Abstract We analysed here, for the first time, 278 small to medium earthquakes that have occurred since 1985 along a 200 km section of the Levant passive continental margins, offshore Israel. The earthquakes are spatially overlapping with numerous submarine landslides and thin-skinned salt-tectonic-related faults scarps, bisecting the continental slope. Thus, we focus on the genetic relationship between the earthquakes, the faults and the landslides. We found that a subgroup of 55 earthquakes is spatially overlapping with the marine extension of the Carmel Fault and thus might be of tectonic origin. A second subgroup, hosting approximately 130 earthquakes, is spatially overlapping with the longshore salt-tectonic-related submarine faults. However, due to the non-shallow focal depth of most of these earthquakes, salt tectonics was ruled out as their possible seismic origin. Thus, the seismic source for theanalysed earthquakes is yet to be revealed. We further found that the observed medium earthquakes (M > 4) have a calculated reoccurrence time of more than 10 years and they are capable of inducing submarine slope failure within the studied area. Hence, they might play a role in submarine mass-wasting processes along the studied continental slope, and must now be considered in future hazard analysis.

ABSTRACT The Tamar gas field, discovered in 2009 by Noble Energy, Delek, and partners, paved the way for a series of presalt discoveries that expanded our understanding of the petroleum systems in the east Mediterranean and the region’s hydrocarbon prospectivity. Approximately 40 tcf of natural gas has been discovered in the Oligocene–Miocene so-called Tamar sands play offshore Israel and Cyprus, which includes some of the largest deep-sea gas discoveries in the world over the last decade. The Tamar field development was expedited such that first gas occurred by March 2013, a mere 51 months following drilling of the wildcat well. Deep-water presalt exploration offshore Israel began in 2003 with the Hannah-1 dry hole. Following a 5-year hiatus, a new subsalt exploration and drilling program began in earnest in 2008, resulting in gas discoveries at Tamar, Dalit, Leviathan, Dolphin, Tanin, Aphrodite, Karish, and Tamar Southwest. The main presalt play area likely extends nearly 30,000 km 2 (11,583 mi 2 ) in water depths of approximately 1300 to 1700 m (4265 to 5577 ft), in the exclusive economic zones of Egypt, Israel, Cyprus, Lebanon, and Syria. The Tamar sands reservoir section is comprised of deep-sea floor fan sandstones punctuated by relatively thin beds of silts and mudstones. The accumulations are characterized by thick deposits, over 250 m (820 ft) of gross pay at Tamar, of high-quality reservoir with >20% porosity and >500 mD permeability. The lean gas (over 98% methane) is thought to be biogenic and sourced from the interbedded shaley units, whereas the seal is the regionally extensive early Miocene silty-shaley unit termed the Ng10 shale. Traps are faulted, four-way closures reaching over 100 km 2 (39 mi 2 ) at Tamar and approximately 330 km 2 (127 mi 2 ) at Leviathan, the largest discovery to date. Over 140 m (459 ft) of conventional core has been collected from one appraisal and two development wells at Tamar, and an extensive suite of side-wall cores were taken in the other wells. Core calibration has proven critical to petrophysical evaluation, resource assessment, and completion design. The Tamar field was developed in under 51 months from discovery to first gas for $3.25 billion in gross development capital. Current production at Tamar is accomplished from five subsea wells, each capable of producing over 250 MMSCF/day and tied back through a subsea manifold to a fixed-leg processing platform located some 150 km (93 mi) south of the field. At the time of development, this was the longest deep-sea tieback in the world. From there, the treated gas is flowed to an onshore terminal in the coastal city of Ashdod. Tamar is currently the only significant provider of natural gas to Israel and has supplied nearly 1.0 tcf of gas as of year end 2016, which fuels over 50% of the local market’s power generation needs. The discovery and development of Tamar opened a new chapter for the eastern Mediterranean oil and natural gas industry.

Abstract: Layer-bound normal faults commonly form polygonal faults with fine-grained sediments early in their burial history. When subject to anisotropic stress conditions, these faults will be preferentially oriented. In this study we investigate how faults grow, evolve and interact within regional-scale layer-bound fault systems characterized by parallel faults. The intention is to understand the geometry and growth of faults by applying qualitative and quantitative fault analysis techniques to a 3D seismic reflection dataset from the Levant Basin, an area containing a unique layer-bound normal fault array. This analysis indicates that the faults were affected by mechanical stratigraphy, causing preferential nucleation sites of fault segments, which were later linked. Our interpretation suggests that growth of layer-bound faults at a basin scale generally follows the isolated model, accumulating length proportional to displacement and, when subject to an anisotropic regional stress field, resembling to a great extent classical tectonic normal faults.

Abstract In recent years deep-water petroleum exploration has been booming. The Gulf of Mexico, some West African regions, and Brazil are leading this growing activity. Current deep-water plays focus on presalt, subsalt, stratigraphic pinch-out and deep-water folded belt targets. Comparisons of conjugated margins across the Atlantic are commonly used by explorationists to extend the prospectivity of known plays. However, what are deep-water plays? Are they only plays presently located in water depths more than 2000 m water depths or do they also include plays developed initially in relatively deep oceanic tectonic settings but are now underneath shallow water? For that matter, what about plays which developed in relatively shallow water but are now located in water depths greater than the continental slope. Present deep-water tectonic settings are mostly compressional toe-thrust regions of larger massive gravitational collapses related to (A) major deltas (B) allochthonous salt provinces, or (C) subduction-related accretionary wedges. Back-arc extensional basins in deep-water settings are underexplored, except for the Black Sea. Other plays presently in deep waters but from a geologic perspective initially formed in relatively shallow marine water and subsequently subsided are the pre-evaporitic plays of the Campos-Santos basins in Brazil and Angola offshore basins. Some elements of deep-water petroleum systems are still poorly understood. Although the presence of widespread deep-water source beds on oceanic crust is mostly known through DSDP/ODP wells, the role of tectonics and volcanic activity in the generation and maturation has yet to be adequately evaluated. Classical upwelling models intended to explain marine source beds may need to be refined. Note that most current deep-water-plays involve siliciclastics. There is no reason to preclude deep-water carbonate plays, the reservoirs of which are analogous to the outer platform, relatively deep-water pelagic carbonates producing in the Bay of Campeche in Mexico. Traditional seismic stratigraphy views unconformities as being caused by eustatic sea level changes. However, the origin of widespread deep-water unconformities needs to be further elucidated. An increasing number of deep crustal seismic surveys along West Africa show low-angle extensional detachments similar to those found on the Galicia margin of Spain and Portugal and comparable with tectonic styles of the Basin and Range Province of the western United States or else in the western Mediterranean ( e.g. , Western Alps or Betic Cordillera). Classical rifting models always need to be updated to be “on target” with new and often surprising seismic observations. In addition to the four principal types of deep-water plays currently being explored, additional plays should be found in deep-water carbonates, volcanic margins including hot spots or volcanic-lineaments, and subsided rifted systems; these may account for significant yet to be explored future plays in many parts of the “deep-water” world.

Abstract Recent drilling activity in the Levant Margin offshore Israel has resulted in the discovery of up to 25 TCF of gas. As exploration efforts continue, the previously under-explored Levant Margin is revealed as one of the most prolific petroleum provinces of the Mediterranean region. Study of regional seismic data show that this margin evolved in three main tectonic phases: Permian to Early Jurassic riffing, middle Jurassic to middle Cretaceous passive margin and late Cretaceous to Tertiary inversion and partial subsidence. Well results indicate the existence of both biogenic and thermogenic petroleum systems. Dry-gas found in Mari-B, Tamar, Leviathan, and several smaller fields suggests basin-wide charge of reservoirs containing bacterial gas, likely originated in Late Tertiary, organic-rich deep-marine shale. Two play types are associated with the biogenic gas system: (A) the Tamar play includes lower Miocene, deep-water turbidite sands in upper Miocene compressional structures; and (B) the Yafo play includes lower Pliocene turbidites in basin-floor fans and mobilized sand mounds. The existence of thermogenic petroleum systems in the Levant Margin is indicated by significant, highgrade oil shows found in several wells, although commercial production of these oils has not yet been established. Potential source rocks are organic-rich carbonates of mid-Triassic, mid-Jurassic, late Cretaceous, and early Tertiary age. Two types of plays are considered: (A) Jurassic, fractured shallow-marine carbonates in compressional structures located near the basin margin; and (B) Cretaceous, deep-water turbidite sands found in the deep, central part of the basin. Both play types are planned to be soon tested by drilling.