# US 2025/0085148 A1 · Multiphase flow meter framework > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 2025/0085148 A1 - Document ID: US20250085148A1 - Status: Published application - Kind: A1 - Application number: 18/696,033 - Filed: 2022-11-18 - Published: 2025-03-13 - Earliest claimed: 2021-11-19 - Assignees: Schlumberger Technology Corporation - Applicants: Schlumberger Technology Corporation - Inventors: Massimiliano Fiore; Kun Yang; Guillaume Jolivet; Alexandre Martins - Web page: https://patentgrep.com/patent/US20250085148A1 ## CPC - G01F 1/74: Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid - G01F 1/44: Venturi tubes - G01F 1/704: using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter (G01F1/76, G01F25/00 take precedence) - G01F 25/10: of flowmeters - G01F: MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME ## Abstract A method can include receiving multiphase flow data via a multiphase flow meter during a flowback production period of a hydraulically fractured well that extends into a formation that includes formation fluid; determining one or more water properties during at least a portion of the flowback production period using the multiphase flow data and a predictive model; and, based on the determining, outputting values indicative of one or more of oil flow rate, gas flow rate, and water flow rate during the flowback production period. ## Claims ### Claim 1 A method comprising: receiving multiphase flow data via a multiphase flow meter during a flowback production period of a hydraulically fractured well that extends into a formation that comprises formation fluid; determining one or more water properties during at least a portion of the flowback production period using the multiphase flow data and a predictive model; and based on the determining, outputting values indicative of one or more of oil flow rate, gas flow rate, and water flow rate during the flowback production period. ### Claim 2 (depends on 1) The method of claim 1, wherein water salinity increases with respect to time toward a formation water salinity of the formation fluid during the flowback production period. ### Claim 3 (depends on 1) The method of claim 1, comprising receiving data from a water sample taken during the flowback production period and adjusting the predictive model using the data. ### Claim 4 (depends on 3) The method of claim 3, wherein the data from the water sample comprises water density data and temperature data and wherein the one or more water properties comprise one or more of water salinity and water mass attenuations. ### Claim 5 (depends on 1) The method of claim 1, wherein the predictive model comprises parameters. ### Claim 6 (depends on 5) The method of claim 5, comprising adjusting the predictive model by fitting the parameters to data acquired from at least one water sample collected from the hydraulically fractured well or collected from a well proximate to the hydraulically fractured well that is in fluid communication with the formation. ### Claim 7 (depends on 6) The method of claim 6, wherein the fitting determines parameter values for the parameters. ### Claim 8 (depends on 5) The method of claim 5, comprising acquiring water property data for one or more of the one or more water properties during the flowback production period and adjusting at least one of the parameters using at least a portion of the water property data. ### Claim 9 (depends on 1) The method of claim 1, wherein the predictive model comprises a plurality of parameters and wherein values for the parameters are determined by fitting the predictive model to data from a number of water samples taken during the flowback production period. ### Claim 10 (depends on 9) The method of claim 9, wherein the number of water samples is more than the number of parameters. ### Claim 11 (depends on 1) The method of claim 1, wherein the multiphase flow comprises water, oil and gas. ### Claim 12 (depends on 1) The method of claim 1, wherein the multiphase flow meter emits at least two incident gamma ray energy levels. ### Claim 13 (depends on 12) The method of claim 12, wherein the predictive model accounts for water mass attenuations at the at least two incident gamma ray energy levels wherein the water mass attenuations depend on one or more of water density and water salinity. ### Claim 14 (depends on 1) The method of claim 1, wherein the multiphase flow meter comprises a processor and wherein the determining is performed by the processor. ### Claim 15 (depends on 1) The method of claim 1, wherein the multiphase flow meter comprises an interface that transmits the multiphase flow data and wherein the determining is performed by a processor that is separate from the multiphase flow meter that receives the transmitted multiphase flow data. ### Claim 16 (depends on 1) The method of claim 1, wherein the outputting comprises outputting one or more of water-liquid ratio, water salinity, and water density with respect to time. ### Claim 17 (depends on 1) The method of claim 1, comprising initializing the multiphase flow meter, wherein initializing comprises determining multiple gamma ray energy absorptions for an oil phase, a water phase, and a gas phase. ### Claim 18 (depends on 17) The method of claim 17, wherein the determining operates without using further initialization measurements for the multiphase flow meter as to gamma ray energy absorptions. ### Claim 19 A system comprising: a processor; memory accessible to the processor; processor-executable instructions stored in the memory and executable by the processor to instruct the system to: receive multiphase flow data via a multiphase flow meter during a flowback production period of a hydraulically fractured well that extends into a formation that comprises formation fluid; perform a determination for one or more water properties during at least a portion of the flowback production period using the multiphase flow data and a predictive model; and based on the determination, output values indicative of one or more of oil flow rate, gas flow rate, and water flow rate during the flowback production period. ### Claim 20 One or more computer-readable media comprising computer-executable instructions executable by a system to instruct the system to: receive multiphase flow data via a multiphase flow meter during a flowback production period of a hydraulically fractured well that extends into a formation that comprises formation fluid; perform a determination for one or more water properties during at least a portion of the flowback production period using the multiphase flow data and a predictive model; and based on the determination, output values indicative of one or more of oil flow rate, gas flow rate, and water flow rate during the flowback production period.