PetroWiki: Difference between revisions

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 | style="padding:2px;" | <h2 id="mp-tfa-h2" style="margin:3px; background:#0068b3; font-family:inherit; font-size:120%; font-weight:bold; border:1px solid #0068b3; text-align:left; color:#FFF; padding:0.2em 0.4em;">Featured topic page<span style="font-size:85%; font-weight:normal;"></span></h2>
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-| style="color:#000;" | <div id="mp-tfa" style="padding:2px 5px">'''[[Estimating horizontal well productivity]]'''
+| style="color:#000;" | <div id="mp-tfa" style="padding:2px 5px">'''[[Pore pressure prediction using seismic]]'''
-There are two fundamental problems that make accurately estimating the productivity of a horizontal well more difficult than estimating the productivity of a vertical well. The theoretical models available have a number of simplifying assumptions and the data required for even these simplified models are not likely to be available. Still, we must make estimates and decisions based on those estimates. In this page, two productivity models that have proved useful in practice are discussed.
+Drilling engineers require estimates of the fluid pressures that they are likely to encounter in any given well to anticipate mud weights required to maintain optimal drilling rates and safety. In addition, the locations of anomalous pore-pressure regions are of interest in exploration because they often:
-[http://petrowiki.org/Estimating_horizontal_well_productivity Learn more....]
+*Correlate with highly productive “sweet” spots in otherwise tight gas sands;
+*Provide constraints on basin evolution;
+*May correspond to density of open fractures, including bedding-plane fractures.
+[http://petrowiki.org/Pore_pressure_prediction_using_seismic Learn more....]
 </div>
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