Это не скважины после ГРП, а естественная трещиноватость коллектора - карбонаты. По этой скважине видно влияние на соседние как минимум 2000 ft.

А если использовать для расчета формулы в аттаче?

Да, вся инфа по скважинке конечно же есть.

Вот что по этому поводу есть на SPE:

Fluid volume calculations using test data

A new proposed method to calculate the volume of fluid “seen” by a well test.  The longer the test goes the higher the radius of investigation.  Heterogeneities within the radius of investigation are “seen”, heterogeneities beyond are not.  Uses only pressure transient data and information on total compressibility but doesn’t need porosity, rate or reservoir pressure decline.  Method is an extension of the TNP (derivative normalization) method, was tested successfully using synthetic data, is not based on rigorous mathematics, and if deemed useful more research is needed to formulate the method more rigorously.  The derivative is normalized in coordinates of kh/u.  The normalized derivative value at any time can be used as a proxy for mobility thickness.  The TNP shows how the radius of investigation increases with test duration (for a given storage coefficient).  The shape of the derivative holds information about the flow geometry.  Fluid volume calculation:  cylindrical flow is a strong assumption, Vfluid=πr2hφ=πA²*kh/μ *1/Ct*t (note this is independent of porosity!).  Model incorporates a slope correction to account for more volume during spherical flow vs. less volume during linear flow or least volume for closed system.  When using the technique a geometry factor needs to be used, i.e., does model assume radial flow or boundary-controlled flow.  There is a 21% difference between a model assuming a circle vs. a square drainage area (4 – π)/4 = 21%.  So now incorporating corrections for slope and geometry factor.  Example of more complex example from a DFN model with a horizontal well and three fracture sets.  Computed connected fractures intersecting well.  Ran simulated well test for long duration to make certain the entire volume was seen in the well test.  Calculated volume from well test within 1% of actual volume calculated from model; method seems to work.  Applications:  dual porosity, flow from matrix?  Compare fluid volume in fractures to total fluid volume in total system with the difference coming from the matrix.  Applications:  volume of a hydrofrac?  Compare fluid volume pre-frac to fluid volume post-frac with difference being frac volume.  The method uses only test transient data and compressibility information.