Determining fluid rate and phase information for a hydrocarbon well using predictive models

A system for determining rate and phase composition of fluid produced from or injected into a well, the system comprising:

• one or more sensors located at the well;
• and
• a processing system configured to perform a method comprising;
• obtaining first temperature and pressure measurements from the one or more sensors at the well;
• obtaining indicators of valve and choke positions from the sensors at the well and at a flowline coupled to the well;
• applying, by a processor, the first temperature and pressure measurements to a plurality of predictive well models to calculate an estimated value of fluid rate and phase composition from each of the predictive well models responsive to the temperature and pressure measurements;
• selecting at least one of the predictive well models based on the indicators of valve and choke positions;
• deriving a first fluid rate and phase composition result from the estimate value of fluid rate and phase composition from the at least one of the predictive well models that was selected;
• storing, in a memory, the first fluid rate and phase composition result and a time indicator associated with a time the first temperature and pressure measurements were obtained;
• obtaining second temperature and pressure measurements from the one or more sensors at the well;
• comparing the second temperature and pressure measurements with the first temperature and pressure measurements;
• and
• responsive to the second temperature and pressure measurements matching the first temperature and pressure measurements within a tolerance limit, storing, in the memory, the first fluid rate and phase composition result associated with a second time indicator associated with a time the second temperature and pressure measurements were obtained.

A non-transitory computer readable medium comprising instructions for causing one or more processors to perform a method of determining rate and phase composition of fluid produced from or injected into a well, the method comprising:

• obtaining first temperature and pressure measurements from sensors at the well;
• obtaining indicators of valve and choke positions from the sensors at the well and at a flowline coupled to the well;
• applying, by a processor, the first temperature and pressure measurements to a plurality of predictive well models to calculate an estimated value of fluid rate and phase composition from each of the predictive well models responsive to the temperature and pressure measurements;
• selecting at least one of the predictive well models based on the indicators of valve and choke positions;
• deriving a first fluid rate and phase composition result from the estimate value of fluid rate and phase composition from the at least one of the predictive well models that was selected;
• storing, in a memory, the first fluid rate and phase composition result and a time indicator associated with a time the first temperature and pressure measurements were obtained;
• obtaining second temperature and pressure measurements from the sensors at the well;
• comparing the second temperature and pressure measurements with the first temperature and pressure measurements;
• and
• responsive to the second temperature and pressure measurements matching the first temperature and pressure measurements within a tolerance limit, storing, in the memory, the first fluid rate and phase composition result associated with a second time indicator associated with a time the second temperature and pressure measurements were obtained.

A method of determining rate and phase composition of fluid produced from or injected into a well, the method comprising:

• obtaining temperature and pressure measurements from sensors at the well;
• obtaining indicators of valve and choke positions from the sensors at the well and at a flowline coupled to the well;
• applying, by a processor, the temperature and pressure measurements to a plurality of predictive well models to calculate an estimated value of fluid rate and phase composition from each of the predictive well models responsive to the temperature and pressure measurements;
• selecting one of the predictive well models based on the indicators of valve and choke positions;
• and
• deriving a fluid rate and phase composition result using the estimated value of fluid rate and phase composition from the one of the predictive well models that was selected.