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With the easy conventional oil in Argentina having been produced, one remaining way to find new oil in existing fields is to convert fields from primary or secondary production to secondary or tertiary production, respectively.

A new proppant exhibits a neutrally wet surface, which does not have a preferential affinity for oil, gas, or water and therefore will not promote the preferential entrapment of any phase within the proppant pack.

Hydraulic fracturing exerts transient geomechanical forces near the wellbore, enabling a brief time interval in which a second hydraulic fracture can be created in a different direction.

The oil-economy downturn will not affect the areas where research, development, and application of novel technologies are absolutely necessary for the commercialization of hydrocarbon.

While many factors may influence fracture-height evolution in multilayer formations, the consensus is that the so-called “equilibrium height belonging to a certain treating pressure” provides an upper limit, at least for nonnaturally fractured media.

An area of great interest to those researching flowback is the interaction of water and salt inside the shale reservoir. After a well is stimulated, the flowback fluids tend to show a rising concentration of salt that falls back to near zero over time.

On the far end of the flowback spectrum is a completion process called soakback. If the well has to be shut in until takeaway capacity is available, the completion fluids soak into the shale rock. Flowback analysis can help understand what happens in the formation.

A new unconventional proppant technology—a rod-shaped proppant—delivered 25% higher oil per net pay compared with offset wells using conventional proppant.

Most shale producers in North America have given little thought to the flowback stage following hydraulic fracturing. Others have come to realize it represents a valuable opportunity to learn more about their wells.

For thin-oil-rim reservoirs, well placement, well type, well path, and the completion methods must be evaluated with close integration of key reservoir and production-engineering considerations.