CPC E21B 47/06 (2013.01) [E21B 47/07 (2020.05); E21B 49/00 (2013.01); E21B 49/08 (2013.01); G01V 9/00 (2013.01); E21B 49/0875 (2020.05)] | 22 Claims |
1. A computer-implemented method comprising:
measuring a wellbore pressure (p) in a wellbore over a production time (t) using a pressure gauge;
receiving, by a computer system, hydrocarbon reservoir production information associated with a naturally fractured hydrocarbon reservoir with entrapped hydrocarbons in which the wellbore has been formed to produce the hydrocarbons, the information comprising the wellbore pressure (p) measured over production time (t), production rate (qw), pressure at standard conditions (psc), temperature at standard conditions (Tsc), thickness of formation in which the wellbore is formed (h), radius of the wellbore (re), hydrocarbon viscosity (p), reservoir temperature (T), and reservoir porosity and compressibility;
determining, by the computer system, from the wellbore pressure measured over the production time, a time rate of change of the wellbore pressure over the production time;
identifying, by the computer system and from a plot of a logarithmic time rate of change of the wellbore pressure (Y-axis) over logarithmic production time (X-axis), a plurality of plot sections, each plot section representing a respective flow regime of a flow of the hydrocarbons from the reservoir;
determining, by the computer system and for each plot section, a corresponding time rate of change of the wellbore pressure Y-axis intersect value;
determining, by the computer system, a reservoir parameter for each corresponding time rate of change of the wellbore pressure Y-axis intersect value determined for each plot section; and
generating the plot of the time rate of change of the wellbore pressure over the logarithmic production time.
|