flowback analysis

Whether it’s reviving inactive gas-condensate wells or identifying overlooked reserves in brownfields, operators are making the most of older wells and fields.

Every horizontal well must pass through the flowback phase before it becomes a true producer. A wealth of insights are generated during this period, but they only matter if an operator knows how to listen and interpret the data sets correctly.

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.

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.

Rising demand for flowback technologies to reduce uncertainties is leading to the creation of more hydrocarbon and water tracers. These chemical-based tracers may play an important role in the shale industry’s effort to come up with more cost-effective fracture designs.

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.