of quartz and carbonate that these shales have a good quality as a gas reservoir and may have also a moderately good behavior during fracturing.

scholarly journals Total Porosity Measured for Shale Gas Reservoir Samples: A Case from the Lower Silurian Longmaxi Formation in Southeast Chongqing, China

Minerals ◽  
2018 ◽  
Vol 9 (1) ◽  
pp. 5 ◽  
Author(s):  
Fangwen Chen ◽  
Shuangfang Lu ◽  
Xue Ding ◽  
Hongqin Zhao ◽  
Yiwen Ju
Keyword(s):  
Shale Gas ◽  
Clay Content ◽  
Total Porosity ◽  
Gas Reservoir ◽  
Longmaxi Formation ◽  
Fine Grained ◽  
Average Value ◽  
Lower Silurian ◽  
Shale Gas Reservoir ◽  
Research Institute

Measuring total porosity in shale gas reservoir samples remains a challenge because of the fine-grained texture, low porosity, ultra-low permeability, and high content of organic matter (OM) and clay mineral. The composition content porosimetry method, which is a new method for the evaluation of the porosity of shale samples, was used in this study to measure the total porosity of shale gas reservoir samples from the Lower Silurian Longmaxi Formation in Southeast Chongqing, China, based on the bulk and grain density values. The results from the composition content porosimetry method were compared with those of the Gas Research Institute method. The results showed that the composition content porosimetry porosity values of shale gas reservoir samples range between 2.05% and 5.87% with an average value of 4.04%. The composition content porosimetry porosity generally increases with increasing OM and clay content, and decreases with increasing quartz and feldspar content. The composition content porosimetry results are similar to the gas research institute results, and the differences between the two methods range from 0.05% to 1.52% with an average value of 0.85%.

Shale Gas-in-Place Calculations Part I: New Pore-Scale Considerations

SPE Journal ◽  
2011 ◽  
Vol 17 (01) ◽  
pp. 219-229 ◽  
Author(s):  
Ray J. Ambrose ◽  
Robert C. Hartman ◽  
Mery Diaz-Campos ◽  
I. Yucel Akkutlu ◽  
Carl H. Sondergeld
Keyword(s):  
Shale Gas ◽  
Organic Material ◽  
Storage Capacity ◽  
Pore Space ◽  
Ion Beam ◽  
Gas Storage ◽  
Organic Content ◽  
Free Gas ◽  
Adsorbed Phase ◽  
Small Pore

Summary Using focused-ion-beam (FIB)/scanning-electron-microscope (SEM) imaging technology, a series of 2D and 3D submicroscale investigations revealed a finely dispersed porous organic (kerogen) material embedded within an inorganic matrix. The organic material has pores and capillaries having characteristic lengths typically less than 100 nm. A significant portion of total gas in place appears to be associated with interconnected large nanopores within the organic material. Thermodynamics (phase behavior) of fluids in these pores is quite different; gas residing in a small pore or capillary is rarefied under the influence of organic pore walls and shows a different density profile. This raises serious questions related to gas-in-place calculations: Under reservoir conditions, what fraction of the pore volume of the organic material can be considered available as free gas, and what fraction is taken up by the adsorbed phase? How accurately is the shale-gas storage capacity estimated using the conventional volumetric methods? And finally, do average densities exist for the free and the adsorbed phases? We combine the Langmuir adsorption isotherm with the volumetrics for free gas and formulate a new gas-in-place equation accounting for the pore space taken up by the sorbed phase. The method yields a total-gas-in-place prediction. Molecular dynamics simulations involving methane in small carbon slit-pores of varying size and temperature predict density profiles across the pores and show that (a) the adsorbed methane forms a 0.38-nm monolayer phase and (b) the adsorbed-phase density is 1.8–2.5 times larger than that of bulk methane. These findings could be a more important consideration with larger hydrocarbons and suggest that a significant adjustment is necessary in volume calculations, especially for gas shales high in total organic content. Finally, using typical values for the parameters, calculations show a 10–25% decrease in total gas-storage capacity compared with that using the conventional approach. The role of sorbed gas is more important than previously thought. The new methodology is recommended for estimating shale gas in place.

A Model To Estimate Carbon Dioxide Injectivity and Storage Capacity for Geological Sequestration in Shale Gas Wells

2015 ◽  
Vol 49 (15) ◽  
pp. 9222-9229 ◽  
Author(s):  
Ryan W. J. Edwards ◽  
Michael A. Celia ◽  
Karl W. Bandilla ◽  
Florian Doster ◽  
Cynthia M. Kanno
Keyword(s):  
Carbon Dioxide ◽  
Shale Gas ◽  
Storage Capacity ◽  
Gas Wells ◽  
Geological Sequestration ◽  
And Storage

scholarly journals Fractal Characteristics of Pores in the Longtan Shales of Guizhou, Southwest China

Geofluids ◽  
2020 ◽  
Vol 2020 ◽  
pp. 1-16
Author(s):  
Yuqi Huang ◽  
Peng Zhang ◽  
Jinchuan Zhang ◽  
Xuan Tang ◽  
Chengwei Liu ◽  
...  
Keyword(s):  
Organic Matter ◽  
Fractal Dimension ◽  
Pore Structure ◽  
Shale Gas ◽  
Storage Capacity ◽  
Evaluation Criteria ◽  
Fractal Dimensions ◽  
Gas Absorption ◽  
Relative Pressure ◽  
And Storage

The pore structure of marine-continental transitional shales from the Longtan Formation in Guizhou, China, was investigated using fractal dimensions calculated by the FHH (Frenkel-Halsey-Hill) model based on low-temperature N2 adsorption data. Results show that the overall D 1 (fractal dimension under low relative pressure, P / P 0 ≤ 0.5 ) and D 2 (fractal dimension under high relative pressure, P / P 0 > 0.5 ) values of Longtan shales were relatively large, with average values of 2.7426 and 2.7838, respectively, indicating a strong adsorption and storage capacity and complex pore structure. The correlation analysis of fractal dimensions with specific surface area, average pore size, and maximum gas absorption volume indicates that D 1 can comprehensively characterize the adsorption and storage capacity of shales, while D 2 can effectively characterize the pore structure complexity. Further correlation among pore fractal dimension, shale organic geochemical parameters, and mineral composition parameters shows that there is a significant positive correlation between fractal dimensions and organic matter abundance as well as a complex correlation between fractal dimension and organic matter maturity. Fractal dimensions increase with an increase in clay mineral content and pyrite content but decrease with an increase in quartz content. Considering the actual geological evaluation and shale gas exploitation characteristics, a lower limit for D 1 and upper limit for D 2 should be set as evaluation criteria for favorable reservoirs. Combined with the shale gas-bearing property test results of Longtan shales in Guizhou, the favorable reservoir evaluation criteria are set as D 1 ≥ 2.60 and D 2 ≤ 2.85 . When D 1 is less than 2.60, the storage capacity of the shales is insufficient. When D 2 is greater than 2.85, the shale pore structure is too complicated, resulting in poor permeability and difficult exploitation.

scholarly journals Investigating Influential Factors of the Gas Absorption Capacity in Shale Reservoirs Using Integrated Petrophysical, Mineralogical and Geochemical Experiments: A Case Study

Energies ◽  
2018 ◽  
Vol 11 (11) ◽  
pp. 3078 ◽  
Author(s):  
Zhuoying Fan ◽  
Jiagen Hou ◽  
Xinmin Ge ◽  
Peiqiang Zhao ◽  
Jianyu Liu
Keyword(s):  
Shale Gas ◽  
Total Porosity ◽  
Organic Content ◽  
Absorption Capacity ◽  
Influential Factors ◽  
Gas Absorption ◽  
Gas Content ◽  
Adsorbed Gas ◽  
Shale Reservoirs ◽  
Gas Volume

Estimating in situ gas content is very important for the effective exploration of shale gas reservoirs. However, it is difficult to choose the sensitive geological and geophysical parameters during the modeling process, since the controlling factors for the abundance of gas volumes are often unknown and hard to determine. Integrated interdisciplinary experiments (involving petrophysical, mineralogical, geochemical and petrological aspects) were conducted to search for the influential factors of the adsorbed gas volume in marine gas shale reservoirs. The results showed that in shale reservoirs with high maturity and high organic content that the adsorbed gas volume increases, with an increase in the contents of organic matter and quartz, but with a decrease in clay volume. The relationship between the adsorbed gas content and the total porosity is unclear, but a strong relationship between the proportions of different pores is observed. In general, the larger the percentage of micropores, the higher the adsorbed gas content. The result is illuminating, since it may help us to choose suitable parameters for the estimation of shale gas content.

Mechanical properties of shale-gas reservoir rocks — Part 1: Static and dynamic elastic properties and anisotropy

Geophysics ◽  
2013 ◽  
Vol 78 (5) ◽  
pp. D381-D392 ◽  
Author(s):  
Hiroki Sone ◽  
Mark D. Zoback
Keyword(s):  
Elastic Properties ◽  
Shale Gas ◽  
Organic Content ◽  
S Wave ◽  
Gas Reservoir ◽  
Reservoir Rocks ◽  
Shale Gas Reservoir ◽  
Static Modulus ◽  
Static Young’S Modulus ◽  
Dynamic Elastic Properties

Understanding the controls on the elastic properties of reservoir rocks is crucial for exploration and successful production from hydrocarbon reservoirs. We studied the static and dynamic elastic properties of shale gas reservoir rocks from Barnett, Haynesville, Eagle Ford, and Fort St. John shales through laboratory experiments. The elastic properties of these rocks vary significantly between reservoirs (and within a reservoir) due to the wide variety of material composition and microstructures exhibited by these organic-rich shales. The static (Young’s modulus) and dynamic (P- and S-wave moduli) elastic parameters generally decrease monotonically with the clay plus kerogen content. The variation of the elastic moduli can be explained in terms of the Voigt and Reuss limits predicted by end-member components. However, the elastic properties of the shales are strongly anisotropic and the degree of anisotropy was found to correlate with the amount of clay and organic content as well as the shale fabric. We also found that the first-loading static modulus was, on average, approximately 20% lower than the unloading/reloading static modulus. Because the unloading/reloading static modulus compares quite well to the dynamic modulus in the rocks studied, comparing static and dynamic moduli can vary considerably depending on which static modulus is used.

scholarly journals Correction to A Model To Estimate Carbon Dioxide Injectivity and Storage Capacity for Geological Sequestration in Shale Gas Wells

2020 ◽  
Vol 54 (16) ◽  
pp. 10383-10383
Author(s):  
Ryan W. J. Edwards ◽  
Michael A. Celia ◽  
Karl W. Bandilla ◽  
Florian Doster ◽  
Cynthia M. Kanno
Keyword(s):  
Carbon Dioxide ◽  
Shale Gas ◽  
Storage Capacity ◽  
Gas Wells ◽  
Geological Sequestration ◽  
And Storage

Gas transport and storage capacity in shale gas reservoirs – A review. Part A: Transport processes

2015 ◽  
Vol 12 ◽  
pp. 87-122 ◽  
Author(s):  
Yves Gensterblum ◽  
Amin Ghanizadeh ◽  
Robert J. Cuss ◽  
Alexandra Amann-Hildenbrand ◽  
Bernhard M. Krooss ◽  
...  
Keyword(s):  
Shale Gas ◽  
Storage Capacity ◽  
Gas Transport ◽  
Transport Processes ◽  
Gas Reservoirs ◽  
Shale Gas Reservoirs ◽  
And Storage

scholarly journals Design, construction and testing of a floating hood biodigester prototype for municipal waste organic waste

2021 ◽  
pp. 22-29
Author(s):  
Dulce Carolina Acosta-Pintor ◽  
Cuitláhuac Mojica-Mesinas ◽  
Eleazar Vidal-Becerra ◽  
Jonathan de Jesús Constantino González-Zarazúa
Keyword(s):  
Organic Waste ◽  
Storage Capacity ◽  
Calorific Value ◽  
Organic Residues ◽  
Gas Reservoir ◽  
Operation Test ◽  
Waste Mixture ◽  
And Storage ◽  
Blue Coloration ◽  
Design Construction

This paper documented the design, construction and operation test of a floating hood biodigester prototype, using organic residues (ruminal content, blood, bovine excreta and viscera) from the municipal trail of Ciudad Valles, S.L.P., with the purpose of generating biogas. The components of the biodigester system considered were: loading duct, concrete biodigester tank, biogas pipeline, floating hood, gas reservoir, discharge duct and discharge tank. A biodigester with storage capacity in the 0.178 m3 floating hood was designed for a 30-day trial operation and storage of 0.120 m3 of organic waste mixture in the biodigester tank. As of day 17 of operation the daily average of biogas generated was 0.1801 m3. The composition of the biogas at day 30 of operation, showed a content of 59.4% of CH4. When performing the flame test, an intense blue coloration was obtained, which indicates that the biogas produced has a high calorific value that will allow heating and flammability.

Pore Characterization of the Marcellus Shale by Nitrogen Adsorption and Prediction of Its Gas Storage Capacity

2021 ◽  
pp. 1-59
Author(s):  
Yixuan Zhu ◽  
Timothy Carr ◽  
Zhongmin Zhang ◽  
Liaosha Song
Keyword(s):  
Shale Gas ◽  
Storage Capacity ◽  
Marcellus Shale ◽  
Nitrogen Adsorption ◽  
Well Logging ◽  
Gas Storage ◽  
Micropore Volume ◽  
Organic Content ◽  
Type I ◽  
Pore Characterization

In a shale gas reservoir, pore characterization is an important factor to determine gas storage capacity. However, the nanometer (nm) scale pore system in shale is difficult to explore by traditional optical, scanning electron microscopy (SEM) or even nuclear magnetic resonance (NMR) well logging. We investigated the pore structure and storage capacity of the Marcellus Shale through integration of petrophysical analysis from lab and well logging data, and nitrogen adsorption. The isotherm of Marcellus Shale is a composite isotherm, which has features of Type I, Type II and Type IV isotherms with Type H4 of hysteresis loop, suggesting slit-like pores developed in the Marcellus Shale. Quantitative analysis of pore volumes from the nitrogen adsorption indicates that density porosity may be more proper to approximate shale porosity and estimating the shale gas volume. In addition, the specific surface area, micropore and mesopore volumes have positive relationship with kerogen volume and total organic content (TOC). By employing Langmuir and Brunauer-Emmet-Teller (BET) models, simulated result indicates that higher adsorbed quantity of the Marcellus Shale could be the result of increase of micropore volume contributed, by increase of kerogen or TOC content. The proposed equations rapidly compute TOC, a key parameter to predict gas storage capacity in over-matured shale such as the Marcellus Shale.

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