Fabio Trippetta

Experimental investigation of the mechanical properties of synthetic magnesium sulfate hydrates: Implications for the strength of hydrated deposits on Mars

[1] We have carried out uniaxial compression experiments to determine the mechanical properties of three crystalline magnesium sulfate hydrates that may be present in the near‐surface environment of Mars. Our synthetic samples of kieserite (MgSO4 ·H 2O), epsomite (MgSO4 ·7 H2O), and meridianiite (MgSO4 · 11H2O) have mean values of unconfined compressive strength of 6.3 ± 0.7, 12.9 ± 1.8, and 30.1 ± 4.5 MPa, respectively, Young’s modulus of 0.8 ± 0.1, 2.9 ± 0.4, and 5.9 ± 0.8 GPa, respectively, and mean porosity values of 47.8% ± 0.5%, 11.1% ± 0.6%, and 2.9% ± 0.2%, respectively. Although our tests cannot quantify a systematic relationship between hydration state and mechanical properties, the different porosities produced by consistent sample preparation methods suggest that the addition of non‐cation‐coordinated water molecules likely reduces the strength of individual sulfate hydrate phases. However, the bulk mechanical properties of our synthetic specimens are instead controlled predominantly by the sample porosity; generally, the strength increases as the porosity decreases. We expect the mechanical properties of sulfate hydrate deposits on Mars to be governed by the bulk porosity rather than the strength of the pure solid phase. We have performed cyclic stressing tests, replicating possible periodic depositional and erosional periods on Mars resulting from obliquity changes. A gradual compaction and reduction in sample porosity, rather than an increase in crack damage, is observed with each loading cycle, suggesting that the evolution of mechanical properties will depend on local factors such as bulk density, in addition to the overall stress history.

Mesozoic Syn- and Postrifting Evolution of the Central Apennines, Italy: The Role of Triassic Evaporites

Jurassic–Cretaceous syn- and postrift successions from the central Apennines were backstripped to gain information on the Mesozoic evolution of the passive margin of the Adriatic Plate. Early Jurassic rifting led to the development of a horst-and-graben paleogeography (the Latium-Abruzzi Carbonate Platform and the Sabina-Umbria-Marche Pelagic Basin). Subsidence curves were built for both carbonate platform and pelagic-basin domains from original and literature stratigraphic data. The paleodepositional depths of the deepwater sediments were reconstructed from field geology data, including new paleontological data. It is proposed that after the deposition of lower Hettangian shallow-water carbonates, an abrupt increase in paleowater depth, to 600–1000 m, occurred during the late Hettangian–Sinemurian synrift stage. The postrift stage was characterized by basin filling, with decreasing paleowater depths during the Jurassic, and by a new deepening during the Cretaceous. Our backstripping curves show, for the Sabina-Umbria-Marche Basin, a short period (<5 m.yr.) of rapid tectonic subsidence at the beginning of the Jurassic, followed by very slow (likely thermally controlled) or absent tectonic subsidence until the Cretaceous. The slight increase in subsidence observed from Cenomanian time is linked to a renewal of extensional tectonics. The Latium-Abruzzi Carbonate Platform shows variable subsidence rates in both place and time. Fast subsidence occurred in the Rhaetian–Hettangian, Toarcian, Berriasian, and Cenomanian and is linked with extensional or transtensional tectonic events. After the Early Jurassic rifting, subsidence rates (on average 30–40 m/m.yr.) affecting the Latium-Abruzzi Carbonate Platform were faster than those recorded by the Sabina-Umbria-Marche Basin. Faster postrift subsidence in carbonate platform areas is a geological paradox that is here explained by the lateral flow of upper Triassic evaporites toward the deepwater domains, as a result of higher sedimentary loading in the carbonate platform areas and the onset of a pressure gradient toward the pelagic basin at the depth of the evaporites.

Tectonic control on the petrophysical properties of foredeep sandstone in the Central Apennines, Italy

Petrophysical properties of rocks and their applicability at larger scale are a challenging topic in Earth sciences. Petrophysical properties of rocks are severely affected by boundary conditions, rock fabric/microstructure, and tectonics that require a multiscale approach to be properly defined. Here we (1) report laboratory measurements of density, porosity, permeability, and P wave velocities at increasing confining pressure conducted on Miocene foredeep sandstones (Frosinone Formation); (2) compare the laboratory results with larger-scale geophysical investigations; and (3) discuss the effect of thrusting on the properties of sandstones. At ambient pressure, laboratory porosity varied from 2.2% to 13.8% and P wave velocities (Vp) from 1.5 km/s to 2.7 km/s. The P wave velocity increased with confining pressure, reaching between 3.3 km/s and 4.7 km/s at 100 MPa. In situ Vp profiles, measured using sonic logs, matched the ultrasonic laboratory measurement well. The permeability varied between 1.4 × 10−15 m2 and 3.9 × 10−15 m2 and was positively correlated with porosity. The porosity and permeability of samples taken at various distances to the Olevano–Antrodoco fault plane progressively decreased with distance while P wave velocity increased. At about 1 km from the fault plane, the relative variations reached 43%, 65%, and 20% for porosity, permeability, and P wave velocity, respectively. This suggests that tectonic loading changed the petrophysical properties inherited from sedimentation and diagenesis. Using field constraints and assuming overburden-related inelastic compaction in the proximity of the fault plane, we conclude that the fault reached the mechanical condition for rupture in compression at differential stress of 64.8 MPa at a depth of 1500 m.

Assessment of earthquake locations in 3-D deterministic velocity models: A case study from the Altotiberina Near Fault Observatory (Italy)

The accuracy of earthquake locations and their correspondence with subsurface geology depends strongly on the accuracy of the available seismic velocity model. Most modern methods to construct a velocity model for earthquake location are based on the inversion of passive source seismological data. Another approach is the integration of high-resolution geological and geophysical data to construct deterministic velocity models in which earthquake locations can be directly correlated to the geological structures. Such models have to be kinematically consistent with independent seismological data in order to provide precise hypocenter solutions. We present the Altotiberina (AT) seismic model, a three-dimensional velocity model for the Upper Tiber Valley region (Northern Apennines, Italy), constructed by combining 300 km of seismic reflection profiles, 6 deep boreholes (down to 5 km depth), detailed data from geological surveys and direct measurements of P- and S-wave velocities performed in situ and in laboratory. We assess the robustness of the AT seismic model by locating 11,713 earthquakes with a non-linear, global-search inversion method and comparing the probabilistic hypocenter solutions to those calculated in three previously published velocity models, constructed by inverting passive seismological data only. Our results demonstrate that the AT seismic model is able to provide higher-quality hypocenter locations than the previous velocity models. Earthquake locations are consistent with the subsurface geological structures and show a high degree of spatial correlation with specific lithostratigraphic units, suggesting a lithological control on the seismic activity evolution.

Oil distribution in outcropping carbonate-ramp reservoirs (Maiella Mountain, Central Italy): Three-dimensional models constrained by dense historical well data and laboratory measurements

Heavy oil and bitumens have been exploited in Italy during the past, in particular over the Maiella Mountain’s northwest flank (Central Italy), where relatively undeformed, hydrocarbon-bearing carbonate-ramp reservoirs of the Bolognano Formation crop out. These reservoirs represent the exhumed analog of a wider petroleum system that has been investigated also in the subsurface by exploration activities, both onshore and offshore (Central Adriatic). Here we present, for the first time, a historical data set composed of 180 shallow wells drilled over the area in 1942 by a company named Azienda Lavorazione Bitumi Asfalti; we digitally reconstructed this data set, integrating it with field observations, laboratory measurements, and thin-section analysis. Using Petrel (mark of Schlumberger) three-dimensional software, we modeled the reservoir and the hydrocarbon distribution, also calculating volumes of hydrocarbons in place. In our work, we demonstrate the presence of these quite homogeneous, porous carbonate reservoirs over the whole region, and we identify internal reservoir geometries characterized by clinoforms, likely resulting from a large-scale depositional cross-bedding and progradation. We also infer a different function of faults in the hydrocarbon accumulations: major faults were able to create independent compartments during migration, whereas minor, more recent elements did not control hydrocarbon accumulation, likely postdating a main lower-Pliocene migration phase. We believe that the observations derived from our work can represent a good analog for carbonate-ramp reservoirs elsewhere, may help in identifying appropriate modeling solutions, and can be used as calibration for future renewed exploration efforts in the region, both onshore and offshore.