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A system for estimating a wellbore parameter includes a first component located at or near a terranean surface; a second component at least partially disposed within a wellbore at or near a subterranean zone; and a controller communicably coupled to the first and second components. The second compon

A system for estimating a wellbore parameter includes a first component located at or near a terranean surface; a second component at least partially disposed within a wellbore at or near a subterranean zone; and a controller communicably coupled to the first and second components. The second component is associated with a sensor. The controller is operable to: adjust a characteristic of an input fluid to the wellbore through a range of input values; receive, from the sensor, a plurality of output values of the input fluid that vary in response to the input values, the output values representative of a downhole condition; and estimate a wellbore parameter distinct from the downhole condition based on the measured output values.

대표청구항 ▼

1. A method for estimating a downhole wellbore parameter, comprising: adjusting a characteristic of an input fluid to a wellbore through a first range of input values of the input fluid;measuring, in the wellbore, a first plurality of output values of the input fluid that vary in response to the fir

1. A method for estimating a downhole wellbore parameter, comprising: adjusting a characteristic of an input fluid to a wellbore through a first range of input values of the input fluid;measuring, in the wellbore, a first plurality of output values of the input fluid that vary in response to the first range of input values, the first plurality of output values representative of a downhole condition of a downhole system;based on the measured first plurality of output values, calibrating at least one downhole sensor operable to measure the first plurality of output values;subsequent to the calibration, adjusting the characteristic of the input fluid to the wellbore through a second range of input values;measuring, in the wellbore, a second plurality of output values of the input fluid that vary in response to the input values in the second range, the second plurality of output values representative of the downhole condition; andestimating a wellbore parameter distinct from the downhole condition based on the measured second plurality of output values. 2. The method of claim 1, wherein the downhole system comprises a heated fluid generation system. 3. The method of claim 2, wherein the estimated wellbore parameter comprises a steam quality. 4. The method of claim 2, wherein adjusting a characteristic of an input fluid comprises adjusting a flow rate of the input fluid. 5. The method of claim 4, wherein the input fluid comprises at least one of: a fuel used for combustion;air used for combustion;a combined of the fuel and the air used for combustion; anda treatment fluid delivered to a combustor of the heated fluid generation system. 6. The method of claim 2, wherein the measured output values comprise a plurality of measured values representative of at least one of: a temperature of a heated fluid output from the heated fluid generation system used to treat a subterranean zone;a pressure of the heated fluid output from the heated fluid generation system used to treat a subterranean zone;an amount of oxygen in a wellbore at or near a downhole combustor in the heated fluid generation system; anda pressure drop across an orifice in the heated fluid generation system. 7. The method of claim 2, further comprising identifying a first output value among the first plurality of output values, wherein the first output value is associated with a change to a rate of change of the downhole condition. 8. The method of claim 7, wherein the first output value comprises at least one of: a value representative of an amount of combustion energy necessary to convert at least a portion of a treatment liquid supplied to a combustor of the heated fluid generation system to vapor; anda value representative of an amount of combustion energy necessary to convert substantially all of the treatment liquid supplied to the combustor of the heated fluid generation system to vapor. 9. The method of claim 1, wherein the estimated wellbore parameter is indicative of a mechanical health of the downhole system. 10. The method of claim 1, wherein adjusting a characteristic of an input fluid to a wellbore through a first range of input values comprises adjusting the characteristic of the input fluid at or near a terranean surface. 11. The method of claim 1, wherein the downhole system comprises a gravel packing system. 12. The method of claim 11, wherein the estimated wellbore parameter comprises a location of an injected particulate. 13. The method of claim 12, wherein the injected particulate comprises at least one of gravel or proppant. 14. The method of claim 1, wherein calibrating at least one downhole sensor operable to measure the first plurality of output values comprises at least one of: calibrating the at least one downhole sensor based at least in part on the measured first plurality of output values of the input fluid that are measured in the wellbore;calibrating the at least one downhole sensor based at least in part on a command from a user; or;calibrating the at least one downhole sensor based at least in part on an alarm. 15. The method of claim 14, wherein calibrating the at least one downhole sensor based at least in part on the measured first plurality of output values of the input fluid comprises: measuring, at or near a terranean surface, a third plurality of output values of the input fluid that vary in response to the input values;comparing the measured first plurality of output values of the input fluid that are measured in the wellbore to the measured third plurality of output values of the input fluid that vary in response to the input values; andbased on the comparison of the measured first plurality of output values and the measured third plurality of output values, calibrating the at least one downhole sensor. 16. The method of claim 15, further comprising: determining a fouling factor based on the comparison of the measured first plurality of output values and the measured second plurality of output values. 17. A system for estimating a wellbore parameter, comprising: a first component located at or near a terranean surface;a second component at least partially disposed within a wellbore at or near a subterranean zone, the second component associated with a sensor; anda controller communicably coupled to the first and second components, the controller operable to: adjust a characteristic of an input fluid to the wellbore through a first range of input values of the input fluid;receive, from the sensor, a first plurality of output values of the input fluid that vary in response to the input values, the first plurality of output values representative of a downhole condition; andreceive a second plurality of output values of the input fluid that are measured at or near the terranean surface and vary in response to the input values;compare the measured first plurality of output values of the input fluid that are measured in the wellbore to the measured second plurality of output values of the input fluid that vary in response to the input values;based on the comparison of the measured first plurality of output values and the measured second plurality of output values, calibrate the sensor; andestimate a wellbore parameter distinct from the downhole condition based on the measured output values. 18. The system of claim 17, wherein the first and second components comprise at least a portion of one of: a heated fluid generation system; ora gravel packing system. 19. The system of claim 18, wherein the estimated wellbore parameter comprises a steam quality. 20. The system of claim 18, wherein the characteristic of the input fluid comprises a flow rate of at least one fluid used for combustion in the heated fluid generation system. 21. The system of claim 20, wherein the flow rate of the at least one fluid used for combustion comprises at least one of: a flow rate of a fuel used for combustion;a flow rate of air used for combustion; anda combined mass flow rate of the fuel and air used for combustion. 22. The system of claim 18, wherein the characteristic of the input fluid comprises a flow rate of a treatment fluid delivered to a combustor of the heated fluid generation system. 23. The system of claim 18, wherein the measured output values comprise a plurality of measured values representative of at least one of: a temperature of a heated fluid output from the heated fluid generation system used to treat the subterranean zone;a pressure of the heated fluid output from the heated fluid generation system used to treat the subterranean zone;an amount of oxygen in the wellbore at or near a downhole combustor in the heated fluid generation system;a pressure drop across an orifice in the heated fluid generation system; anda pressure differential across a gravel pack at least partially disposed in the wellbore. 24. The system of claim 18, wherein the controller is further operable to identify a first output value among the plurality of output values, wherein the first output value is associated with a change to a rate of change of the downhole condition. 25. The system of claim 24, wherein the first output value comprises at least one of: a value representative of an amount of combustion energy necessary to convert at least a portion of a treatment liquid supplied to a combustor of the heated fluid generation system to vapor; anda value representative of an amount of combustion energy necessary to convert substantially all of the treatment liquid supplied to the combustor of the heated fluid generation system to vapor. 26. The system of claim 17, wherein the controller is further operable to calibrate the sensor based, at least in part, on at least one of the measured first plurality of output values of the input fluid that are measured in the wellbore;a command from a user; or;an alarm generated by the controller. 27. The system of claim 17, wherein the controller is further operable to: determine a fouling factor based on the comparison of the measured first plurality of output values and the measured second plurality of output values.