Use of distributed temperature sensors during wellbore treatments
The invention relates to a method for treating subterranean formation comprising providing distributed temperature sensors, injecting a treatment fluid and monitoring the temperature across the treatment interval during the injection process.
1. A method for treating a drilled well, the method comprising the steps of:
positioning distributed temperature sensors on a fiber along an interval within a well, wherein the distributed temperature sensors provide substantially continuous temperature monitoring along the interval;
obtaining a baseline temperature profile across the interval;
monitoring substantially continuously the temperature along the interval;
calculating a differential temperature profile across the interval relative to the baseline temperature profile;
injecting a fluid into the well and into one or more zones surrounding the interval;
shutting-in the well until the temperature in the well substantially stabilizes;
monitoring the shut-in temperature along the interval during the shut-in period;
determining the shut-in temperature deviation relative to the baseline temperature profile across the interval; and
determining the one or more formation zones in which the injected fluid flowed.
2. The method of claim 1 , further comprising the step of determining the shut-in temperature deviation relative to the differential temperature profile measured prior to the shut-in.
3. The method of claim 1 , further comprising the step of determining the volume of the fluid injected into the one or more zones.
4. The method of claim 1 , wherein the fiber has a bottom end including a temperature sensor for substantially continuous monitoring of bottom-hole temperature.
5. The method of claim 1 , wherein the fiber has a bottom end, the bottom end including a temperature sensor for substantially continuous monitoring of bottom-hole temperature and a pressure sensor for measuring for substantially continuous monitoring of bottom-hole pressure.
6. The method of claim 1 , wherein the fiber has a bottom end including a pressure sensor for substantially continuous monitoring of bottom-hole pressure.
7. The method of claim 1 , further including the step of injecting a subsequent fluid pursuant to the step of determining the zone of injection of the prior injected fluid.
8. The method of claim 1 , further including the steps of:
injecting a diverter into the well pursuant to the step of determining the zone of injection of the prior injected fluid; and
injecting a subsequent fluid pursuant to the step of determining the zone of injection of the prior injected fluid.
9. The method of claim 1 , wherein the fluid is a matrix treatment agent.
10. The method of claim 1 , wherein the fluid is a matrix acidizing agent.
11. The method of claim 1 , wherein the fluid is a fracturing agent.
12. The method of claim 1 , wherein the fluid is an acid fracturing agent.
13. The method of claim 1 , wherein the fluid is a gravel packing agent.
14. A method for treating a drilled well, the method comprising the steps of:
positioning distributed temperature sensors on a fiber along an interval within a well surrounded by one or more formation zones, wherein the distributed temperature sensors provide substantially continuously temperature monitoring along the interval;
obtaining a baseline temperature profile across the interval;
monitoring substantially continuously the temperature along the interval;
calculating a differential temperature profile across the interval relative to the baseline temperature profile;
injecting a fluid non-reactive with the one or more formation zones into the well and the one or more formation zones;
calculating the injectivity of the one or more formation zones based on temperature profile along the interval during the step of injecting the non-reactive fluid;
injecting a fluid reactive to the one or more formation zones into the well and into one or more formation zones surrounding the interval pursuant to the calculating the injectivity step;
shutting-in the well until the temperature in the well substantially stabilizes;
monitoring the shut-in temperature along the interval during the shut-in period;
determining the shut-in temperature deviation relative to the baseline temperature profile across the interval; and
determining the one or mare formation zones in which the injected fluid flowed.
15. The method of claim 14 , further comprising the step of determining the shut-in temperature deviation relative to the differential temperature profile measured prior to the shut-in.
16. The method of claim 14 , further including the step of injecting a diverter into the well pursuant to the step of determining the injectivity of the one or more formation zones relative to the injecting of the non-reactive fluid.
17. The method of claim 14 , further comprising the step of determining the volume of the reactive fluid injected into the one or more zones.
18. The method of claim 14 , further including the step of injecting a subsequent fluid pursuant to the step of determining the zone of injection of the prior injected fluid.
19. The method of claim 14 , further including the steps of:
injecting a diverter into the well pursuant to the step of determining the zone of injection of the prior injected fluid; and
injecting a subsequent fluid pursuant to the step of determining the zone of injection of the prior injected fluid.
20. The method of claim 14 , further including the steps of:
injecting a diverter into the well pursuant to the step of determining the one or more formation zones of injection of the prior injected reactive fluid; and
injecting a subsequent fluid pursuant to the step of determining the zone of injection of the prior injected reactive fluid.