Download Pressure Transient Formation and Well Testing by Fikri Kuchuk, Florian Hollaender and Mustafa Onur (Eds.) PDF

By Fikri Kuchuk, Florian Hollaender and Mustafa Onur (Eds.)

This reference provides a finished description of stream via porous media and ideas to strain diffusion difficulties in homogenous, layered, and heterogeneous reservoirs. It covers the basics of interpretation thoughts for formation tester strain gradients, and pretests, multiprobe and packer strain temporary assessments, together with spinoff, convolution, and pressure-rate and pressure-pressure deconvolution. Emphasis is positioned on the greatest chance technique that permits one to estimate blunders variances in strain information in addition to the unknown formation parameters.Serves as a coaching guide for geologists, petrophysicists, and reservoir engineers on formation and strain brief testingOffers interpretation recommendations for instant software within the fieldProvides unique assurance of pretests, multiprobe and packer strain temporary checks, together with by-product, convolution, and pressure-rate and pressure-pressure deconvolution

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Extra resources for Pressure Transient Formation and Well Testing

Example text

Stability, and resolution if the temperature variations were negligible during the test. 01 psi, with high stability and without hysteresis. 025% in reading pressures greater than 1000 psi (Miller, Seeds, & Shira, 1972). However, the early time pressure data for both formation and well testing were inaccurate, particularly for buildup tests during which temperature may change more than a few degrees Celsius, although it was a perfect gauge for interference tests, where the downhole temperature remains constant during the test.

Finally, both pressure change and derivative show a linear flow regime (m = 1/2) towards the end of the test. Practically, this 160-hr buildup test does not provide information about the well productivity and formation, or the reservoir pressure. 52) is a simple material balance for a slightly compressible fluid in the wellbore. As discussed above, the evolution of solution gas in the wellbore fluid makes the wellbore fluid compressibility vary, which in turn produces a variable wellbore storage condition in the wellbore.

Kuchuk et al. 3 Semilog (MDH) plot of the wellbore pressure for a drawdown test. The above analysis procedure is called the semilog method or MDH for drawdown tests. The semilog straight line period is called the infinite acting radial flow regime. 38) with respect to ln(t) gives mr d pw (t) = . 4 presents a log-log plot of the pressure derivative for the drawdown test. 4, the logarithmic derivative exhibits an infinite acting radial flow regime for the same period as in the semilog plot after 10 hours.

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