Abstract: Fluid is injected into a wellbore at a first rate which is low enough to maintain formation pressure beneath formation parting pressure. Thereafter, the rate of fluid injection is increased to a second rate which is high enough to exceed formation parting pressure. The time and pressure data obtained during the first and second periods are normalized, plots thereof are superposed and the formation parting pressure is determined by noting the point at which the plots deviate from one another.

Abstract: A method of flow testing a producing formation through a well including lowering into the well a recording pressure and temperature device to measure pressure and temperature as functions of time, then lowering into the well a test chamber closed at the bottom by a surface activated valve. The space between the chamber and the top of the formation is sealed and immediately thereafter the pressure and temperature of the well is measured. The valve on the test chamber is opened to allow formation fluids to enter therein and the pressure and temperature is measured as a function of time for a substantial period of time during which the pressure in the chamber increases, whereby the flow capacity and skin factor of the formation can be calculated.