WO2021066797A1 - Appareil de surveillance d'eau dans l'huile et procédés associés - Google Patents

Appareil de surveillance d'eau dans l'huile et procédés associés Download PDF

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Publication number
WO2021066797A1
WO2021066797A1 PCT/US2019/053788 US2019053788W WO2021066797A1 WO 2021066797 A1 WO2021066797 A1 WO 2021066797A1 US 2019053788 W US2019053788 W US 2019053788W WO 2021066797 A1 WO2021066797 A1 WO 2021066797A1
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WIPO (PCT)
Prior art keywords
water
fluid
density
oil
data
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PCT/US2019/053788
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English (en)
Inventor
Francis Allouche
Elena BORISOVA
Original Assignee
Schlumberger Technology Corporation
Schlumberger Canada Limited
Services Petroliers Schlumberger
Schlumberger Technology B.V.
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Application filed by Schlumberger Technology Corporation, Schlumberger Canada Limited, Services Petroliers Schlumberger, Schlumberger Technology B.V. filed Critical Schlumberger Technology Corporation
Priority to PCT/US2019/053788 priority Critical patent/WO2021066797A1/fr
Publication of WO2021066797A1 publication Critical patent/WO2021066797A1/fr

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Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
    • G01N33/26—Oils; Viscous liquids; Paints; Inks
    • G01N33/28—Oils, i.e. hydrocarbon liquids
    • G01N33/2835—Specific substances contained in the oils or fuels
    • G01N33/2847—Water in oils
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N9/00—Investigating density or specific gravity of materials; Analysing materials by determining density or specific gravity
    • G01N9/36—Analysing materials by measuring the density or specific gravity, e.g. determining quantity of moisture

Definitions

  • This disclosure relates generally to surface well testing and, more particularly, to water-in-oil monitoring apparatus and related methods.
  • Surface well tests include sampling and analyzing the content of water in a fluid containing oil and water.
  • Known water cut analyzers measure the instantaneous volumetric fraction of water in oil. For example, some known watercut analyzers measure a density of the water-oil mixture and calculate the water fraction based on the density of water and oil at line conditions (e.g., pressure and/or temperature conditions under which the water-oil mixture flows). Some other known water cut analyzers analyze light absorption properties of the fluid mixture. Some other known examples determine the water fraction based on dielectric measurements involving, for example, capacitance.
  • An example apparatus includes a first density meter coupled to a fluid conduit.
  • the first density meter is to generate fluid density data for a fluid flowing through the fluid conduit, the fluid including oil.
  • the apparatus includes a water cut analyzer coupled to the fluid conduit.
  • the water cut analyzer is to generate water cut data for the fluid.
  • the water cut data is uncalibrated for one or more properties of the oil.
  • the example apparatus includes a processor in communication with the first density meter and the water cut analyzer. The processor is to determine a water-in-oil concentration for the fluid based on the fluid density data, the water cut data, and water density data.
  • Another example apparatus includes a calculator to define a relationship between a density of oil in a fluid flowing through a fluid conduit of a separator and a water-in-oil concentration of the fluid.
  • the calculator is to determine the water-in-oil concentration for the fluid based on fluid density data, water density data, water cut data, and the relationship between the density of the oil and the water-in-oil concentration.
  • the example apparatus includes a water cut evaluator to perform a comparison of the water- in-oil concentration to a threshold.
  • the example apparatus includes a communicator to output an indicator of water content in the fluid based on the comparison.
  • An example method includes measuring a density of a fluid including oil flowing through a fluid conduit to generate density data; measuring a water cut of the fluid to generate water cut data; determining a water-in-oil concentration of the fluid based on the density data and the water cut data; and determining a density of the oil in the fluid based on the water-in-oil concentration.
  • Another example apparatus includes means for measuring density of a fluid including oil flowing through a fluid conduit.
  • the means for measuring density is to generate density data.
  • the example apparatus includes means for measuring a water cut of the fluid.
  • the means for measuring the water cut is to generate water cut data.
  • the example apparatus includes means for determining a water-in-oil concentration of the fluid based on the density data and the water cut data.
  • the means for determining is to determine a density of the oil in the fluid based on the water-in-oil concentration.
  • FIG. 1 illustrates an example system constructed in accordance with teachings disclosed herein and including a fluid analyzer for determining water cut of a fluid.
  • FIG. 2 illustrates an example system constructed in accordance with teachings disclosed herein and including the fluid analyzer for determining water cut of a fluid.
  • FIG. 3 is a graph showing oil density as a function of water density in accordance with teachings of this disclosure.
  • FIG. 4 is a graph showing water fraction as a function of water density in accordance with teachings of this disclosure.
  • FIG. 5 is a flowchart of an example method that may be executed to implement the example fluid analyzer of FIGS. 1 and/or 2.
  • FIG. 6 is a flowchart of another example method that may be executed to implement the example fluid analyzer of FIGS. 1 and/or 2.
  • FIG. 7 is a processor platform to execute instructions to implement the methods of FIGS. 5 and/or 6 and/or, more generally, the example fluid analyzer of FIGS. 1 and/or 2.
  • the term “coupled” is used to mean “directly coupled together” or “coupled together via one or more elements.”
  • the terms “upstream,” “downstream,” and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the disclosure.
  • any use of “horizontal,” “downwardly inclined,” “vertical,” “top,” “above,” other directional terms, and variations of these terms is made for convenience, but does not mandate any particular orientation of the components.
  • Surface well tests include sampling and analyzing a content of water in a fluid containing oil and water.
  • Known water cut analyzers measure the instantaneous volumetric fraction of water in oil.
  • some known watercut analyzers measure a density of the water-oil mixture and calculate the water fraction based on the density of water and oil at line conditions (e.g., pressure and/or temperature conditions).
  • properties of the fluid can change based on, for example, changes in the composition of the fluid flowing through a conduit over time, stratification of the flow, etc.
  • an operator i.e.
  • a human operator frequently samples the fluid to measure the densities of oil and water and provides the density measurements as inputs to the water cut analyzer.
  • water cut analyzers automatically determine the water fraction once the user-input density measurements are received, the operator’s workload is not reduced due to the efforts to collect and analyze the fluid samples.
  • analysis of the fluid samples to measure oil density and/or water density is typically performed at ambient conditions (e.g., in a lab). The oil and water densities are then re-calculated to account for line conditions that reflect the pressure and temperature experienced during fluid flow. Flowever, estimating oil density at line conditions in view of the changing nature of the fluid composition is difficult and can result in inaccurate characterizations of the fluid properties.
  • the operator is exposed to toxic fluids at high pressures, which can be harmful to the operator’s safety and/or health.
  • Some other known examples for measuring water fraction include infrared absorption water cut meters to measure water-cut related absorption. Such known meters include probes that measure a scattering of light in a fluid and light absorption at multiple wavelengths based on different absorption properties of oil and water.
  • infrared absorption water cut meters are typically calibrated using oil samples in an environment that may not accurately reflect line conditions. Further, optical devices such as infrared absorption water cut meters are sensitive to contamination on the measuring surface(s) of the meters.
  • Some other known examples for measuring a content of water in oil are based on dielectric measurements.
  • a dielectric permittivity of a water-oil mixture depends on a concentration of water in oil. Properties such as capacitance and reflection may be used in connection with the dielectric measurements.
  • Such measurements also involve calibrations performed in a lab based on samples collected by an operator to determine pure oil permittivity values at line conditions.
  • density measurements of the oil-water fluid are generated by a density meter coupled to a conduit through which the fluid flows.
  • water cut measurements for the fluid are generated by a water cut analyzer coupled to the conduit without calibrating for the properties of oil at line conditions. The data generated by the density meter and the water cut analyzer is used by a fluid analyzer in communication with the density meter and the water cut analyzer to measure a concentration of water in the fluid.
  • the example fluid analyzer determines the water-in-oil concentration measurement (also referred to herein as water cut or water fraction) without reliance on manual sampling of the fluid to determine properties of the oil (e.g., density) and without having to recalculate or estimate the oil properties at line conditions based on fluid samples analyzed in ambient environments.
  • the density meter and the water cut meter are coupled to a fluid conduit that is disposed at an oil outlet of a separator.
  • the estimation of the water-in-oil concentration can be used to determine whether the fluid exiting the separator can be disposed of by burning or if the water content of the fluid is too high and, thus, the fluid is not appropriate burning without risk of causing damage to the burner.
  • the oil can be sent to a tank for disposal in other ways than burning.
  • examples disclosed herein provide for an efficient analysis of the water content in the fluid that can be used to manage fluid handling.
  • Examples disclosed herein further improve operator safety by reducing exposure of the operator to toxic fluids that otherwise occurs during manual sampling of the fluid. Further, the reduction in manual sampling reduces a workload of the operator, thereby improving efficiency of the analysis of the fluid and allowing the operator to perform other tasks.
  • FIG. 1 illustrates an example system 100 including a fluid conduit 102 through which a fluid 104 including oil and, in some instances, water flows.
  • the fluid conduit 102 is coupled to an outlet 103 of a separator 105, which outputs the fluid 104 that flows through the fluid conduit 102.
  • the separator 105 is a two- phase separator that separates liquid and gas and the outlet 103 is a liquid outlet of the separator 105.
  • the example fluid conduit 102 can be coupled to a different fluid source than the separator 105.
  • the example fluid conduit 102 includes a density meter 106 coupled thereto.
  • the density meter 106 can be, for instance, a Coriolis flow meter that measures mass flow and density of the fluid 104.
  • the example fluid conduit 102 of FIG. 1 includes a water cut analyzer 108 coupled thereto.
  • the water cut analyzer 108 includes a microwave resonance water cut meter, which provides for improved resistance to the effects of contamination buildup over other known water cut meters. Flowever, other types of density meters and/or water cut analyzers can be used in examples disclosed herein.
  • the example system 100 of FIG. 1 includes a fluid analyzer 110. In the FIG.
  • the fluid analyzer 110 receives fluid density data 109 from the density meter 106 for the fluid 104 flowing through the fluid conduit 102.
  • the fluid density data 109 includes density for the fluid mixture including oil and water.
  • the fluid analyzer 110 of FIG. 1 receives water cut data 111 from the water cut analyzer 108.
  • the water cut data 111 measured by the water cut analyzer 108 represents the water fraction for the fluid 104.
  • the water cut analyzer 108 is not calibrated for the properties of the oil in the fluid 104 at line conditions and, thus, the water cut data 111 generated by the water cut analyzer 108 does not account for the oil density at line conditions.
  • the fluid analyzer 110 of FIG. 1 uses the fluid density data 109 and the water cut data 111 to determine the water-in-oil concentration in the fluid 104 without calibration data for the density of the oil at line conditions.
  • the fluid density data 109 generated by the density meter 106 and the water cut data 111 generated by the water cut analyzer 108 are transmitted to the fluid analyzer 110 via one or more wired or wireless communication protocols.
  • the fluid density data 109 and/or the water cut data 111 can be transmitted to the fluid analyzer 110 substantially continuously as the data is measured by the respective meters, periodically, or aperiodically based on, for instance, user settings.
  • the fluid density data 109 and the water cut data 111 transmitted to the fluid analyzer 110 are stored in a database 112.
  • the database 112 may be located at the fluid analyzer 110 or located elsewhere and in communication with the fluid analyzer 110 as shown in FIG. 1 .
  • the database 112 of FIG. 1 also stores water density data 113, or data indicative of the density of water at line conditions.
  • the water density data 113 is provided to the database 112 via user input(s).
  • the water density data 113 is determined based on an analysis of samples of the water collected from the fluid 104 by an operator (e.g., at the inlet or outlet lines of the separator 105). In some such examples, the water is analyzed at ambient conditions (e.g., a lab) to determine the water density.
  • the fluid analyzer 110 accounts any errors in the water density measurement due to the sampling and analysis outside the fluid conduit 102 from which the water sample is collected.
  • the fluid analyzer 110 of the example of FIG. 1 includes a calculator 114.
  • the calculator 114 analyzes the fluid density data 109, the water cut data 111, and the water density data 113 stored in the database 112 to determine the water-in-oil concentration for the fluid 104.
  • the calculator 114 determines the water-in-oil concentration based on the following equations:
  • Pmix (1 )Poii + Pw (Eq. 1), where p mix is the density of the fluid 104 (which can include a mixture of water and oil), is the water fraction (i.e. , the fraction of water in oil), p oU is the density of oil, and p w is the density of water, and
  • [0033] wca a pou p re f) (Eq. 2), where wca is the uncalibrated watercut measurement from the water cut meter 108, a is a density correction factor, and p ref is a reference density value for oil.
  • the density of the mixture p mix is a function of the water fraction and the oil and water densities p w , p oU .
  • the mixture density p mix e.g., the fluid density data 109
  • the water density p w e.g., the water density data 113
  • the uncalibrated water cut value wca e.g., the water cut data 111
  • the values of a and p ref are reference values provided by, for instance, a manufacturer of the water cut meter 108.
  • Equations 1 and 2 the unknown variables are the density of oil p oU at line conditions and , the water fraction, or the fraction of water in oil. Equations 1 and 2 can be written as:
  • the calculator 114 substitutes the variables p o , p w , and p mix in Equations 4 and 5, above, to obtain the following equations for the water fraction:
  • the new oil density variable p oil is defined as a function of the same variables as the water fraction .
  • the calculator 114 defines a relationship between the oil density variable p oil and the water fraction variable .
  • the oil density variable p oil in Equation 9 can be replaced with the water fraction variable , as shown in Equation 11.
  • the calculator 114 can determine the water fraction without knowing the oil density at line conditions by replacing the oil density variable p oil with the water fraction variable and solving only for the unknown water fraction .
  • the calculator 114 determines the water fraction for the fluid 104 flowing through the fluid conduit 102 based on the following quadratic equation, in which the water fraction is the unknown variable: the solution to Equation 12 is as
  • the calculator 114 can also calculate the oil density p oU using the following equation: [0050] wca p oii — p re f (Eq. 14). a
  • the calculator 114 determines the density of oil for the fluid 104 without manual sampling of the fluid 104 and analysis of the samples at ambient conditions (e.g., in a lab). As demonstrated by Equation 14, the calculator 114 determines the oil density p oa based on the water fraction value determined for the fluid 104.
  • Equations 1-14 the calculator 114 of the example fluid analyzer 110 of FIG. 1 determines the water fraction for the fluid 104 without using calibrated data for the density of the oil in the fluid 104 flowing through the fluid conduit 102 at line conditions. Further, the calculator 114 can determine the oil density p oa for the fluid without relying on the collection of fluid samples. As such, Equations 1-14 can be considered auto-calibration algorithms, in that they provide for determination of water fraction for the fluid 104 without manual sampling and analysis of the fluid.
  • the example fluid analyzer 110 of FIG. 1 includes a water cut evaluator 116.
  • the water cut evaluator 116 identifies properties of the fluid 104 based on the outputs generated by the calculator 114 using one or more of the above equations (e.g., Equations 1-14). For instance, when the value of the mixture density p mix as determined by the calculator 114 is equal to zero, the water fraction is also equal to zero. In such examples, the water cut evaluator 116 detects that the fluid 104 is pure oil or substantially pure oil. In such examples, the water cut evaluator 116 determines that the oil density value calculated by the calculator 114 using Equation 14 represents the density of pure oil.
  • the automatic detection of fluid 104 as including pure oil or substantially pure oil by the water cut evaluator 116 based on the outputs generated by the calculator 114 reduces or eliminates the effects human error or judgment in assessing the composition of the fluid 104 and provides a more accurate assessment of the properties of the fluid 104. Further, in some examples, the calculator 114 determines the water fraction and/or oil density data in substantially real-time as the fluid 104 is flowing through the fluid conduit 102 (e.g., within seconds of the density data 109 and the water cut data 111 being measured by the respective meters 106, 108).
  • the water cut evaluator 116 determines the properties of the fluid 104 based on the water fraction and/or oil density data during flow of the fluid 104 through the fluid conduit 102.
  • examples disclosed herein can improve accuracy in the characterization of the fluid 104 as compared to if the composition of the fluid 104 was analyzed using samples collected at an earlier time.
  • the water fraction value(s) calculated by the calculator 114 serve as a trigger for performing one or more actions with the fluid 104 or refraining from performing one or more actions with the fluid 104.
  • the water cut evaluator 116 analyzes the water fraction value(s) calculated by the calculator 114 based on, for instance, one or more predefined thresholds stored in the database 112. For instance, the water cut evaluator 116 can compare the water fraction value(s) to a predefined threshold with respect to water content levels for burning the fluid 104. If the water cut evaluator 116 determines that the water fraction value(s) exceed a predefined threshold (e.g., above 25%), the fluid 104 may not be suitable for burning without risk of damaging the burner.
  • a predefined threshold e.g., above 25%
  • the water cut evaluator 116 determines that the fluid 104 should be disposed of in another manner (e.g., sent to a tank).
  • the water cut evaluator 116 can analyze the water fraction value(s) in connection with other activities that may involve consideration of the water-in-oil concentration.
  • the example fluid analyzer 110 of FIG. 1 includes a communicator 118.
  • the communicator 118 transmits the value(s) determined by the calculator 114 such as water fraction and oil density to, for example, one or more other processors, one or more display devices, etc., in wired or wireless communication with the fluid analyzer 110.
  • the communicator 118 outputs indicator(s) or alert(s) (e.g., visual alert(s), audio alert(s)) based on the analysis of the water-in-oil concentration by the water cut evaluator 116.
  • the communicator 118 can transmit the value(s) and/or alert(s) for output based on, for instance, user setting(s) received at the fluid analyzer 110.
  • the density meter 106 can include a Coriolis flow meter.
  • the calculator 114 of the example fluid analyzer 110 assumes that the fluid 104 exiting the liquid outlet 103 of the separator 105 is a liquid-liquid mixture of oil and water, in operation, some gas from the separator 105 may enter the fluid conduit 102. The presence of gas in the fluid 104 can result in inaccurate calculations of the water fraction by the calculator 114.
  • a drive gain measurement generated by the Coriolis flow meter can be analyzed to detect the presence of gas in the fluid 104.
  • the density meter 106 can transmit the drive gain values to the fluid analyzer 110.
  • the calculator 114 may execute the auto calibration algorithms (e.g., Equations 1-14) if the drive gain is less than a predefined threshold indicating that gas is not present in the fluid 104 (e.g., a drive gain of less than 30%). The calculator 114 may refrain from executing the auto-calibration algorithms if the drive gain exceeds the threshold.
  • the fluid conduit 102 can be coupled to a liquid outlet of a two-phase separator that separates the fluid 104 into oil and gas.
  • the water density value p w is provided as a user input based on sampling and analysis of water.
  • the fluid conduit is coupled to an oil outlet of a three-phase separator that separates the fluid into gas and two types of liquid, namely, oil and water.
  • a density meter can be coupled to a fluid conduit of the water outlet of the separator to automatically measure the density of water.
  • FIG. 2 illustrates an example system 200 including a first fluid conduit 202 and a second fluid conduit 204.
  • the first fluid conduit 202 is coupled to an oil outlet 203 of a three-phase separator 205.
  • the second fluid conduit 204 is coupled to a water outlet 207 of the three-phase separator 205.
  • a first fluid 206 including oil and, in some examples, at least some amount of water, flows through the first fluid conduit 202.
  • a second fluid 208 flows through the second fluid conduit 204.
  • the second fluid 208 is water.
  • the second fluid 208 is substantially water with at least some amount of oil and/or gas in the fluid flow.
  • the first fluid conduit 202 includes a first density meter 210 (e.g., a Coriolis flow meter) coupled thereto.
  • the first density meter 210 measures mass flow and density of the fluid 206.
  • the first fluid conduit 202 includes a water cut analyzer 212 (e.g., a microwave resonance water cut meter).
  • the first density meter 210 generates fluid density data 209 for the fluid 206 flowing through the first fluid conduit 202 that is transmitted to the fluid analyzer 110.
  • the water cut analyzer 212 generates water cut data 211 for the fluid 206 (i.e.
  • the water cut data 211 generated by the water cut analyzer 212 is transmitted to the fluid analyzer 110.
  • the fluid density data 209 and the water cut data 211 can be transmitted to the fluid analyzer 110 via one or more wired or wireless communication protocols and stored in the database 112.
  • the fluid density data 209 and/or the water cut data 211 can be transmitted to the fluid analyzer 110 substantially continuously as the data is measured, periodically, or aperiodically based on user settings
  • the second fluid conduit 204 includes a second density meter 214 (e.g., a Coriolis flow meter) coupled thereto.
  • the second density meter 214 measures the density of the second fluid 208, (e.g., water or a fluid primarily including water), flowing through the second fluid conduit 204.
  • the second density meter 214 transmits water density data 213 to the fluid analyzer 110 via one or more wired or wireless communication protocols.
  • the water density data 213 can be transmitted to the fluid analyzer 110 substantially continuously as the data is measured, periodically, or aperiodically based on user settings.
  • the water density data 213 can be stored in the database 112 of the fluid analyzer 110.
  • the water density data 213 is automatically generated by the second density meter 214.
  • the calculator 114 of the example fluid analyzer 110 determines the oil density p oU and water fraction for the first fluid 206 flowing through the first fluid conduit 202 based on the fluid density data 209 measured by the first density meter 210, the water density data 213 measured by the second density meter 214, and the uncalibrated water cut data 209 measured by the water cut analyzer 212.
  • the calculator 114 determines the oil density p oU and water cut values based on Equations 1-14 disclosed above in connection with FIG. 1. However, in the example of FIG. 2, the calculator 114 uses the water density data 213 measured by the second density meter 214 of the second fluid conduit 204, or the water line, rather than user-input water density values.
  • the example system 200 of FIG. 2 substantially eliminates the need for fluid sampling to be performed by an operator. Further, in the example system 200 of FIG. 2, the water density data 213 is collected at line conditions rather than being determined at ambient conditions after sampling as in the example of FIG. 1. Thus, the examples of FIGS. 1 and 2 accommodate different means for obtaining water density data, including manual sampling or automatic measurements obtained during flow of the water at line conditions.
  • FIGS. 1 and/or 2 While an example manner of implementing the fluid analyzer 110 is illustrated in FIGS. 1 and/or 2, one or more of the elements, processes and/or devices illustrated in FIGS. 1 and/or 2 may be combined, divided, re-arranged, omitted, eliminated and/or implemented in any other way. Further, the example database 112, the example calculator 114, the example water cut evaluator 116, the example communicator 118, and/or, more generally, the example fluid analyzer 110 of FIGS. 1 and/or 2 may be implemented by hardware, software, firmware and/or any combination of hardware, software and/or firmware.
  • any of the example database 112, the example calculator 114, the example water cut evaluator 116, the example communicator 118, and/or, more generally, the example fluid analyzer 110 could be implemented by one or more analog or digital circuit(s), logic circuits, programmable processor(s), programmable controller(s), graphics processing unit(s) (GPU(s)), digital signal processor(s) (DSP(s)), application specific integrated circuit(s) (ASIC(s)), programmable logic device(s) (PLD(s)) and/or field programmable logic device(s) (FPLD(s)).
  • At least one of the example database 112, the example calculator 114, the example water cut evaluator 116, and/or the example communicator 118 is/are hereby expressly defined to include a non-transitory computer readable storage device or storage disk such as a memory, a digital versatile disk (DVD), a compact disk (CD), a Blu-ray disk, etc. including the software and/or firmware.
  • a non-transitory computer readable storage device or storage disk such as a memory, a digital versatile disk (DVD), a compact disk (CD), a Blu-ray disk, etc. including the software and/or firmware.
  • the example fluid analyzer 110 of FIGS. 1 and/or 2 may include one or more elements, processes and/or devices in addition to, or instead of, those illustrated in FIGS.
  • the phrase “in communication,” including variations thereof, encompasses direct communication and/or indirect communication through one or more intermediary components, and does not require direct physical (e.g., wired) communication and/or constant communication, but rather additionally includes selective communication at periodic intervals, scheduled intervals, aperiodic intervals, and/or one-time events.
  • the water density data 113 is provided as a user input based on sampling of the water of the fluid 104.
  • any errors in the water density measurement p w due to, for instance, the analysis of the water at ambient conditions do not have a significant impact on the determination of oil density and water fraction.
  • FIG. 3 is a graph 300 illustrating oil density p oU versus water fraction as determined by the calculator 114 of the example fluid analyzer 110 of FIG. 1 based on water density inputs.
  • the determination of the oil density remains within 3% accuracy relative to the determination of the oil density using the error-free water density data (line 302) despite the water density input data containing errors.
  • the error in the estimation of oil density p oU is less than 1 %.
  • the sensitivity of Equations 1-14 to errors in the water density decreases with decreasing water fraction, as shown in FIG. 3.
  • FIG. 4 is a graph 400 of water fraction values as determined by the calculator 114 of the example fluid analyzer 110 of FIG. 1 based on water density inputs.
  • the water density values determined at ambient conditions based on fluid sampling do not need to be recalculated to line conditions. Therefore, in examples in which the water density data is provided based on fluid sampling, the efficiency in determining the water density data can be increased as the data can be provided without adjustments to account for line conditions. Rather, the auto-calibration algorithms of Equations 1-14 accommodate discrepancies in the water density data.
  • the water density data 213 is automatically measured by the second density meter 214 of the second fluid conduit 204.
  • the calculator 114 of the example fluid analyzer 110 determines the oil density p oa and the water fraction based on the water density data generated by the second density meter 214 and Equations 1-14.
  • Equations 1-14 have low sensitivity to the water density value(s) and, thus, can tolerate some deviation in the water density measurement from the actual water density value without significantly affecting the accuracy of the water fraction or oil density calculations. As such, in some examples of FIG.
  • the second density meter 214 may periodically measure density of the water flowing through the second fluid conduit 204 and/or may periodically transmit the water density data 213 (e.g., based on user setting(s)), thereby increasing efficiency in measuring and processing the water density data by the second density meter 214 and the fluid analyzer 110. Further, the low sensitivity of Equations 1- 14 to the water density value(s) accommodates any differences in water density between water flowing upstream of the separator 205 and water flowing downstream of the separator 205 due to mixing in the separator 205.
  • FIG. 5 is a flowchart of an example method 500 for determining water-in-oil concentration of a fluid flowing through a fluid conduit without performing a separate calibration for oil properties.
  • the example method 500 can be implemented by the example fluid analyzer 110 of FIGS. 1 and/or 2.
  • the example method 500 of FIG. 5 includes accessing fluid density data generated by a density meter during a flow of fluid including oil through a fluid conduit (block 502).
  • the fluid analyzer 110 of FIGS. 1 and/or 2 accesses the fluid density data 109, 209 generated by the density meter 106, 210 for the fluid 104, 206 flowing through the fluid conduit 102, 202, which can contain a mixture of oil and water.
  • the fluid density data 109, 209 can be stored in the database 112 associated with the fluid analyzer 110.
  • the example method 500 of FIG. 5 includes accessing uncalibrated water cut data generated by a water cut analyzer during flow of the fluid through the fluid conduit (block 504).
  • the fluid analyzer 110 of FIGS. 1 and/or 2 accesses water cut data 111 , 211 generated by the water cut analyzer 108, 212 for the fluid 104, 206 flowing through the fluid conduit 102, 202.
  • the water cut data 111 , 211 generated by the water cut analyzer 108, 212 is not calibrated for the oil properties of the fluid.
  • the water cut data 111 , 211 can be stored in the database 112 associated with the fluid analyzer 110.
  • the example method 500 of FIG. 5 includes accessing water density data (block 506).
  • the water density data 113 is provided to the fluid analyzer 110 (e.g., stored in the database 112) via one or more user inputs.
  • an operator may collect samples of water (e.g., from inlet or outlet lines of the separator 105 of FIG. 1 ) and analyze the samples to determine the density of water.
  • water density data 213 is generated by the density meter 214 coupled to the water flow line 204 of the three-phase separator 205 of FIG. 3.
  • the density meter 214 transmits the water density data 213 to the fluid analyzer 110 via one or more wired or wireless communication protocols.
  • the example method 500 of FIG. 5 includes determining water fraction and oil density value(s) based on the fluid density data, the water density data, and the uncalibrated water cut data (block 508).
  • the fluid analyzer 110 implements the auto-calibration algorithms set forth in Equations 1-14, above, to determine water fraction and oil density p oa values for the fluid 104, 206.
  • the example method 500 continues until there is no further fluid density data, water density data, and/or water cut data to be analyzed (blocks 510, 512).
  • FIG. 6 is a flowchart of an example method 600 for determining whether fluid is acceptable for burning via a burner based on water fraction values (e.g., as determined in the example method 500 of FIG. 5).
  • the example method 600 can be implemented by the example fluid analyzer 110 of FIGS. 1 and/or 2.
  • the example method 600 of FIG. 6 includes accessing water fraction value(s) for a fluid determined using auto-calibration algorithm(s) (block 602).
  • the water cut evaluator 116 of the fluid analyzer 110 of FIGS. 1 and/or 2 can obtain the water fraction value(s) calculated by the calculator 114 using Equations 1-14, above.
  • the example method 600 of FIG. 6 includes comparing the water fraction value(s) to predefined threshold(s) to determine if the water fraction value(s) exceed the threshold(s) (blocks 604, 606).
  • the water cut evaluator 116 compares the water fraction value(s) to predefined (e.g., user-defined) threshold value(s) stored in the database 112.
  • the threshold(s) can define water cut level(s) for which a fluid can be burned by the burner and water cut level(s) for which the fluid should be disposed of otherwise than burning.
  • the example method 600 includes outputting a warning indicating that the fluid may not be safe for burning without a risk of damage to the burner due to the amount of water in the fluid (block 608).
  • the water cut evaluator 116 can instruct the communicator 118 to output an alert (e.g., a visual alert, an audio alert) via an output device (e.g., a display device) to indicate that the fluid is not acceptable for burning.
  • an alert e.g., a visual alert, an audio alert
  • the example method 600 includes outputting an indicator that the fluid is acceptable for burning based on the water cut value(s) (block 610).
  • the water cut evaluator 116 can instruct the communicator 118 to output an indicator (e.g., a visual indicator, an audio indicator) via the output device to indicate that the fluid is acceptable for burning.
  • an indicator e.g., a visual indicator, an audio indicator
  • the example method 600 of FIG. 6 ends when there is no further water fraction value(s) to analyze (blocks 612, 614).
  • FIGS. 5 and 6 are representative of example hardware logic, machine readable instructions, hardware implemented state machines, and/or any combination thereof for implementing the fluid analyzer 110 of FIGS. 1 and/or 2.
  • the machine readable instructions may be an executable program or portion of an executable program for execution by a computer processor such as the processor 110 shown in the example processor platform 700 discussed below in connection with FIG. 7.
  • the program may be embodied in software stored on a non-transitory computer readable storage medium such as a CD-ROM, a floppy disk, a hard drive, a DVD, a Blu-ray disk, or a memory associated with the processor 110, but the entire program and/or parts thereof could alternatively be executed by a device other than the processor 110 and/or embodied in firmware or dedicated hardware.
  • a non-transitory computer readable storage medium such as a CD-ROM, a floppy disk, a hard drive, a DVD, a Blu-ray disk, or a memory associated with the processor 110, but the entire program and/or parts thereof could alternatively be executed by a device other than the processor 110 and/or embodied in firmware or dedicated hardware.
  • a non-transitory computer readable storage medium such as a CD-ROM, a floppy disk, a hard drive, a DVD, a Blu-ray disk, or a memory associated with the processor 110
  • the entire program and/or parts thereof could
  • any or all of the blocks may be implemented by one or more hardware circuits (e.g., discrete and/or integrated analog and/or digital circuitry, an FPGA, an ASIC, a comparator, an operational-amplifier (op-amp), a logic circuit, etc.) structured to perform the corresponding operation without executing software or firmware.
  • hardware circuits e.g., discrete and/or integrated analog and/or digital circuitry, an FPGA, an ASIC, a comparator, an operational-amplifier (op-amp), a logic circuit, etc.
  • FIGS. 5 and 6 may be implemented using executable instructions (e.g., computer and/or machine readable instructions) stored on a non-transitory computer and/or machine readable medium such as a hard disk drive, a flash memory, a read-only memory, a compact disk, a digital versatile disk, a cache, a random-access memory and/or any other storage device or storage disk in which information is stored for any duration (e.g., for extended time periods, permanently, for brief instances, for temporarily buffering, and/or for caching of the information).
  • a non-transitory computer readable medium is expressly defined to include any type of computer readable storage device and/or storage disk and to exclude propagating signals and to exclude transmission media.
  • FIG. 7 is a block diagram of an example processor platform 700 structured to execute instructions to implement the methods of FIGS. 5 and/or 6 to implement the fluid analyzer 110 of FIGS. 1 and/or 2.
  • the processor platform 700 can be, for example, a server, a personal computer, a workstation, a self-learning machine (e.g., a neural network), a mobile device (e.g., a cell phone, a smart phone, a tablet such as an iPadTM), a personal digital assistant (PDA), an Internet appliance, or any other type of computing device.
  • a self-learning machine e.g., a neural network
  • a mobile device e.g., a cell phone, a smart phone, a tablet such as an iPadTM
  • PDA personal digital assistant
  • Internet appliance or any other type of computing device.
  • the processor platform 700 of the illustrated example includes a processor 110.
  • the processor 110 of the illustrated example is hardware.
  • the processor 110 can be implemented by one or more integrated circuits, logic circuits, microprocessors, GPUs, DSPs, or controllers from any desired family or manufacturer.
  • the hardware processor may be a semiconductor based (e.g., silicon based) device.
  • the processor implements the calculator 114, the water cut evaluator 116, and the communicator 118.
  • the processor 110 of the illustrated example includes a local memory 713 (e.g., a cache).
  • the processor 110 of the illustrated example is in communication with a main memory including a volatile memory 714 and a non-volatile memory 716 via a bus 718.
  • the volatile memory 714 may be implemented by Synchronous Dynamic Random Access Memory (SDRAM), Dynamic Random Access Memory (DRAM), RAMBUS® Dynamic Random Access Memory (RDRAM®) and/or any other type of random access memory device.
  • the non-volatile memory 716 may be implemented by flash memory and/or any other desired type of memory device. Access to the main memory 714, 716 is controlled by a memory controller.
  • the processor platform 700 of the illustrated example also includes an interface circuit 720.
  • the interface circuit 720 may be implemented by any type of interface standard, such as an Ethernet interface, a universal serial bus (USB), a Bluetooth® interface, a near field communication (NFC) interface, and/or a PCI express interface.
  • one or more input devices 722 are connected to the interface circuit 720.
  • the input device(s) 722 permit(s) a user to enter data and/or commands into the processor 110.
  • the input device(s) can be implemented by, for example, an audio sensor, a microphone, a camera (still or video), a keyboard, a button, a mouse, a touchscreen, a track-pad, a trackball, isopoint and/or a voice recognition system.
  • One or more output devices 724 are also connected to the interface circuit 720 of the illustrated example.
  • the output devices 724 can be implemented, for example, by display devices (e.g., a light emitting diode (LED), an organic light emitting diode (OLED), a liquid crystal display (LCD), a cathode ray tube display (CRT), an in-place switching (IPS) display, a touchscreen, etc.), a tactile output device, a printer and/or speaker.
  • display devices e.g., a light emitting diode (LED), an organic light emitting diode (OLED), a liquid crystal display (LCD), a cathode ray tube display (CRT), an in-place switching (IPS) display, a touchscreen, etc.
  • the interface circuit 720 of the illustrated example thus, typically includes a graphics driver card, a graphics driver chip and/or a graphics driver processor.
  • the interface circuit 720 of the illustrated example also includes a communication device such as a transmitter, a receiver, a transceiver, a modem, a residential gateway, a wireless access point, and/or a network interface to facilitate exchange of data with external machines (e.g., computing devices of any kind) via a network 726.
  • the communication can be via, for example, an Ethernet connection, a digital subscriber line (DSL) connection, a telephone line connection, a coaxial cable system, a satellite system, a line-of-site wireless system, a cellular telephone system, etc.
  • DSL digital subscriber line
  • the processor platform 700 of the illustrated example also includes one or more mass storage devices 728 for storing software and/or data.
  • mass storage devices 728 include floppy disk drives, hard drive disks, compact disk drives, Blu-ray disk drives, redundant array of independent disks (RAID) systems, and digital versatile disk (DVD) drives.
  • the database 112 may be implemented by the volatile memory 714 and/or the mass storage device(s) 728.
  • Coded instructions 732 of FIG. 7 may be stored in the mass storage device 728, in the volatile memory 714, in the non-volatile memory 716, and/or on a removable non-transitory computer readable storage medium such as a CD or DVD.
  • example methods, apparatus and articles of manufacture have been disclosed that improve efficiency and accuracy in determining water-in-oil concentration for a fluid containing a mixture of water and oil over known water cut analyzers.
  • the water-in-oil concentration is calculated without calibration for the properties of oil (e.g., oil density).
  • examples disclosed herein eliminate the need for manual sampling and analysis of the fluid to generate calibration data that may not accurately represent oil properties at line conditions and/or may not reflect the composition of the fluid flowing through the fluid conduit in view of the changing nature of the fluid.
  • Some examples disclosed herein further eliminate manual sampling of water in the fluid by automatically measuring water density using a density meter coupled to, for instance, a water line of separator.
  • examples disclosed herein tolerate errors or discrepancies in water density data that is determined at ambient conditions based on fluid sampling. Examples disclosed herein provide for improved accuracy in analyzing the water-in-oil concentration for a fluid flowing through a fluid conduit and reduce operator workload by determining the water- in-oil concentration without manual sampling and analysis of the fluid. As a result, examples disclosed herein also improve operator safety by reducing exposure of the operator to toxic fluids.
  • An example apparatus includes a first density meter coupled to a fluid conduit.
  • the first density meter is to generate fluid density data for a fluid flowing through the fluid conduit, the fluid including oil.
  • the apparatus includes a water cut analyzer coupled to the fluid conduit.
  • the water cut analyzer is to generate water cut data for the fluid.
  • the water cut data is uncalibrated for one or more properties of the oil.
  • the example apparatus includes a processor in communication with the first density meter and the water cut analyzer. The processor is to determine a water-in-oil concentration for the fluid based on the fluid density data, the water cut data, and water density data.
  • the processor is to define the water-in-oil concentration as a function of a density of water, a density of the fluid, and a density of the oil.
  • the processor is to further define a relationship between the water-in-oil concentration and the density of oil to determine the water-in-oil concentration as a function of a density of water and a density of the fluid.
  • the processor is to define the relationship between the water-in-oil concentration and the density of oil based on the water cut data and a predefined value of the density of the oil.
  • the processor is to compare the water-in-oil concentration to a water cut threshold and generate an alert if the water-in-oil concentration exceeds the water cut threshold, the water cut threshold based on a water content for burning the fluid.
  • the fluid conduit is a first fluid conduit of a separator and further including a second density meter coupled to a second fluid conduit of the separator.
  • the second density meter is to generate the water density data.
  • the water density data is provided to the processor based on sampling of water in the fluid.
  • the fluid conduit is coupled to a fluid outlet of a two- phase separator.
  • the processor is to further determine a density of oil based on the water cut data and the water-in-oil concentration.
  • Another example apparatus includes means for measuring density of a fluid including oil flowing through a fluid conduit.
  • the means for measuring density is to generate density data.
  • the example apparatus includes means for measuring a water cut of the fluid.
  • the means for measuring the water cut is to generate water cut data.
  • the example apparatus includes means for determining a water-in-oil concentration of the fluid based on the density data and the water cut data.
  • the means for determining is to determine a density of the oil in the fluid based on the water-in-oil concentration.
  • the threshold includes a water cut level for burning the fluid, the indicator to include an alert if the water-in-oil concentration exceeds the threshold.
  • the calculator is to determine the density of the oil based on the water-in-oil concentration.
  • the water cut evaluator is to determine a composition of the fluid based on the water-in-oil concentration.
  • the calculator is to access the water density data from a density meter coupled to a water conduit of the separator.
  • the fluid density data represents a density of the fluid including water and oil.
  • An example method includes measuring a density of a fluid including oil flowing through a fluid conduit to generate density data; measuring a water cut of the fluid to generate water cut data; determining a water-in-oil concentration of the fluid based on the density data and the water cut data; and determining a density of the oil in the fluid based on the water-in-oil concentration. Some or all of the measuring and determining methods may be done by executing an instruction with at least one processor.
  • the method may include measuring, by executing an instruction with at least one processor, a density of a fluid including oil flowing through a fluid conduit to generate density data; measuring, by executing an instruction with the processor, a water cut of the fluid to generate water cut data; determining, by executing an instruction with the at least one processor, a water-in-oil concentration of the fluid based on the density data and the water cut data; and determining, by executing an instruction with the at least processor, a density of the oil in the fluid based on the water-in-oil concentration.
  • the method further includes performing a comparison of the water-in-oil concentration to a threshold, wherein the threshold includes a water cut level for burning the fluid, and outputting an indicator of water content in the fluid based on the comparison, the indicator to include an alert if the water-in-oil concentration exceeds the threshold.
  • the method further includes determining the water-in-oil concentration based on water density data.
  • the water cut data is uncalibrated for a density of the oil.
  • the fluid conduit is a first fluid conduit and the method further includes measuring density of water flowing through a second fluid conduit different from the first fluid conduit.
  • the method further includes determining a composition of the fluid based on the water-in-oil concentration.
  • Another example apparatus includes means for measuring density of a fluid including oil flowing through a fluid conduit.
  • the means for measuring density is to generate density data.
  • the example apparatus includes means for measuring a water cut of the fluid.
  • the means for measuring the water cut is to generate water cut data.
  • the example apparatus includes means for determining a water-in-oil concentration of the fluid based on the density data and the water cut data.
  • the means for determining is to determine a density of the oil in the fluid based on the water-in-oil concentration.
  • the means for measuring density is a Coriolis density meter.
  • the means for determining is to further determine the water- in-oil concentration based on water density data.
  • the water cut data is uncalibrated for a density of the oil.
  • the fluid conduit is a first fluid conduit and the apparatus further includes means for measuring density of water.
  • the means for measuring density of water is coupled a second fluid conduit different from the first fluid conduit.
  • the means for measuring density and the means for measuring the water cut are coupled to a liquid outlet of a separator.
  • A, B, and/or C refers to any combination or subset of A, B, C such as (1 ) A alone, (2) B alone, (3) C alone, (4) A with B, (5) A with C, (6) B with C, and (7) A with B and with C.
  • the phrase “at least one of A and B” is intended to refer to implementations including any of (1 ) at least one A, (2) at least one B, and (3) at least one A and at least one B.
  • the phrase “at least one of A or B” is intended to refer to implementations including any of (1) at least one A, (2) at least one B, and (3) at least one A and at least one B.
  • the phrase “at least one of A and B” is intended to refer to implementations including any of (1 ) at least one A, (2) at least one B, and (3) at least one A and at least one B.
  • the phrase “at least one of A or B” is intended to refer to implementations including any of (1) at least one A, (2) at least one B, and (3) at least one A and at least one B.

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Abstract

L'invention concerne un appareil de surveillance d'eau dans l'huile donné à titre d'exemple et des procédés associés. Un appareil donné à titre d'exemple inclut un premier densimètre couplé à un conduit de fluide. Le premier densimètre est destiné à générer des données de densité de fluide pour un fluide s'écoulant dans le conduit de fluide, le fluide incluant de l'huile. L'appareil comprend un analyseur de teneur en eau couplé au conduit de fluide. L'analyseur de teneur en eau est destiné à générer des données de teneur en eau pour le fluide. Les données de teneur en eau sont non étalonnées pour une ou plusieurs propriétés de l'huile. L'appareil donné à titre d'exemple inclut un processeur en communication avec le premier densimètre et l'analyseur de teneur en eau. Le processeur est destiné à déterminer une concentration d'eau dans l'huile pour le fluide sur la base des données de densité du fluide, des données de teneur en eau, et des données de densité de l'eau.
PCT/US2019/053788 2019-09-30 2019-09-30 Appareil de surveillance d'eau dans l'huile et procédés associés WO2021066797A1 (fr)

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Cited By (1)

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WO2019132878A1 (fr) * 2017-12-27 2019-07-04 Halliburton Energy Services, Inc. Détection d'une fraction d'un composant dans un fluide

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CN113640176B (zh) * 2021-07-30 2024-02-20 深圳市中金岭南有色金属股份有限公司凡口铅锌矿 石灰乳比重测量方法、装置、系统及计算机可读存储介质

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