Determination of stimulated reservoir volume and estimated ultimate recovery of hydrocarbons for unconventional reservoirs
A method for determining SRV and EUR includes: monitoring an amount and a density of a hydrocarbon fluid produced from the production well; obtaining a cumulative amount of the fluid that has accumulated from a beginning of production; obtaining a relationship between the cumulative amount and a square root of the time; determining a deviation point where the relationship changes from linear to non-linear; determining a deviation amount of the fluid corresponding to the deviation point; determining a first density of the hydrocarbon fluid at the beginning of production, a second density at a pore pressure equal to a bottom hole pressure in the production well, a first porosity at the beginning of production, and a second porosity for a pore pressure equal to the bottom hole pressure; and determining SRV and the EUR based on the deviation amount, the first and second densities, and the first and second porosities.
1. A method, comprising:
creating a plurality of hydraulic fractures using a horizontal well in an unconventional reservoir, wherein the unconventional reservoir comprises a plurality of stimulated zones;
producing, using a production well comprising the horizontal well, hydrocarbon fluid from the unconventional reservoir;
monitoring, via a monitor disposed at a well head of the production well in the unconventional reservoir, an amount of the hydrocarbon fluid that is produced from the production well, and monitoring a density of the hydrocarbon fluid;
obtaining a cumulative amount of the hydrocarbon fluid that has accumulated over time from a beginning of reservoir production;
obtaining a relationship between the cumulative amount of the hydrocarbon fluid as a function of production time and a square root value of the production time in the function;
determining, by the monitor, a deviation point where the relationship changes from linear to non-linear;
determining, by the monitor, a deviation amount of the hydrocarbon fluid that corresponds to the deviation point;
determining, by the monitor, a first density of the hydrocarbon fluid under a reservoir condition of the hydrocarbon fluid being produced at the production well, a second density of the hydrocarbon fluid at a pore pressure equal to a bottom hole pressure in the production well, a first porosity under reservoir condition at the beginning of reservoir production, and a second porosity of the reservoir for a pore pressure equal to the bottom hole pressure in the production well;
determining, by the monitor, stimulated reservoir volume (SRV) and estimated ultimate recovery (EUR) for the unconventional reservoir based on the deviation amount, the first density, the second density, the first porosity, and the second porosity,
wherein the SRV is calculated as
S
R
V
=
1.5
π
Q
c
m
i
-
m
w
,
where Q c is the deviation amount, m i is a product of the first density and the first porosity, and m w is a product of the second density and the second porosity, and
wherein the EUR is calculated as
EUR=√{square root over (1.5π)} Q c ,
where Q c is the deviation amount; and
managing, at the production well using the monitor, the hydrocarbon fluid based on the SRV and the EUR of the unconventional reservoir.
2. The method according to claim 1 , further comprising plotting the relationship between the cumulative amount and the square root value of the time.