000			02672nab a2200241 4500
005			20260520000320.0
008			260224s2016 xxu ing
041			_aInglés
245	0	0	_aImpacts of hydrothermal dolomitization and thermochemical sulfate reduction on secondary porosity creation in deeply buried carbonates _bA case study from the Lower Saxony Basin, northwest Germany
260			_a _b _cabr. 2016
270			_a06/06/2016 ; 06/06/2016
300			_a24 p. ; 597-621
520			_aTranscripción del resumen del autor: The role of deep-burial dissolution in the creation of porosity in carbonates has been discussed controversially in the recent past. We present a case study from the Upper Permian Zechstein 2 carbonate reservoirs of the Lower Saxony Basin in northwest Germany. These reservoirs are locally characterized by high amounts of carbon dioxide (CO2) and variable amounts of hydrogen sulfide (H2S), which are derived from thermochemical sulfate reduction (TSR) and inorganic sources. To study the contribution of these effects on porosity development, we combine petrography, stable isotope, and rare earth and yttrium (REY) analyses of fracture cements with Raman spectroscopy and d13C analyses of fluid inclusions. It is shown that fluid migration along deep fault zones created and redistributed porosity. Fluid inclusion analyses of vein cements demonstrate that hydrothermal fluids transported inorganic CO2 into the reservoir, where it mixed with minor amounts of TSR-derived organic CO2. The likely source of inorganic CO2 is the thermal decomposition of deeply buried Devonian carbonates. The REY distribution patterns support a hydrothermal origin of ascending iron- and CO2-rich fluids causing dolomitization of calcite and increasing porosity by 10%–16% along fractures. This porosity increase results from hydrothermal dolomitization and dissolution by acids generated from the reaction of Fe2+ with H2S to precipitate pyrite. In contrast, hydrothermal dolomite cements reduced early diagenetic porosity in dolomitic intervals by approximately 17%. However, the carbonate dissolution in the predominantly calcitic host rock results in a net increase in porosity and permeability in the vicinity of the fracture walls, which has to be considered for modeling reservoir properties and fluid migration pathways.
581			_a4
773	0		_tAAPG Bulletin _g100
942			_cARTICULO
100	1		_aBiehl, Bianca C. _955380
100	1		_aReuning, Lars _955381
100	1		_aSchoenherr, Johannes _955382
100	1		_aLüders, Volker _955383
100	1		_aKukla, Peter A. _952316
999			_c189575 _d189575