000			04017nam a2200301 4500
005			20260520010400.0
008			260224s2018 xxu esp
041			_aEspañol
082			_a068.82 553.28 C62 2018 0015650
245	0	0	_aEvolución del conocimiento y comportamiento dinámico de aries, un campo maduro costa afuera en la Cuenca Austral
260			_a _b _c2018
270			_a28/06/2022 ; 18/03/2019
300			_a16 p. ; 167-183
520			_aAries is a gas and condensate field belonging to the CMA-1 concession (Cuenca Marina Austral 1) which is being operated by Total Austral (37.5%) in association with Wintershall Energy (37.5%) and Pan American Energy (25%). It is located 30km off-shore of the Tierra del Fuego province, where the water depth is around 80m. Aries has been developed with three wells from a central platform and connected by a pipeline shared with Carina platform to the Río Cullen process facilities. The production started in February 2006, reaching a maximum rate of 8Msm3/d (in 2009) and is currently producing ~2Msm3/d (2018).Aries field is composed by a 3-way dip structure limited by a NW-SE oriented mayor fault. The structural style developed sub-parallel fault network and two sub-structures connected by a gentle saddle in between. The main reservoir is composed by the transgressive sandstones (Hauterivian) of Argo sequence and the fluvial sandstones of the Hidra sequence (Valanginian), deposited over the paleo-topography of the Tobífera formation, which is considered the economical basement.The development of Aries field started between 2005/2006, with three wells drilled: a slant well, located in the saddle targeting the sandstones of both sequences, Argo and Hidra; and, two wells with horizontal drains of 400m each one along the upper part of the Argo reservoir sandstones; following the uppermost structural positions toward northwest one of the horizontal wells and southeast the other one. These two wells have been equipped with bottom hole pressure gauges, then it is possible to continuously monitor the pressure behavior of the reservoir. The slant well was used as an observer during the first couple of years of production; now-a-day it became a permanent producer. After the drilling campaign the petrophysical measurement resulted from the wells were in-line with the predictions based on the original geological model (static). However, the initial performance of the wells (based on dynamic tests) was higher than expected (dynamic model); since 2006, it is still the case (IGIP higher than prognosed), which is confirmed by the permanent production monitoring, WHP/BHP, P/Z-law, etc. The interpretation of all these information, together with the update of reservoir model, lead to review and increase the originally proposed gas accumulation (IGIP) and to change the vision of future geological models.The main objective of this paper is to show an example of developed field where, despite the good quality of the available 3D seismic, relative small structure calibrated by seven wells acquired during the exploration stage with an important set of petrophysical and dynamic data; the comprehension of the field behavior and its heterogeneities, is evolving with time according to its maturity, challenging the most optimistic pre-development case (Maxi).
773			_g
942			_cCONGTP
100	1		_aAchilli, Federico _951871
100	1		_aBurne, Lisandro _948505
100	1		_aLaiz, Gerardo _958632
100	1		_aÁvila, Daniel _958633
100	1		_aRodriguez-Lorente, Ezequiel _958634
100	1		_aTirella, Miguel _958635
111	2		_aCongreso de Exploración y Desarrollo de Hidrocarburos (10mo. : 2018 nov. 5 - 9 : Mendoza) _9573
111	2		_aSimposio de Desarrollo de Hidrocarburos (2018 nov. 5 - 9 : Mendoza) _9692
650		0	_aModelo estático _958636
999			_c192763 _d192763
856			_uhttps://biblioteca.iapg.org.ar/ArchivosAdjuntos/Conexplor2018/SDH/1543.pdf