TY  - DATA
AU  - González González,Ángel
AU  - Valderrama,José Manuel
AU  - Gschaider,Carlos Tomás
AU  - Adaros Cárcamo,Rodrigo
AU  - Verdugo Dobronic,Martín
AU  - Canessa Di Santo,Néstor Diego
AU  - Pérez Pérez,Álvaro
AU  - Velásquez Arauna,Aníbal
AU  - Sánchez Ojeda,Jesús
AU  - Ahumada Villar,Mauricio
AU  - González Vidal,Miguel
ED  - Congreso de Exploración y Desarrollo de Hidrocarburos (10mo. : 2018 nov. 5 - 9 : Mendoza)
ED  - Simposio de Recursos No Convencionales (2018 nov. 5 - 9 : Mendoza)
TI  - Desarrollo del play tight gas zona glauconítica, bloque Arenal, Cuenca de Magallanes - Chile : Caso de estudio
U1  - 068.82 553.28 C62 2018 0015655 
PY  - 2018///
CY  - 
PB  - 
KW  - Tight gas
KW  - Fractura hidráulica
N2  - The zona glauconítica in the Arenal Block of Tierra del Fuego Island, in southern Chile, has been under exploitation since 2011 and currently contributes with more than 60% of ENAP ś gas production in the Magallanes basin. The reservoir encompasses 40 km2 of area of fine-grained marine rocks with an average gross thickness of 50 meters.This paper presents the current state of development in this unconventional tight gas reservoir, mainly composed by interbedded wackes and siltstones. The petrophysical characterization was based on electrical well logs and well cores analysis such as: X-ray diffraction, infrared spectroscopy, and porosity and permeability measurements. It was determined that the best petrofacies corresponds to wackes with secondary porosity, due to grains dissolution. With an average low permeability (<0.1mD), the use of hydraulic fracturing for reservoir ś stimulation is mandatory, in order to ensure commercial production. Fracture design is managed within a threshold of operational net pressure in order to contain the fracture within the reservoir thickness. Currently, 150 massive hydraulic stimulation treatments have been carried out (one stage per well) mainly, using treated water or hybrid (treated water and linear gel) as fracture fluid .Based in 3D seismic, we interpret a subtle, west-southwest dipping monocline without prominent structural faulting and closures. However, a polygonal fault system (PFS) is interpreted from a combination of seismic horizon and volume attributes. PFS location have been accounted for development drilling (PAD) design as they might cause partial reservoir compartmentalization and possible control in the orientation of the induced hydraulic fractures.Currently, there are more than 100 wells producing wet gas with a 50-60 °API condensate. Initial flow rates ranges from 20 Mm3/d to 100 Mm3/d and the most productive zone it is located to the northwest part of the reservoir area
UR  - https://biblioteca.iapg.org.ar/ArchivosAdjuntos/Conexplor2018/SRNC/1477.pdf
ER  -