Real-time data acquisition and interpretation for coiled tubing fluid injection operations
Methods for acquiring and interpreting operating parameter data during an operation to inject a work fluid into a wellbore.
1. A method of acquiring and interpreting operating parameter data during an operation to inject a work fluid into a wellbore, the method comprising the steps of:
running a work string into a wellbore, the work string having a bottom hole assembly with a radially exterior surface to inject a work fluid into a portion of the wellbore and at least one sensor carried on the radial exterior surface of the bottom hole assembly to detect temperature and pressure at locations along the wellbore;
measuring temperature and pressure with the at least one sensor at the locations along the wellbore during the time the work string is run into the wellbore;
injecting a work fluid at a predetermined location in the wellbore;
removing the work string from the wellbore;
measuring temperature and pressure at the locations along the wellbore with the at least one sensor during the time the work string is removed from the wellbore; and
determining fluid flow rate into the formation based upon measured temperature and pressure.
2. The method of claim 1 wherein the work string is coiled tubing and the work fluid comprises acid.
3. The method of claim 1 wherein the work fluid comprises fracturing fluid containing proppant.
4. The method of claim 1 wherein the step of determining fluid flow rate into the formation further comprises calculating a real-time fluid flow rate into formation based upon measured single-point pressure and temperature data.
5. The method of claim 4 wherein the real-time fluid flow rate comprises a rate of acid flow into formation from acidizing.
6. The method of claim 4 wherein the real-time fluid flow rate comprises a rate of fracturing fluid flow into formation from hydraulic fracturing.
7. The method of claim 4 wherein the operation to inject a work fluid into a wellbore comprises a multistage stimulation treatment which includes acidizing and hydraulic fracturing.
8. The method of claim 1 further comprising the step of optimizing fluid flow rate and schedule based upon the determined fluid flow rate.
9. The method of claim 1 wherein the step of determining fluid flow rate into the formation further comprises:
transmitting a signal representative of measured pressure and temperature to a signal processor which is programmed to determine fluid flow rate from measured temperature and pressure; and
calculating said fluid flow rate using said signal processor.
10. The method of claim 9 wherein the step of transmitting a signal further comprises transmitting the signal from the bottom hole assembly to the signal processor via a conduit, the conduit being from the group consisting of: Telecoil or an optic fiber.
11. The method of claim 9 wherein the step of transmitting a signal further comprises transmitting the signal from the bottom hole assembly to the signal processor via a wireless communication link.
12. The method of claim 1 further comprising the step of storing measured temperature and pressure within a memory module.
13. A method of acquiring and interpreting operating parameter data during an operation to inject a work fluid into a wellbore, the method comprising the steps of:
running a work string into a wellbore, the work string having a bottom hole assembly to inject a work fluid into a portion of the wellbore and at least one sensor carried on a radially exterior surface of the bottom hole assembly to detect temperature and pressure at locations along the wellbore;
measuring temperature and pressure at the locations along the wellbore with the at least one sensor during the time the work string is run into the wellbore;
injecting a work fluid at a predetermined location in the wellbore;
removing the work string from the wellbore;
measuring temperature and pressure at the locations along the wellbore with the at least one sensor during the time the work string is removed from the wellbore; and
determining fluid flow rate into the formation based upon measured temperature and pressure wherein a real-time fluid flow rate into formation is calculated based upon measured single-point pressure and temperature data.
14. The method of claim 13 wherein the work string is coiled tubing and the work fluid comprises acid.
15. The method of claim 13 wherein the work fluid comprises fracturing fluid containing proppant.
16. The method of claim 13 wherein the operation to inject a work fluid into a wellbore comprises a multistage stimulation treatment which includes acidizing and hydraulic fracturing.
17. The method of claim 13 wherein the step of determining fluid flow rate into the formation further comprises:
transmitting a signal representative of measured pressure and temperature to a signal processor which is programmed to determine fluid flow rate from measured temperature and pressure; and
calculating said fluid flow rate using said signal processor.
18. The method of claim 17 wherein the step of transmitting a signal further comprises transmitting the signal from the bottom hole assembly to the signal processor via a conduit, the conduit being from the group consisting of: Telecoil or an optic fiber.
19. The method of claim 17 wherein the step of transmitting a signal further comprises transmitting the signal from the bottom hole assembly to the signal processor via a wireless communication link.