Evaluation of Shale Source Rocks and Clay Mineral Diagenesis in the Permian Basin, USA: Inferences on Basin Thermal Maturity and Source Rock Potential

Green, Hunter; Šegvić, Branimir; Zanoni, Giovanni; Omodeo-Salé, Silvia; Adatte, Thierry

doi:10.3390/geosciences10100381

Cited by 14 publications

(4 citation statements)

References 105 publications

(210 reference statements)

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“…This is consistent with previous studies (e.g. Green et al, 2020;Ferreiro-Mählmann et al, 2012 and references therein) which have demonstrated that clay minerals are slow to react to hydrothermal influences in comparison to organic matter.…”

Section: Controls On the Maturity Of The Fahdene And Bahloul Formation Source Rockssupporting

confidence: 93%

Maturity of Potential Cretaceous Source Rocks at the Isis Field, Offshore Eastern Tunisia: Influence of Hydrothermal Fluids

Kort

Elmola

Ouazaa

et al. 2021

Journal of Petroleum Geology

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An increase in source rock thermal maturity is in general linked to burial‐related heating according to the regional geothermal gradient, but maturities may also locally be influenced by high‐temperature hydrothermal fluids or igneous intrusions. In the present study of the Isis field located in the Gulf of Gabes (offshore Tunisia), we combine an analysis of organic matter maturity indicators and clay mineral signatures to constrain possible fluid/rock interactions and to define controls on the maturity of potential source rocks. Cuttings samples were collected from source rock intervals in the Cretaceous Bahloul (Cenomanian – Turonian) and underlying Fahdene (Albian – Cenomanian) Formations at the PM borehole, and detailed organic geochemical and clay mineralogical analyses of source rock samples and extracts were carried out. Samples from the Bahloul Formation (2381 m to 2400 m) consist of black to dark grey claystones and globigerinid limestones. Those from the Fahdene Formation (2400 m to 2700 m) comprise alternating claystones and chalky limestones containing globigerinids including Ticinella primula. Both source rock intervals have similar mineralogical compositions consisting of calcite, quartz, albite, anorthite, minor anatase, pyroxene and pyrite. The clay mineralogy of the formations is composed of abundant smectite (two generations), subordinate kaolinite and minor illite and/or mica. The Fahdene source rock contains organic matter consisting of mixed kerogen Types II/III; Type II OM is present in the Bahloul Formation.At the borehole location, the source rock intervals in the Fahdene and Bahloul Formations have been affected by hydrothermal fluids which are derived from an unconformably overlying basalt succession which is >300 m thick. Based on bulk mineral assemblages, the Bahloul Formation has been modified by the hydrothermal fluids more significantly than the underlying Fahdene Formation. Analyses of the clay minerals compositions indicate that interactions between the hydrothermal fluids and the host rocks were very rapid and were localized within fractures and micropores. The Bahloul Formation source rocks have reached an advanced stage of thermal maturity (overmature or end‐ oil window) compared to the thermally immature source rocks in the Fahdene Formation.The results show that the main control on source rock maturation at the studied well was maximum palaeotemperature and this may locally have been influenced by short‐term hydrothermal and magmatic heating as well as by the regional geotherm. Clay minerals were less affected by hydrothermal heating compared to organic matter indices; this may be because mineral components are slower to react to short‐term higher temperature conditions than organic matter.Thus magmatic activity and hydrothermal fluids may locally accelerate the thermal maturation of source rocks even at shallow depths. The study also shows that a combination of clay mineral characterization and organic matter indicators can be useful for the assessment of thermal maturity in potential source rocks.

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Section: Controls On the Maturity Of The Fahdene And Bahloul Formation Source Rockssupporting

confidence: 93%

Maturity of Potential Cretaceous Source Rocks at the Isis Field, Offshore Eastern Tunisia: Influence of Hydrothermal Fluids

Kort

Elmola

Ouazaa

et al. 2021

Journal of Petroleum Geology

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“…Figure 1. A structural map of the Permian Basin on the left (modified from [13]) and stratigraphic columns on the right (after [14]). Figure 1.…”

Section: Data Acquisitionmentioning

confidence: 99%

3D VSP Imaging Using DAS Recording of P- and S-Waves in Vertical and Lateral Well Sections in West Texas

Wang,

Stewart

2024

Sensors

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A 3D vertical seismic profiling (VSP) survey was acquired using a distributed acoustic sensing (DAS) system in the Permian Basin, West Texas. In total, 682 shot points from a pair of vibroseis units were recorded using optical fibers installed in a 9000 ft (2743 m) vertical part and 5000 ft (1524 m) horizontal reach of a well. Transmitted and reflected P, S, and converted waves were evident in the DAS data. From first-break P and S arrivals, we found average P-wave velocities of approximately 14,000 ft/s (4570 m/s) and S-wave velocities of 8800 ft/s (3000 m/s) in the deep section. We modified the conventional geophone VSP processing workflow and produced P–P reflection and P–S volumes derived from the well’s vertical section. The Wolfcamp formation can be seen in two 3D volumes (P–P and P–S) from the vertical section of the well. They cover an area of 3000 ft (914 m) in the north–south direction and 1500 ft (460 m) in the west–east direction. Time slices showed coherent reflections, especially at 1.7 s (~11,000 ft), which was interpreted as the bottom of the Wolfcamp formation. Vp/Vs values from 2300 ft (701 m) –8800 ft (2682 m) interval range were between 1.7 and 2.0. These first data provide baseline images to compare to follow-up surveys after hydraulic fracturing as well as potential usefulness in extracting elastic properties and providing further indications of fractured volumes.

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“…The outcome for core-extract samples (0.93 to 0.94 VREQ) are very similar to the result for extracted oil samples (~ 0.94 VREQ). Gas maturity which is conditioned on ethane / propane carbon isotopes (VREG) (GeoMark proprietary isotope/maturity calibration scale) has an average of approximately 0.93 for samples core head-space [11]. The average saturates/aromatics ratio samples and low asphaltenes sulfur provide evidence of high-quality oil and are aligned tothe API gravity of 42.0 deg.…”

Section: Conventional -The Lower Pennsylvanian Sandstone Playmentioning

confidence: 99%

Comparing Resource Plays in the Texas and New Mexico Permian Basin – Implications for Exploration Research

Adu-Gyamfi¹,

Golding²,

Pérez³

et al. 2021

SJEE

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The Permian Basin in Western Texas and North Eastern New Mexico is an energy powerhouse. With three sub-basins i.e., Delaware, Central Basin Platform and Midland Basin producing hydrocarbons from both conventional and unconventional plays, the Texan Permian has been a focus of more interest from energy companies than the North-Western Shelf of the basin in New Mexico. However, the less explored North Western shelf of the basin in New Mexico furnishes equal opportunity for oil and gas exploration companies for further exploration research and subsequent discoveries. This research is an attempt to showcase the exploration significance and highlight the gaps for in exploration research in the New Mexico Permian Basin. We compare the oil plays in both Texas and New Mexico Permian based on reservoir geology and basin architecture. Overall, The Permian Basin is dominated by carbonate reservoirs. They account for 75% of all oil production followed by clastics, which contribute 14%; then come the mixed clastics and carbonates accounting for 8%; and lastly cherts make up around 3%. The leading growing production zone is the San Andres platform (Northwest shelf) carbonate play (4.0 billion bbl) followed by the Leonard restricted platform carbonate play (3.3 billion bbl). The Lower Permian Horseshoe and Pennsylvanian plays are next (2.7 billion bbl) and lastly by the San Andres platform carbonate play contributes to the overall production (2.2 billion bbl). With known potential of shelf plays we determine that North Western Shelf has similar stratigraphy and extensive hydrocarbon potential yet to be researched and explored.

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Evaluation of Shale Source Rocks and Clay Mineral Diagenesis in the Permian Basin, USA: Inferences on Basin Thermal Maturity and Source Rock Potential

Cited by 14 publications

References 105 publications

Maturity of Potential Cretaceous Source Rocks at the Isis Field, Offshore Eastern Tunisia: Influence of Hydrothermal Fluids

Maturity of Potential Cretaceous Source Rocks at the Isis Field, Offshore Eastern Tunisia: Influence of Hydrothermal Fluids

3D VSP Imaging Using DAS Recording of P- and S-Waves in Vertical and Lateral Well Sections in West Texas

Comparing Resource Plays in the Texas and New Mexico Permian Basin – Implications for Exploration Research

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