scholarly journals Hydraulic Fracture Injection Strategy Influences the Probability of Earthquakes in the Eagle Ford Shale Play of South Texas

2019 ◽  
Vol 46 (22) ◽  
pp. 12958-12967 ◽  
Author(s):  
Shannon L. Fasola ◽  
Michael R. Brudzinski ◽  
Robert J. Skoumal ◽  
Teresa Langenkamp ◽  
Brian S. Currie ◽  
...  
Keyword(s):  
Hydraulic Fracture ◽  
South Texas ◽  
Eagle Ford Shale ◽  
Eagle Ford ◽  
Injection Strategy

Regional assessment of the Eagle Ford Group of South Texas, USA: Insights from lithology, pore volume, water saturation, organic richness, and productivity correlations

2016 ◽  
Vol 4 (1) ◽  
pp. SC125-SC150 ◽  
Author(s):  
Ursula Hammes ◽  
Ray Eastwood ◽  
Guin McDaid ◽  
Emilian Vankov ◽  
S. Amin Gherabati ◽  
...  
Keyword(s):  
Organic Matter ◽  
Pore Volume ◽  
Water Saturation ◽  
Production Quality ◽  
South Texas ◽  
Eagle Ford Shale ◽  
Eagle Ford ◽  
The North ◽  
The Impact ◽  
Sweet Spots

A comprehensive regional investigation of the Eagle Ford Shale linking productivity to porosity-thickness (PHIH), lithology ([Formula: see text]), pore volume (PHIT), organic matter (TOC), and water-saturation ([Formula: see text]) variations has not been presented to date. Therefore, isopach maps across the Eagle Ford Shale play west of the San Marcos Arch were constructed using thickness and log-calculated attributes such as TOC, [Formula: see text], [Formula: see text], and porosity to identify sweet spots and spatial distribution of these geologic characteristics that influence productivity in shale plays. The Upper Cretaceous Eagle Ford Shale in South Texas is an organic-rich, calcareous mudrock deposited during a second-order transgression of global sea level on a carbonate-dominated shelf updip from the older Sligo and Edwards (Stuart City) reef margins. Lithology and organic-matter deposition were controlled by fluvial input from the Woodbine delta in the northeast, upwelling along the Cretaceous shelf edge, and volcanic and clastic input from distant Laramide events to the north and west. Local oxygen minimum events along the South Texas margin contributed to the preservation of this organic-rich source rock related to the Cenomanian/Turonian global organic anoxic event (OAE2). Paleogeographic and deep-seated tectonic elements controlled the variations of lithology, amount and distribution of organic matter, and facies that have a profound impact on production quality. Petrophysical modeling was conducted to calculate total organic carbon, water saturation, lithology, and porosity of the Eagle Ford Group. Thickness maps, as well as PHIH maps, show multiple sweet spots across the study area. Components of the database were used as variables in kriging, and multivariate statistical analyses evaluated the impact of these variables on productivity. For example, TOC and clay volume ([Formula: see text]) show an inverse relationship that is related to production. Mapping petrophysical parameters across a play serves as a tool to predict geologic drivers of productivity across the Eagle Ford taking the geologic heterogeneity into account.

COMPARTMENTALIZATION OF THE EAGLE FORD SHALE, SOUTH TEXAS – A NOBLE GAS INVESTIGATION

2018 ◽  
Author(s):  
Guolei Han ◽  
◽  
M. Clara Castro ◽  
Toti Larson ◽  
Jean-Philippe Nicot ◽  
...  
Keyword(s):  
Noble Gas ◽  
South Texas ◽  
Eagle Ford Shale ◽  
Eagle Ford

Refracturing on Horizontal Wells in the Eagle Ford Shale in South Texas - One Operator’s Perspective

2015 ◽  
Author(s):  
Mamadou Diakhate ◽  
Ayman Gazawi ◽  
Robert David Barree ◽  
Manuel Cossio ◽  
Beau Tinnin ◽  
...  
Keyword(s):  
Horizontal Wells ◽  
South Texas ◽  
Eagle Ford Shale ◽  
Eagle Ford
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