An Organofacies-Based Mudstone Classification for Unconventional Tight Rock &amp; Source Rock Plays

Donovan, Art D.; Evenick, Jonathan C.; Banfield, Laura A.; McInnis, Noel; Hill, William

doi:10.15530/urtec-2017-2715154

Cited by 16 publications

(4 citation statements)

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“…Together they represent 90%; the other 10% of the mass is composed of clay minerals and gypsum. With less than 50% of clay and more than 30% of carbonates in weight, this sample can be classified as a carbonate mudstone using the Donovan et al (2017) classification, which is usually associated with oil-prone organic matter.…”

Section: Resultsmentioning

confidence: 99%

On the evolution of artificially maturated hydrocarbon source rocks

Lacerda¹,

Mörschbächer²,

Justen³

et al. 2023

Front. Earth Sci.

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The elastic moduli are a function of properties that could vary between samples and change during maturation. Consequently, the effects of organic matter maturation on the elastic wave velocities of organic-rich rocks are challenging to describe. This work analyzes the isolated maturation effects on the organic content, pore volume, microstructure, and propagation velocities of elastic waves. To avoid any initial rock heterogeneity, we prepared a series of homogeneous samples from a unique outcrop block collected on the Eagle Ford formation with mineral composition initially determined using X-ray diffraction. From the initial set, four samples were held in their original condition and four were artificially maturated by hydropyrolysis until transformation rates were up to 95%. Then, the evolution of the sample properties was examined using an association of LECO TOC, Rock-Eval pyrolysis, vitrinite reflectance, mercury intrusion porosimetry (MIP), and ultrasonic pulse propagation. In addition, scanning electron microscopy images registered the microstructure evolution. To evaluate the effects of maturation on pore geometry and the organic matter elastic moduli, we analyze the relationship between the measured quantities using a rock physics inclusion model with the unmeasured properties taken as fitting parameters. The hydropyrolysis maturation increases the vitrinite reflectance from the initial 0.55% to 1.34% on the most matured sample. A total organic carbon reduction from 4.2% to 2.1% and a porosity increase from 9.2% to 21% are associated with observed maturation. The geochemical characterization on cleaned samples reveals an initial increment of soluble organic matter followed by a monotonical reduction related to oil migration out of bulk volume. The measurement of wave propagation velocities as a function of confining pressure displays an increasing pressure sensitivity with a downward trend in both velocity moduli. The petrophysical analysis indicates that the porosity increases through organic matter consumption and pore creation. The rock physics diagnoses indicate a decrease in the pore aspect ratio with an increase in the elastic modulus of the organic matter with maturation.

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Section: Resultsmentioning

confidence: 99%

On the evolution of artificially maturated hydrocarbon source rocks

Lacerda¹,

Mörschbächer²,

Justen³

et al. 2023

Front. Earth Sci.

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“…6−9 Vitrinite reflectance (R o ) values of 0.9 and 1.0% have been regarded as the critical conditions of medium-low and medium-high maturity in the in-depth exploration of shale oil and gas, respectively. 25,[6][7][8]10,26 The medium-and high-maturity shales have a high retained hydrocarbon content, with a high gas−oil ratio, low viscosity, and good fluidity. The hydrocarbons mainly remain in inorganic pores and abundant organic pores in the gaseous state.…”

Section: Introductionmentioning

confidence: 99%

“…The essence of shale oil and gas is the residual hydrocarbons in shale. , The generation, residue, and discharge of hydrocarbons in shales are controlled by their maturity, leading to significant differences in oil and gas properties in shales with different maturities. − Vitrinite reflectance ( R o ) values of 0.9 and 1.0% have been regarded as the critical conditions of medium-low and medium-high maturity in the in-depth exploration of shale oil and gas, respectively. ,− ,, The medium- and high-maturity shales have a high retained hydrocarbon content, with a high gas–oil ratio, low viscosity, and good fluidity. The hydrocarbons mainly remain in inorganic pores and abundant organic pores in the gaseous state. , The middle-low-maturity shales are enriched in organic matter, with a low hydrocarbon conversion rate.…”

Section: Introductionmentioning

confidence: 99%

Differences between the Hydrocarbon-Bearing Properties of Shales with Differing Maturities: Shahejie and Longmaxi Shales

Chen,

Huang,

Jiang

et al. 2024

Energy Fuels

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In order to better understand hydrocarbon enrichment in shales with various thermal maturities, we experimentally evaluate the geological characteristics of shales in the Third Member of the Shahejie Formation of the Bohai Bay Basin and draw comparisons with the Longmaxi shales in the Sichuan Basin. The kerogens in the Third Member and in the Longmaxi shales are mainly similar of types I and II and occur dominantly in micro-and nanopores. A difference in maturity results in significant differences in shale compositions, pore structure, and hydrocarbon enrichment characteristics. The Third Member shale contains a large proportion of high TOC material, and mesopores are dominant. The Longmaxi shales contain a large proportion of low TOC material, and nanoscale pores such as organic pores are common; the Longmaxi shales are also more brittle. The nanopores in medium-to high-mature Longmaxi shales have a large specific surface area, the high adsorption capacity of which clearly controls the accumulation and fluidity of hydrocarbons. Micromigration and accumulation of hydrocarbons in interlayers of middle-low-maturity shales are affected by pore structure and overpressure as well as by fault activity.

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“…Adapted from ref (public domain 2022). Sligo and Edwards shelf margins, clastic shelf margin,, 25% clay line,, and Frio River Line…”

Section: Introductionmentioning

confidence: 99%

Examining Water and Proppant Demand, and Produced Water Production, Associated with Petroleum Resource Development in the Eagle Ford Group, Texas

Gianoutsos,

Haines,

Varela

et al. 2024

Energy Fuels

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More than 20,000 horizontal wells have been drilled and hydraulically fractured in the Eagle Ford Group since the discovery well in 2008, but a considerable amount of undiscovered petroleum remains. Recently, drilled wells have been hydraulically fractured with an average of nearly 13 million gallons of water and 16 million lb of sand, yielding a million or more gallons of produced water. To inform future petroleum development in the Eagle Ford, the U.S. Geological Survey (USGS) conducted a water and proppant assessment using a geology-based approach that builds on the 2018 USGS assessment of undiscovered technically recoverable petroleum. Using probabilistic input values and a Monte Carlo simulation, we determined that production of the remaining undiscovered technically recoverable oil and gas in the Eagle Ford Group would require approximately 687,565 Mgal (millions of gallons) of water and 839,702,000,000 lb of proppant (both are mean values of output distributions). This possible future petroleum production would also include 176,817 Mgal (mean value) of produced formation water. On average, oil wells require water volumes that are approximately twice the volume of oil that will be produced, and Eagle Ford gas wells require approximately 5.21 Mgal of water per billion cubic feet of gas (bcfg). Produced formation water volumes are approximately 60% of the produced oil volume and, for gas wells, will yield approximately 1 Mgal formation water per bcfg. Understanding the water and proppant requirements associated with petroleum exploration and the resulting volume of produced water can inform decisions regarding the future of Eagle Ford development.

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An Organofacies-Based Mudstone Classification for Unconventional Tight Rock & Source Rock Plays

Cited by 16 publications

References 0 publications

On the evolution of artificially maturated hydrocarbon source rocks

On the evolution of artificially maturated hydrocarbon source rocks

Differences between the Hydrocarbon-Bearing Properties of Shales with Differing Maturities: Shahejie and Longmaxi Shales

Examining Water and Proppant Demand, and Produced Water Production, Associated with Petroleum Resource Development in the Eagle Ford Group, Texas

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