Type curve analysis following a pre-frac nitrogen fracture-injection/falloff test.
Every shale play is different. And Reservoir Development Consulting has analyzed 100s of pressure diagnostic tests in shale reservoirs across North America beginning in the Barnett and recently working in the Marcellus.
State-of-the-art diagnostic analysis can characterize the potential to hydraulically fracture a particular shale; characterize the presence of natural fractures or fissures by the effects of wellbore and fracture storage; and characterize the potential for fracture network development.
Pressure diagnostics can help otimize fracture treatment design, and when combined with microseismic mapping, pressure diagnostics can improve an operator's understanding of shale-reservoir productivity.
Several diagnostics are available for studying shale reservoirs. A fracture-injection/falloff test pumped with either treated water or nitrogen is a common pre-frac diagnostic. Post-frac injection falloff tests are also useful for identifying fracture damage, but perhaps the best post-frac test to define the created fracture network and characterize the reservoir is a pressure buildup test after dewatering the fracture network.
New pressure transient solutions allow multiple arbitrarily-oriented fractures to be identified in vertical and horizontal wells. In horizontal wells, for example, pressure transient methods are the only means of determining the number of fractures and the length of the lateral contributing to production.
Reservoir Development continues to develop and refine diagnostic technologies in shale reservoirs, and Reservoir Development can develop a testing program to help operators realize optimal shale-reservoir potential.
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