A Comprehensive Approach to Sweet-Spot Mapping for Hydraulic Fracturing and CO2 Huff-n-Puff Injection in Chattanooga Shale Formation

2015 ◽  
Author(s):  
M. Vinassa ◽  
S. E. Cudjoe ◽  
Joao Henrique Bessa Gomes ◽  
R. Barati Ghahfarokhi
Keyword(s):  
Hydraulic Fracturing ◽  
Comprehensive Approach ◽  
Sweet Spot ◽  
Chattanooga Shale ◽  
Shale Formation ◽  
Spot Mapping

scholarly journals Erratum to “A Perspective on Stratigraphic, Vertically-Upward “Displacements or Dislocations” of Conodont-Elements: An Example From the Upper Devonian, Pre-Lithified, Black Shales of the Chattanooga Shale Formation In Tennessee, USA” ...

2019 ◽  
Vol 9 (1) ◽  
pp. 14
Author(s):  
Michael Iannicelli
Keyword(s):  
Black Shale ◽  
Environmental Chemistry ◽  
Black Shales ◽  
Photic Zone ◽  
Marine Organic Matter ◽  
Chattanooga Shale ◽  
Shale Formation ◽  
Organic Matter Biomarkers ◽  
Reference Section ◽  
Made In

Even though the author already incorporated the citation of Sinninghe-Damste & Schouten (2006) into the text of the paper, the author regrets having failed to include their full citation within the Reference Section of my above paper which is: Sinninghe-Damste, J. S. & Schouton, S. (2006). Biological markers for anoxia in the photic zone of the water column. In, Volkman, J. K. (ed.), Marine Organic Matter: Biomarkers, Isotopes and DNA, (pp. 127 – 163). The Handbook of Environmental Chemistry, vol. 2N. Springer: Berlin and Heidelberg. https://doi.org/10.1007/698_2_005 The author also needs to paraphrase a statement made in the last three lines of the 2nd paragraph on page 40 where it reads as: “Thus, we may conclude here that paleo-upfreezing of any conodont-element(s) originally buried in the pre-lithified, light-colored shale occurred in order to account for their presence in black shale”. Instead, in lieu of that statement, it should read as “At this point in time of the study, we may tentatively conclude here while completely concluding later in the study, that conodont-elements originally existing in the underlying, pre-lithified, light-colored shale, had to paleo-upfreeze vertically upward into pre-lithified, black shale sediment in order to account for their presence in lithified black shale”.

scholarly journals Study on Fracture Morphological Characteristics of Refracturing for Longmaxi Shale Formation

Geofluids ◽  
2020 ◽  
Vol 2020 ◽  
pp. 1-13 ◽  
Author(s):  
Yintong Guo ◽  
Lei Wang ◽  
Xin Chang ◽  
Jun Zhou ◽  
Xiaoyu Zhang
Keyword(s):  
Hydraulic Fracturing ◽  
Morphological Characteristics ◽  
Test Method ◽  
Pressure Curve ◽  
Natural Fractures ◽  
True Triaxial ◽  
Bedding Planes ◽  
Initiation And Propagation ◽  
Longmaxi Shale ◽  
Shale Formation

Refracturing technology has become an important means for the regeneration of old wells reconstruction. It is of great significance to understand the formation mechanism of hydraulic fracturing fracture for the design of hydraulic fracturing. In order to accurately evaluate and improve fracturing volume after refracturing, it is necessary to understand the mechanism of refracturing fracture in shale formation. In this paper, a true triaxial refracturing test method was established. A series of large-scale true triaxial fracturing experiments were carried out to characterize the refracturing fracture initiation and propagation. The results show that for shale reservoirs with weak bedding planes and natural fractures, hydraulic fracturing can not only form the main fracturing fracture, which is perpendicular to horizontal minimum principal stress, but it can also open weak bedding plane or natural fractures. The characteristics of fracturing pump curve indicated that the evolution of fracturing fractures, including initiation and propagation and communication of multiple fractures. The violent fluctuation of fracturing pump pressure curve indicates that the sample has undergone multiple fracturing fractures. The result of refracturing shows that initial fracturing fracture channels can be effectively closed by temporary plugging. The refracturing breakdown pressure is generally slightly higher than that of initial fracturing. After temporary plugging, under the influence of stress induced by the initial fracturing fracture, the propagation path of the refracturing fracture is deviated. When the new fracturing fracture communicates with the initial fracturing fracture, the original fracturing fracture can continue to expand and extend, increasing the range of the fracturing modifications. The refracturing test results was shown that for shale reservoir with simple initial fracturing fractures, the complexity fracturing fracture can be increased by refracturing after temporary plugging initial fractures. The effect of refracturing is not obvious for the reservoir with complex initial fracturing fractures. This research results can provide a reliable basis for optimizing refracturing design in shale gas reservoir.

scholarly journals Regulation Requires Records: Access to Fracking Information in the Marcellus/Utica Shale Formations

2018 ◽  
Vol 2 ◽  
pp. 3 ◽  
Author(s):  
Eira Tansey
Keyword(s):  
Hydraulic Fracturing ◽  
Water Supply ◽  
Environmental Regulation ◽  
Economic Activity ◽  
Fossil Fuel ◽  
Shale Formations ◽  
Utica Shale ◽  
The World ◽  
Shale Formation ◽  
Records Access

In the world of environmental regulation, records are the foundation on which all further regulatory action takes place. From permits that give industry permission to pollute in the name of economic activity, to annual production reports documenting how much fossil fuel is taken out of the ground, notices of violation issued by regulators, to complaints filed by citizens noticing contaminants in their water supply, recordkeeping is fundamental to regulation. Even as records are critical to understanding and contextualizing environmental problems, accessing and interpreting this information is an exceptionally difficult experience. This article will consider the regulatory recordkeeping context of hydraulic fracturing (fracking) in Ohio, Pennsylvania, and West Virginia, the three most productive states in the Marcellus/Utica shale formation.

scholarly journals Numerical Study on the Effects of Imbibition on Gas Production and Shut-In Time Optimization in Woodford Shale Formation

Energies ◽  
2020 ◽  
Vol 13 (12) ◽  
pp. 3222 ◽  
Author(s):  
Zhou Zhou ◽  
Shiming Wei ◽  
Rong Lu ◽  
Xiaopeng Li
Keyword(s):  
Numerical Model ◽  
Hydraulic Fracturing ◽  
Field Data ◽  
Gas Production ◽  
Model Parameters ◽  
Water Recovery ◽  
Woodford Shale ◽  
Capillary Suction ◽  
Shale Formation ◽  
The Relationship

In shale gas formations, imbibition is significant since the tight pore structure causes a strong capillary suction pressure. After hydraulic fracturing, imbibition during the period of shut-in affects the water recovery of flowback. Although there have been many studies investigating imbibition in shale formations, few papers have studied the relationship between gas production and shut-in time under the influence of imbibition. This paper developed a numerical model to investigate the effect of imbibition on gas production to optimize the shut-in time after hydraulic fracturing. This numerical model is a 2-D two-phase (gas and water) imbibition model for simulating an imbibed fluid flow and its effect on permeability, flowback, and water recovery. The experimental and field data from the Woodford shale formation were matched by the model to properly configure and calibrate the model parameters. The experimental data consisted of the relationship between the imbibed fluid volume and permeability change, the relative permeability, and the capillary pressure for the Woodford shale samples. The Woodford field data included the gas production and flowback volume. The modeling results indicate that imbibition can be a beneficial factor for gas production, since it can increase rock permeability. However, the gas production would be reduced when excessive fluid is imbibed by the shale matrix. Therefore, the shut-in time after hydraulic fracturing, when the imbibition happens in shale, could be optimized to maximize the gas production.

Sweet spot identification through seismic inversion and multiattribute transform: A case study of the Niobrara and Codell unconventionals

2019 ◽  
Vol 7 (4) ◽  
pp. T887-T898
Author(s):  
Sheila Harryandi ◽  
Ali Tura
Keyword(s):  
Hydraulic Fracturing ◽  
Development Strategy ◽  
Seismic Inversion ◽  
Sweet Spot ◽  
Hydrocarbon Production ◽  
Facies Model ◽  
Facies Classification ◽  
Tight Reservoir ◽  
Well Data ◽  
Prestack Seismic Inversion

The Niobrara and Codell unconventional tight reservoir play at the Wattenberg field, Colorado, has potentially two billion barrels of oil equivalent, requiring hundreds of wells to access this resource. Due to the formations’ high heterogeneity and variable thicknesses, we model the facies at the well-bore scale and upscale it to the seismic scale to guide the development strategy and evaluate future exploration targets. A facies classification from well data supervises the prestack seismic inversion and multiattribute transformation workflows to build a 3D facies model. The 3D facies model captures the reservoir heterogeneity throughout the study area and suggests the location of sweet spots for future hydraulic fracturing and refracturing. The term “sweet spot” refers to the parts of the rock formation that potentially have the highest hydrocarbon production. The significance of sweet spot identification includes improved recovery from the Niobrara, Codell, and potential deeper intervals for future exploration of drilling targets. Furthermore, sweet spot information also assists in keeping the well in formation, which is difficult to do without the seismic data. Keeping the well in formation is key for the efficiency of hydraulic fracturing operations and improved production.

Impact of the stress state and the natural network of fractures/faults on the efficiency of hydraulic fracturing operations in the Goldwyer Shale Formation

2020 ◽  
Vol 60 (1) ◽  
pp. 163
Author(s):  
Partha Pratim Mandal ◽  
Reza Rezaee ◽  
Joel Sarout
Keyword(s):  
Stress State ◽  
Hydraulic Fracturing ◽  
Pore Pressure ◽  
Cost Effective ◽  
Fracture Network ◽  
Fault Reactivation ◽  
Hydraulic Fractures ◽  
Natural Fractures ◽  
Future Production ◽  
Shale Formation

Cost-effective hydrocarbon production from low-permeability unconventional reservoirs requires multi-stage hydraulic fracturing (HF) operations. Each HF stage aims to generate the most spatially extended fracture network, giving access to the largest volume of reservoir possible (stimulated volume) and allowing hydrocarbons to flow towards the wellbore. The size of the stimulated volume, and therefore, the efficiency of any given HF stage, is governed by the rock’s deformational behaviour and presence of pre-existing natural fractures/faults. Naturally elevated pore pressures at depth not only help to reduce the injection energy required to generate hydraulic fractures but can also induce slip along pre-existing fractures/faults, and therefore, enhance production rates. Here we analyse borehole image, density, resistivity and sonic logs available from a vertical exploration well in the Goldwyer Shale Formation (Canning Basin) to (i) characterise the pre-existing network of natural fractures; and (ii) estimate the in-situ pore pressure and stress state at depth. The aim of such an analysis is to evaluate the possibility of fracture/fault reactivation (slip) during and following HF operations. Based on this analysis, we found that an increase in the formation's pore pressure by only a few MPa (typically ~5–10 MPa) could lead to slip along pre-existing fractures/faults, provided they are favourably oriented with respect to the prevalent stress field for future production. We also found that slip along the horizontal or sub-horizontal bedding of the Goldwyer Formation is unlikely in view of the prevalent strike-slip faulting regime, unless an extremely large overpressure exists within the reservoir.

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