# US 2021/0340869 A1 · Method and system for determining the flow rates of multiphase and/or multi-component fluid produced from an oil and gas well > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 2021/0340869 A1 - Document ID: US20210340869A1 - Status: Published application - Kind: A1 - Application number: 17/243,630 - Filed: 2021-04-29 - Published: 2021-11-04 - Earliest claimed: 2020-04-30 - Assignees: Schlumberger Technology Corporation - Applicants: Schlumberger Technology Corporation - Inventors: Denis Syresin; Pavel Evgenievich Spesivtsev; Jean-Philippe Hussenet; Bertrand Claude Theuveny; Victor Korneev; Nikolay Tarelko - Web page: https://patentgrep.com/patent/US20210340869A1 ## CPC - E21B 47/138: {Devices entrained in the flow of well-bore fluid for transmitting data, control or actuation signals} - E21B 49/0875: {determining specific fluid parameters} - E21B 47/10: Locating fluid leaks, intrusions or movements - E21B 2200/20: Computer models or simulations, e.g. for reservoirs under production, drill bits - E21B 2200/22: Fuzzy logic, artificial intelligence, neural networks or the like - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## Abstract A method and system for determining a flow rate of at least a phase or a component of a fluid produced from an oil and gas well are presented hereinafter. The fluid is one of a multiphase and of a multicomponent fluid. The method comprises, in a training phase, collecting primary measurements of pressure, temperature, and additional flow parameter of the produced fluid. The primary measurements are carried out at the wellhead by a set of sensors installed in a flow line for the produced fluid. In the training phase, the method also comprises collecting a flow rate of at least one of the phases or components of the produced fluid simultaneously measured by a reference multiphase flow meter installed in the flow line. It also includes establishing a relationship between the pressure, temperature, and the additional flow parameter and the flow rate of the at least one of the phases or components of the produced fluid. The method also comprises, in a subsequent production phase, determining the flow rate of the at least one of the phases or components of the produced fluid based on the primary measurements of the pressure, temperature, and the at least one additional flow parameter and on the established relationship. ## Claims ### Claim 1 A method for determining a flow rate of at least a phase or a component of a fluid produced from an oil and gas well, wherein the fluid is one of a multiphase and of a multicomponent fluid, comprising: in a training phase: collecting primary measurements of pressure, temperature, and at least one additional parameter of the flow of the produced fluid carried out at the wellhead by a set of sensors installed in a flow line for the produced fluid; collecting a flow rate of at least one of the phases or components of the produced fluid simultaneously measured by a reference multiphase flow meter installed in the flow line, establishing a relationship between the pressure, temperature, and the additional at least one additional flow parameter and the flow rate of the at least one of the phases or components of the produced fluid, and in a subsequent production phase: determining the flow rate of the at least one of the phases or components of the produced fluid based on the primary measurements of the pressure, temperature, and the at least one additional flow parameter and on the established relationship. ### Claim 2 (depends on 1) The method according to claim 1, comprising changing at least one flow parameter of the produced fluid in the flow line using a training device. ### Claim 3 (depends on 2) The method according to claim 2, including, in the training phase: collecting initial primary measurements and an initial flow rate of the at least one of the phases or components of the produced fluid, wherein the initial primary measurements and initial flow rate are simultaneously measured, changing the at least one flow parameter of the produced fluid in the flow line using the training device, and collecting additional primary measurements and an additional flow rate of the at least one of the phases or components of the produced fluid after the flow parameters change, wherein the additional primary measurements and additional flow rate are simultaneously measured, establishing the relationship based on the initial and additional primary measurements and initial and additional flow rates of the at least one of the phases or components of the produced fluid. ### Claim 4 (depends on 2) The method according to claim 2, wherein the at least one flow parameter includes at least one of the following: a water cut (WC), a gas factor (GVF), an gas flow rate, an oil flow rate and a water flow rate. ### Claim 5 (depends on 1) The method according to claim 1, comprising disconnecting the reference flow meter from the flow line after the end of the training phase. ### Claim 6 (depends on 2) The method according to claim 2, comprising disconnecting the training device after the end of the training phase. ### Claim 7 (depends on 1) The method according to claim 1, comprising measuring continuously the pressure, temperature, and the at least one additional parameter of the flow of the produced fluid using the set of sensors during the training and the production phase. ### Claim 8 (depends on 1) The method according to claim 1, comprising measuring continuously the flow rate of the at least one of the phases or components of the produced fluid. ### Claim 9 (depends on 1) The method according to claim 1, including, during the training phase: comparing the flow rate of the at least one phase or component of the produced fluid measured by the reference flow meter to a predicted flow rate of the at least one phase or component, wherein the predicted flow rate is determined based on the simultaneous primary measurements and the established relationship, determining a relative error between the measured flow rate and the predicted flow rate, comparing the relative error to a predetermined threshold, and terminating the training phase when the relative error is below the predetermined threshold. ### Claim 10 (depends on 1) The method according to claim 1, wherein establishing the relationship includes training a machine learning model. ### Claim 11 (depends on 1) The method according to claim 1, wherein the machine learning model is a supervised machine learning model. ### Claim 12 (depends on 1) The method according to claim 1, wherein the at least one additional parameter of the flow of the produced fluid collected as part of the primary measurements includes at least one of the following: effective fluid flow rate, velocity of at least one of the phases or components of the produced fluid, sound speed in the flow medium, effective density of a mixture of components or one or more phases, volume fraction of one or more components or phases, component viscosities, effective viscosity, dielectric permittivity, or conductivity. ### Claim 13 (depends on 1) The method according to claim 1, including selecting the at least one additional parameter based on previous downhole or surface measurements. ### Claim 14 (depends on 1) The method according to claim 1, including obtaining at least one additional reference parameter using the reference flow meter during the training phase, and using the one or more additional reference parameter to establish the relationship. ### Claim 15 (depends on 14) The method according to claim 14, wherein the at least one additional reference parameter include at least one of: a density of each component of the produced fluid, volume and mass fraction of each of the phases, pressure and temperature in the flow line. ### Claim 16 (depends on 1) The method according to claim 1, wherein the phases or components of the produced fluid include at least one of: liquid, gas, oil and water. ### Claim 17 A system for determining a flow rate of at least a phase or component of a fluid produced from an oil and gas well, wherein the fluid is one of a multiphase and multicomponent fluid, comprising: a set of sensors configured to carry out primary measurements, wherein the primary measurements include a measurement of pressure, temperature, and at least one additional flow parameter of the produced fluid, and installed in the produced fluid flow line at the wellhead; a reference multiphase flow meter configured to measure the flow rate of the at least one of the phases or components of the produced fluid and installed in the flow line of the produced fluid at the wellhead; a computing module configured to: collect the primary measurements from the set of sensors and the flow rate of the at least one of the phases or components from the reference multiphase flowmeter and establish a relationship between the measured pressure, temperature, and additional flow parameter of the produced fluid and the flow rate of the at least one of the phases and/or components of the produced fluid, determine the flow rate of the at least one of the phases or components of the produced fluid based on the primary measurements and the established relationship. ### Claim 18 (depends on 17) The system according to claim 17 further comprising a training device designed to change at least one parameter of the flow of the produced fluid. ### Claim 19 (depends on 17) The system according to claim 17, wherein the set of sensors comprises one or more of the following sensors: a Coriolis flow meter, an electromagnetic flow meter, an ultrasonic flow meter, a turbine flow meter, a vortex flow meter, a restriction device, an ultrasonic sensor for measuring one or more of transit time, speed of sound, or Doppler shift, an optical sensor, an infrared sensor, an X-ray sensor, a watercut sensor, an inductance sensor, a conductivity sensor, a resistance sensor, a microwave sensor, a capacitance sensor, a pressure sensor, a differential pressure sensor, a temperature sensor. ### Claim 20 A method for determining a flow rate of at least a phase or a component of a fluid produced from an oil and gas well, wherein the fluid is one of a multiphase and of a multicomponent fluid, comprising determining a flow rate of at least one of the phases or components of the produced fluid based on primary measurements of pressure, temperature, and at least one additional flow parameter and on an established relationship, wherein the primary measurements are carried out at the wellhead by a set of sensors installed in a flow line for the produced fluid, wherein the relationship has been established based on the primary measurements of pressure, temperature, and at least one additional flow parameter and on a flow rate of at least one of the phases or components of the produced fluid simultaneously measured by a reference multiphase flow meter installed in the flow line