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By Cosan Ayan (Ed.)

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For closely spaced points in a single wellbore, the gradient precision is determined by the offset of the pressure stations from a fixed location. The placement of this gradient in space, ultimately necessary for connectivity and fluid contact calculation, still requires well survey error data. Even if pressure and gauge accuracy were known, the measurement can also be influenced by other factors. One of the most noted is the supercharge effect. Formation testers typically operate in overbalanced conditions which can result in the sand face wellbore pressure being elevated above formation pressure.

This is exactly what we expect since as the number of points (N) and the number of wells ( r ) get larger the estimates of σ2 get closer and closer to the true σ2, hence their ratio tends toward one. This is seen in Fig. 12, which shows the F distribution for various N, r. 2 0 nu1 = 1, nu2 = 1 nu1 = 2, nu2 = 2 nu1 = 4, nu2 = 2 nu1 = 2, nu2 = 4 nu1 = 6, nu2 = 4 nu1 = 10, nu2 = 20 nu1=100, nu2=80 1 2 3 4 F Fig. 12 F distribution for various degrees of freedom for the numerator (nu1) and the denominator (nu2).

19 shows the shifted data with the best fit line using the techniques of the Connectivity Analysis section above. 339 is, of course, the weighted average of the individual slopes so it is reasonable. 3 for the slopes to be all the same. This is a bit inconclusive regarding the proposition that the slopes are the same.

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