# US 11,111,784 B2 · System and method for determining bottomhole conditions during flowback operations of a shale reservoir > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 11,111,784 B2 - Document ID: US11111784B2 - Status: Granted - Kind: B2 - Application number: 15/545,771 - Filed: 2016-01-22 - Published: 2018-01-18 - Granted: 2021-09-07 - Earliest claimed: 2015-01-23 - Assignees: Schlumberger Technology Corporation - Applicants: Schlumberger Technology Corporation - Inventors: Dean Michael Willberg; Ryan Donald Williams; Katharine Moncada; Jean Desroches; Philippe Enkababian; Pavel Spesivtsev - Web page: https://patentgrep.com/patent/US11111784B2 ## CPC - E21B 49/008: {by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor (measuring pressure E21B47/06)} - E21B 34/025: {Chokes or valves in wellheads and sub-sea wellheads for variably regulating fluid flow} - E21B 41/00: Equipment or details not covered by groups E21B15/00 - E21B40/00 - E21B 43/12: Methods or apparatus for controlling the flow of the obtained fluid to or in wells (E21B43/25 takes precedence; valve arrangements E21B34/00) - E21B 43/267: reinforcing fractures by propping - E21B 47/06: Measuring temperature or pressure - E21B 49/005: {Testing the nature of borehole walls or the formation by using drilling mud or cutting data} - E21B 47/107: using acoustic means - G01V 9/02: Determining existence or flow of underground water - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS - G01V: GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS (means for indicating the location of accidentally buried, e.g. snow-buried, persons A63B29/02) ## Abstract A system and method is provided that determines at least one bottomhole condition during flowback operations in a well that traverses a hydraulically fractured reservoir. The system and method measure fluid properties of fluids produced at a surface-location of the well during the flowback operations. A transient fluid flow simulator determines composition and properties of fluids in the well between the surface-location of the well and at least one bottomhole-location of the well based on the measured fluid properties. At least one bottomhole condition in the well is determined based on the composition and properties of fluids in the well between the surface-location and at least one bottomhole-location of the well. ## Claims ### Claim 1 A method of determining at least one bottomhole condition in a well, the method comprising: measuring fluid properties, via one or more sensors, of fluids produced at a surface-location of the well, wherein the well traverses a hydraulically fractured reservoir, wherein the measured fluid properties include flow rates of different fluid phases that are part of the fluids, and wherein the different fluid phases are selected from the group including an oil phase, a gas phase, a water phase, and a solid phase; using a transient fluid flow simulator to determine composition and properties of the fluids in the well between a surface-location of the well and at least one bottomhole-location of the well based on the measured fluid properties and based on calculations involving data characterizing mineralogy of the hydraulically fractured reservoir; calculating at least one bottomhole condition in the well based on the determined composition and properties of the fluids in the well between the surface-location and the at least one bottomhole-location of the well; and controlling a flowback operation in the well based at least in part on the at least one bottomhole condition; wherein controlling the flowback operation in the well further comprises: calculating a drawdown pressure in the well at a particular time, wherein the drawdown pressure in the well is a function of a rate of a bottomhole pressure change and a bottomhole fluid rate; determining when the calculated drawdown pressure is outside a particular safe zone defined by upper and lower limits on drawdown pressure as a function of time; and adjusting a surface-located choke in response to determining the calculated drawdown pressure is outside the particular safe zone. ### Claim 2 (depends on 1) The method according to claim 1, wherein: the measured fluid properties include pressure before or at the surface-located choke. ### Claim 3 (depends on 2) The method according to claim 2, wherein: the surface-located choke includes a variable sized aperture, and the measured fluid properties include pressure downstream of the variable sized aperture of the surface-located choke. ### Claim 4 (depends on 2) The method according to claim 2, wherein: the surface-located choke includes a variable sized aperture, and the measured fluid properties include pressure upstream of the variable sized aperture of the surface-located choke. ### Claim 5 (depends on 1) The method according to claim 1, wherein: the transient fluid flow simulator determines the composition and properties of the fluids in the well between the surface-location of the well and the at least one bottomhole-location of the well based further on calculations involving a set point or other predefined parameter. ### Claim 6 (depends on 1) The method according to claim 1, wherein: the transient fluid flow simulator determines the composition and properties of the fluids in the well between the surface-location of the well and the at least one bottomhole-location of the well based further on calculations involving data from at least one other well. ### Claim 7 (depends on 1) The method according to claim 1, wherein: the transient fluid flow simulator determines the composition and properties of the fluids in the well between the surface-location of the well and the at least one bottomhole-location of the well based further on calculations involving data derived during drilling the well. ### Claim 8 (depends on 1) The method according to claim 1, wherein: the at least one bottomhole condition includes pressure in the well at at least one bottomhole location of the well. ### Claim 9 (depends on 1) The method according to claim 1, wherein: the transient fluid flow simulator determines the composition and properties of the fluids in the well between the surface-location of the well and the at least one bottomhole location of the well for a first period of time based on the measured fluid properties measured over a second period of time that precedes the first period of time. ### Claim 10 (depends on 9) The method according to claim 9, wherein: the transient fluid flow simulator determines the composition and properties of the fluids in the well for the first period of time based on an extrapolation of the measured fluid properties during the second period of time. ### Claim 11 (depends on 1) The method according to claim 1, further comprising: using a plurality of transient fluid flow simulators to individually determine the composition and properties of the fluids in the well between the surface-location of the well and at least one bottomhole-location of the well based on the measured fluid properties; comparing the measured fluid properties, respectively, with sets of properties determined by each of the transient fluid flow simulators; and selecting at least one of the transient fluid flow simulators based on the comparing, wherein the at least one bottomhole condition in the well is calculated based on the determination of the composition and properties of the fluids in the well determined by the selected at least one of the transient fluid flow simulators, wherein the plurality of transient fluid flow simulators reflect different flowback scenarios. ### Claim 12 (depends on 1) The method according to claim 1, wherein: the fluid properties of the fluids produced at a surface-location of the well are measured in real-time; the transient fluid flow simulator determines in real-time the composition and properties of the fluids in the well between the surface-location of the well and at least one bottomhole-location of the well based on the real-time measurement of the fluid properties; and the at least one bottomhole condition in the well is calculated in real-time based on the real-time determination of the composition and properties of the fluids in the well, wherein the transient fluid flow simulator is updated in real-time such that determined properties of the fluids at the surface-location in the well matches the measured fluid properties at the surface-location in the well. ### Claim 13 (depends on 1) The method according to claim 1, wherein: calculating the at least one bottomhole condition in the well includes calculating multiple estimates of bottomhole pressure and a statistical distribution of the bottomhole pressure. ### Claim 14 (depends on 1) The method according to claim 1, wherein: adjusting the surface-located choke comprises closing the surface-located choke when the calculated drawdown pressure is above the particular safe zone or opening the surface-located choke when the calculated drawdown pressure is below the particular safe zone. ### Claim 15 A method of determining fracture properties in a hydraulically fractured reservoir, the method comprising: measuring fluid properties, via one or more sensors, of fluids produced at a surface-location of a well that traverses the hydraulically fractured reservoir, wherein the measured fluid properties include flow rates of different fluid phases that are part of the fluids, and wherein the different fluid phases are selected from the group including an oil phase, a gas phase, a water phase, and a solid phase; using a transient fluid flow simulator to determine at least one fracture property at at least one bottomhole location of the well over time based on the measured fluid properties, wherein the at least one fracture property characterizes fracture conductivity of a fracture in a near-wellbore region adjacent the well; and controlling a flowback operation in the well based at least in part on the at least one fracture property; wherein controlling the flowback operation in the well further comprises: calculating a drawdown pressure in the well at a particular time, wherein the drawdown pressure in the well is a function of a rate of a bottomhole pressure change and a bottomhole fluid rate; determining when the calculated drawdown pressure is outside a particular safe zone defined by upper and lower limits on drawdown pressure as a function of time; and adjusting a surface-located choke in response to determining the calculated drawdown pressure is outside the particular safe zone. ### Claim 16 (depends on 15) The method according to claim 15, wherein: the at least one fracture property characterizes unpropped fracture area of a fracture in a near-wellbore region adjacent the well. ### Claim 17 (depends on 15) The method according to claim 15, further comprising: estimating a safe drawdown operating envelope based on the determined at least one fracture property, wherein the safe drawdown operating envelope is defined as a function of bottomhole pressure, rate of bottomhole pressure change, and bottomhole fluid rate, and wherein the safe drawdown operating envelope defines an upper drawdown limit corresponding to a condition where fracture pinch is predicted in a near-wellbore region adjacent the well. ### Claim 18 (depends on 17) The method according to claim 17, further comprising: determining a risk of unwanted condition based on the at least one fracture property, wherein the unwanted condition is selected from the group consisting of formation failure, fracture pinchout and a combination thereof, wherein the safe drawdown operating envelope defines an upper drawdown limit corresponding to a condition where the fracture pinch is predicted in a near-wellbore region adjacent the well, and wherein the safe drawdown operating envelope is based on the determined risk of unwanted condition. ### Claim 19 A method of determining at least one bottomhole condition in a well, the method comprising: measuring fluid properties, via one or more sensors, of fluids produced at a surface-location of the well, wherein the well traverses a hydraulically fractured reservoir, wherein the measured fluid properties include flow rates of different fluid phases that are part of the fluids, and wherein the different fluid phases are selected from the group including an oil phase, a gas phase, a water phase, and a solid phase; using a transient fluid flow simulator to determine composition and properties of the fluids in the well between a surface-location of the well and at least one bottomhole-location of the well based on the measured fluid properties and based on calculations involving data derived during drilling the well; calculating at least one bottomhole condition in the well based on the determined composition and properties of the fluids in the well between the surface-location and the at least one bottomhole-location of the well; and controlling a flowback operation in the well based at least in part on the at least one bottomhole condition; wherein controlling the flowback operation in the well further comprises: calculating a drawdown pressure in the well at a particular time, wherein the drawdown pressure in the well is a function of a rate of a bottomhole pressure change and a bottomhole fluid rate; determining when the calculated drawdown pressure is outside a particular safe zone defined by upper and lower limits on drawdown pressure as a function of time; and adjusting a surface-located choke in response to determining the calculated drawdown pressure is outside the particular safe zone. ### Claim 20 A method of determining at least one bottomhole condition in a well, the method comprising: measuring fluid properties, via one or more sensors, of fluids produced at a surface-location of the well, wherein the well traverses a hydraulically fractured reservoir, wherein the measured fluid properties include flow rates of different fluid phases that are part of the fluids, and wherein the different fluid phases are selected from the group including an oil phase, a gas phase, a water phase, and a solid phase; using a transient fluid flow simulator to determine composition and properties of the fluids in the well between a surface-location of the well and at least one bottomhole-location of the well based on the measured fluid properties; calculating at least one bottomhole condition in the well based on the determined composition and properties of the fluids in the well between the surface-location and the at least one bottomhole-location of the well, wherein calculating the at least one bottomhole condition in the well includes calculating multiple estimates of bottomhole pressure and a statistical distribution of the bottomhole pressure; and controlling a flowback operation in the well based at least in part on the at least one bottomhole condition; wherein controlling the flowback operation in the well further comprises: calculating a drawdown pressure in the well at a particular time, wherein the drawdown pressure in the well is a function of a rate of a bottomhole pressure change and a bottomhole fluid rate; determining when the calculated drawdown pressure is outside a particular safe zone defined by upper and lower limits on drawdown pressure as a function of time; and adjusting a surface-located choke in response to determining the calculated drawdown pressure is outside the particular safe zone. ### Claim 21 (depends on 20) The method according to claim 20, further comprising: measuring at least one bottomhole condition of the well at a bottomhole location of the well; comparing the at least one measured bottomhole condition with the calculated at least one bottomhole condition; and tuning or validating the transient flow simulator based on the comparison between the at least one measured bottomhole condition with the calculated at least one bottomhole condition.