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WO2020222772A1 - Procédé de mesure et de prédiction de propriétés rhéologiques de fond - Google Patents

Procédé de mesure et de prédiction de propriétés rhéologiques de fond Download PDF

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Publication number
WO2020222772A1
WO2020222772A1 PCT/US2019/029747 US2019029747W WO2020222772A1 WO 2020222772 A1 WO2020222772 A1 WO 2020222772A1 US 2019029747 W US2019029747 W US 2019029747W WO 2020222772 A1 WO2020222772 A1 WO 2020222772A1
Authority
WO
WIPO (PCT)
Prior art keywords
dial reading
viscosity
pressure
drilling fluid
viscosity dial
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/US2019/029747
Other languages
English (en)
Inventor
Dale E. Jamison
Sandeep Kulkarni
Lalit N. MAHAJAN
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Halliburton Energy Services Inc
Original Assignee
Halliburton Energy Services Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Priority to GB2113777.3A priority Critical patent/GB2596479B/en
Priority to BR112021018655-7A priority patent/BR112021018655B1/pt
Priority to US16/645,518 priority patent/US20210238938A1/en
Priority to PCT/US2019/029747 priority patent/WO2020222772A1/fr
Priority to AU2019443517A priority patent/AU2019443517B2/en
Publication of WO2020222772A1 publication Critical patent/WO2020222772A1/fr
Priority to NO20211157A priority patent/NO20211157A1/no
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure

Definitions

  • drilling fluid As a borehole is drilled into a production formation, drilling fluid is pumped down a borehole through a drill string to power the drill bit at a cutting end of the drill string. The drilling fluid then exits the drill bit to convey drill cuttings up and out of the borehole.
  • the pressure and chemical composition of the drilling fluid can interact with the formation. For example, over-pressurizing the drilling fluid can fracture the formation, and under-pressurizing can allow cave-in, among other potential interactions. Therefore, it is helpful to know the pressure at points along the length/depth of the borehole.
  • Models may be used to predict the pressure in the borehole, but the models rely on a broad range of characteristics of the drilling fluid, such as rheological properties at a variety of temperatures and pressures, to achieve accurate results. Measuring all the characteristics at the various temperatures and pressures is impractical in real-time since the characteristics are changing constantly as additional drill cuttings are produced and mixed in to the drilling fluid.
  • FIG. 1 is a schematic and cross-sectional diagram of an embodiment of a drilling system using a well modeling system
  • FIG. 2 is a list of possible temperatures and pressures that a well modeling system may select from to test and record the viscosity dial readings;
  • FIG. 3 is a list of data sets that were recorded by a well modeling system; and [0006] FIG. 4 illustrates a shear stress vs. shear rate function for viscosity dial readings that is generated for the full range of pressures and temperatures.
  • FIG. 1 is a schematic and cross-sectional diagram of an embodiment of a drilling system 100 using a well modeling system 138.
  • the drilling system 100 is for drilling a borehole 106 using a drilling fluid, and includes a drilling rig 102 located at the earth’s surface 104 of the borehole 106.
  • the drilling rig 102 provides support for a drill string 108.
  • the drill string 108 conveys the drilling fluid from the surface 104 to a bottom-hole assembly 110 through a drill pipe 112.
  • the bottom-hole assembly 110 has a drill collar 114, a downhole tool 116, and a drill bit 118.
  • Other systems 100 may include additional or alternative components in the bottom-hole assembly 110.
  • the drilling system 100 pumps drilling fluid through the drill pipe 112 to power the downhole tool 116 and the drill bit 118.
  • the drill collars 114 may be used to add weight to the drill bit 118 and stiffen the bottom-hole assembly 110.
  • the downhole tool 116 may comprise any of a number of different types of tools including measurement-while-drilling (MWD) tools, logging-while-drilling (LWD) tools, pressure sensors, temperature sensors, and others.
  • the bottom-hole assembly 110 creates and logs the borehole 106 by penetrating the surface 104 to access subsurface formations 122.
  • a mud pump 124 pumps the drilling fluid (sometimes known as“drilling mud”) from a mud pit 126 through a hose 128 into the drill pipe 112 and down to the drill bit 118.
  • the drilling fluid flows out from the drill bit 118 and returns to the surface 104 through an annular area 130 between the drill pipe 112 and a side 120 of the borehole 106.
  • the mud pump 124 can be controlled to influence the speed and effectiveness of the drill bit 118 pumping the drilling fluid fast enough to remove the cuttings that are drilled, cool the drill bit 118, and lubricate the drill string 112. Faster pumping increases the effectiveness of transporting the cuttings, but the mud pump 124 will not pump as efficiently.
  • the drill bit 118 will drill faster with a higher pressure from the mud pump 124.
  • the benefits of higher pressure can reach a limit, however, because the drilling fluid, among other things, exerts a pressure against the side 120 of the borehole 106. If the mud pump 124 pressurizes the drilling fluid too much, then the pressure against the side 120 can cause drilling fluid to penetrate into the subsurface formations 122. Furthermore, the drilling fluid can fracture or break down the side 120 and lose fluid to the formation. Too little pressure can also be a problem in the borehole 106, since fluid and gases from the formations 122 can come into the borehole 106 and expand to the surface 104. In summary, drilling with a pressure that is too high or too low can damage the subsurface formation 122, or otherwise decrease the fluid flow from the subsurface formation 122. Thus, it is useful to know the pressure at locations within the borehole 106.
  • the pressure of drilling fluid is easier to model when the fluid is stationary, since the density of the fluid is so highly determinative under those conditions.
  • the drilling fluid is in constant motion.
  • a well modeling system can determine the downhole pressures if values for rheological properties of the drilling fluid are accurately known and included in the models.
  • Rheological properties for the drilling fluid can be measured at the surface, but these rheological properties change as the drilling fluid cycles through the borehole 106, the mud pit 126, the hose 128, and the drill pipe 112, etc.
  • Drill cuttings that are not filtered out of the drilling fluid can change the chemical makeup and rheological properties of the drilling fluid.
  • the formations 122 may include chemicals that dissolve into the drilling fluid and further change the makeup of the drilling fluid and how additional interactions with the formation 122 will influence the side 120. It is thus important to consistently update the rheological properties of the drilling fluid throughout the drilling process.
  • the system 100 includes a well modeling system 138.
  • the well modeling system 138 receives information from a rheometer 142 that collects samples of the drilling fluid and measures a viscosity dial reading for each sample. The dial readings may be recorded at various shear rates and/or revolutions per minute, for example 2, 3, 4, 5, 6, or more different shear rates.
  • the well modeling system 138 may have a processor and a memory for storing data and running instructions.
  • the rheometer 142 can be installed, as illustrated, in line with the hose 128. In other embodiments, the rheometer 142 may be located remotely from the drilling rig 102, and samples may be conveyed to this remote location periodically.
  • the rheometer 142 may include, for example, a rotating cylinder that imparts a rotational force on the drilling fluid and measures that force with a torsional bob. Other geometries and measurement techniques may be used to measure the viscosity dial reading for each sample. In the test of each sample, a temperature and pressure are selected (e.g., randomly, progressively) and the rheometer 142 monitors and keeps these selected parameters constant for the sample as a number of shear rates (e.g., the various rotational speeds of the rheometer 142) are tested. The viscosity dial readings for each shear rate are stored by the well modeling system 138, for example, in a computer memory for storing the viscosity dial readings.
  • a goal of the modeling is to be able to accurately model a complete picture of the pressure losses in the drilling fluid downhole.
  • This complete picture is known as the equivalent circulating density (ECD) and can be dependent on the movement of the drilling fluid within the borehole. That is, if the drilling fluid were still, the pressure could be modeled and/or calculated more simply using the density of the fluid. Since the drilling fluid constantly flows during the drilling process, however, the rheological properties must be accounted for in the model.
  • ECD equivalent circulating density
  • the system 100 Rather than taking real time measurements for all temperatures and pressures that may be present in a borehole of a drilling operation, the system 100 periodically takes shear stress dial readings at a combination of temperature and pressure.
  • the combination is based on selection criteria that has a high likelihood of representing a broad range of temperatures and pressures over the course of several measurement periods. For example, the combination may be randomly selected, or may be selected by systematically measuring from a low temperature/pressure, or vice versa.
  • the shear stress dial readings are then ranked according to the relevance of each data set. For example, the shear stress dial readings may be ranked based on how recently they were taken.
  • the system or method then scales a generalized rheology function of temperature and pressure with the time modified weighting. The scaled rheology function is used to model hydraulics for the borehole.
  • a new sample is collected and the rheometer 142 selects a new temperature and pressure to test the shear rates.
  • the well modeling system may select the temperature and pressure randomly from a list and/or range of possible temperatures and pressures (see FIG. 2 and description below).
  • the list and/or range of possible temperatures and pressures may be adjusted by the well modeling system 138 as the borehole 106 changes. For example, as the borehole 106 gets deeper the possible maximum pressures may get higher. Therefore, the maximum pressure in the list and/or range would increase.
  • the list and/or range may be customized to each well based on geological characteristics that are already known about the formations 122. That is, for locations known to have particularly hot formations 122, a range for the temperatures of the borehole being drilled there will include a higher maximum temperature than a range given for a borehole having cooler formations 122.
  • the well modeling system 138 uses a model (e.g., linear, non-Newtonian, Bingham, power law, Herschel- Bulkley) to scale a generalized rheology response to the range of pressures and temperatures that may be experienced within the borehole.
  • the model may calculate rheological properties for the whole range of pressures and temperatures based on readings from just one combination of pressure and temperature.
  • the model may be improved, however, by additional readings at other temperatures and pressures. For example, a first viscosity dial reading may be measured at the low end of the pressure range, and the low end of the temperature range.
  • This first viscosity dial reading may be used to model the pressure and temperature at the high end of the pressure and temperature ranges.
  • the model may be improved by taking an additional viscosity dial reading, and combining the generalized rheology response from both.
  • the resulting response may be used to calculate the rheological parameters for the fluid at conditions experienced at particular locations downhole.
  • This combination of generalized rheology responses may be done for any number of viscosity dial readings (e.g., 3, 4, 5, 6, 7, 8, or more viscosity dial readings).
  • the system 100 can change operational parameters to optimize drilling and keep the downhole pressure within a range.
  • the system 100 manages the rate of the mud pump 124, the rotation of the drill string 112, and the mud density and viscosity. Changing the density and viscosity effects the relationship between movement of the fluid, and the pressure that it exerts on the formation.
  • the system 100 may include functionality to add a viscosifier if the drilling fluid is not viscous enough. If the drilling fluid is too viscous, a thinner may be added. The system 100 may add barite or other materials if the drilling fluid density is too low.
  • the system 100 may dilute the fluid with a base fluid or centrifuge out some of the weighting material if the density is too high. These operational changes maintain the pressure, ECD, pore pressure within a production formation, and fracture gradient while maximizing the rate of penetration.
  • FIG. 2 is a list 200 of possible temperatures 202 and pressures 204 that a well modeling system (e.g., the well modeling system 138 of FIG. 1) may use to test and record the viscosity dial readings.
  • the range of temperatures 202 and the range of pressures 204 may be customized to a borehole, and may change during the drilling operation as explained above.
  • the range of temperatures 202 may be between -18 degrees Celsius (0 degrees Fahrenheit) to 205 degrees Celsius (400 degrees Fahrenheit).
  • the max temperature may be 100 degrees Celsius (212 degrees Fahrenheit), increasing as the borehole is drilled deeper.
  • the specific values within the range may differ by a set amount, or may be any values between the low end of the high end of the range.
  • the range of pressures may include 0 Pascal (0 psi) to 1.7 x 10 L 8 Pascal (25,000 psi), or smaller ranges.
  • the well modeling system 138 may select the temperature 202 and pressure 204 independently, or the well modeling system may select the temperature 202 and the pressure 204 from sets 206 of temperature/pressure that are pre-determined combinations of temperature and pressure. In some instances, the well modeling system selects one temperature 202 and pressure 204, records the viscosity dial readings from a rheometer, and then randomly selects a new temperature 202 and pressure 204 after a given time period. The time period may range from a half an hour to several hours. Periodicity may depend on several factors including rate of expected change in the drilling fluid, speed of drilling, drilling equipment, weather, or other considerations.
  • the well modeling system may select one temperature 202 to be used for several viscosity dial readings in a row, randomly selecting a new pressure 204 after each given time period. In still further instances, the well modeling system may select one pressure 204 for several viscosity dial readings in a row, randomly selecting a new temperature 202 after each given time period. The well modeling system may also systematically select the temperature 202 and pressure 204. For example, each new temperature 202 and/or pressure 204 is higher than the previous temperature 202 or pressure 204. After several iterations, a broad range of temperatures 202 and pressures 204 will have been selected, and the viscosity dial readings recorded at various shear rates and/or revolutions per minute.
  • FIG. 3 is a list 300 of example data sets 302-316 that were recorded by a well modeling system (e.g., the well modeling system 138 of FIG. 1).
  • the list 300 includes the eight most recent sets 302-316 ordered according to when the set was recorded.
  • Each set 302-316 in the list 300 includes viscosity dial readings 318 taken at six different shear rates (e.g., six different rotation speeds of the rheometer).
  • the six shear rates will be common for each of the sets 302-316.
  • the six shear rates will include: 1022, 511, 341, 170, 10.2, and 5.1 reciprocal seconds (1/s).
  • more shear rates may be tested, or fewer shear rates may be tested.
  • the shear rates may include other values as well for testing the drilling fluid.
  • Each of the sets 302-316 is associated with a pressure value 322 and a temperature value 324. These values 322, 324 are selected by the well modeling system as described above. The viscosity dial readings 318 at one pressure value 322 and temperature value 324 may be used to create a generalized rheology response for all temperatures and all pressures using known techniques such as Herschel-Bulkley models.
  • each set 302-316 of viscosity dial readings 318 also includes a weighting value 326.
  • the weighting value 326 for the latest set 302 illustrated in FIG. 3, for example, is 0.50.
  • the well modeling system uses this weighting value 320 in a modeling function to scale a generalized rheology response to pressure and temperature.
  • the weighting value 326 is updated each time a new viscosity dial reading 318 is taken.
  • the older viscosity dial readings 318 are weighted less, and the latest viscosity dial reading is given the highest weighting value 326.
  • the scaling of the weighting values 326 may be based a variety of scaling functions, depending on the expected change in the drilling fluid. For example, the weighting values 326 may decrease according to a linear, parabolic, or exponential weighting function. Or, the eight most recent sets 302-316 may be given custom weighting values 326 based on the knowledge of an operator.
  • the generalized rheology response created from the latest set 302 is scaled according to the weighting value 326. That scaled rheology response from the latest set 302 is then combined with the rheology response from the second latest set 304 as it has been scaled by the weighting value 326 (i.e., 0.32). This scaling and combination is completed for each of the sets 302-316 until a shear stress vs. shear rate function for viscosity dial readings is generated for the full range of temperatures and pressures.
  • FIG. 4 illustrates a shear stress vs. shear rate function 400 for viscosity dial readings 402 that is generated for the full range of pressures 404 and temperatures 406.
  • the model 400 it is possible that only a few, or none of the values match the exact values that were measured by the well modeling system. Rather, the model 400 is a combination of all the sets (e.g., the sets 302-316 illustrated in FIG. 3), with the latest set (e.g., the latest set 302 from FIG. 3) having the most highly scaled values. This combination thus increases the accuracy of the model despite changing rheology in the drilling fluid, and, the inherent issues of modeling temperatures and pressures with only one reference point.
  • a substantially real-time ECD can be determined for the length of the borehole. This information may be combined with information about formation downhole to control operating parameters of the drilling operation. For example, if the model 400 shows that a viscosity for conditions at a certain depth is increasing, and that depth has a formation with a low pressure threshold, then the drilling system may lower pressurization from the mud pump to protect the formation. If the viscosity decreases, then the pressure may be re-adjusted back up. Furthermore, the drilling system may also change the rotation speed of the drill string, and/or add additives to the drilling fluid to change the mud density or viscosity. The model 400 may also be updated whenever a new viscosity dial reading is measured.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Geophysics (AREA)
  • Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
  • Earth Drilling (AREA)
  • Measuring Fluid Pressure (AREA)
  • Drilling And Boring (AREA)

Abstract

Des systèmes et des procédés selon les modes de réalisation de la présente invention comprennent le prélèvement d'un premier échantillon d'un fluide de forage à un premier temps, la mesure, avec un rhéomètre, d'une première lecture par cadran de viscosité du premier échantillon, le prélèvement d'un deuxième échantillon d'un fluide de forage à un deuxième temps, la mesure, avec le rhéomètre, d'une deuxième lecture par cadran de viscosité du deuxième échantillon, la pondération de la première lecture par cadran et de la deuxième lecture par cadran sur la base d'un temps écoulé depuis le premier temps et d'un temps écoulé depuis le deuxième temps, et le calcul d'une fonction de la contrainte de cisaillement en fonction du taux de cisaillement du fluide de forage pour une pluralité de températures et une pluralité de pressions sur la base de la première lecture par cadran de viscosité pondérée et de la deuxième lecture par cadran de viscosité pondérée.
PCT/US2019/029747 2019-04-29 2019-04-29 Procédé de mesure et de prédiction de propriétés rhéologiques de fond Ceased WO2020222772A1 (fr)

Priority Applications (6)

Application Number Priority Date Filing Date Title
GB2113777.3A GB2596479B (en) 2019-04-29 2019-04-29 Method to measure and predict downhole rheological properties
BR112021018655-7A BR112021018655B1 (pt) 2019-04-29 Método para perfurar um poço e sistema para perfurar um poço usando um fluido de perfuração
US16/645,518 US20210238938A1 (en) 2019-04-29 2019-04-29 Method to measure and predict downhole rheological properties
PCT/US2019/029747 WO2020222772A1 (fr) 2019-04-29 2019-04-29 Procédé de mesure et de prédiction de propriétés rhéologiques de fond
AU2019443517A AU2019443517B2 (en) 2019-04-29 2019-04-29 Method to measure and predict downhole rheological properties
NO20211157A NO20211157A1 (en) 2019-04-29 2021-09-27 Method to measure and predict downhole rheological properties

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2019/029747 WO2020222772A1 (fr) 2019-04-29 2019-04-29 Procédé de mesure et de prédiction de propriétés rhéologiques de fond

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WO2020222772A1 true WO2020222772A1 (fr) 2020-11-05

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PCT/US2019/029747 Ceased WO2020222772A1 (fr) 2019-04-29 2019-04-29 Procédé de mesure et de prédiction de propriétés rhéologiques de fond

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US (1) US20210238938A1 (fr)
AU (1) AU2019443517B2 (fr)
GB (1) GB2596479B (fr)
NO (1) NO20211157A1 (fr)
WO (1) WO2020222772A1 (fr)

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US12399097B2 (en) * 2019-09-09 2025-08-26 The Texas A&M University System Application of marsh funnel through use of trained algorithm
US12044116B1 (en) * 2023-07-14 2024-07-23 Halliburton Energy Services, Inc. Geomechanical data interpretation and recommendation system using large language models
US11966845B1 (en) 2023-07-17 2024-04-23 Halliburton Energy Services, Inc. Service document generation using large language models
US12486727B1 (en) 2024-06-03 2025-12-02 Halliburton Energy Services, Inc. Drilling event detection

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US20130146357A1 (en) * 2010-08-26 2013-06-13 Halliburton Energy Services, Inc System and Method for Managed Pressure Drilling
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Publication number Priority date Publication date Assignee Title
US20090282907A1 (en) * 2008-05-16 2009-11-19 Schlumberger Technology Corporation Methods and apparatus to control a formation testing operation based on a mudcake leakage
US20130146357A1 (en) * 2010-08-26 2013-06-13 Halliburton Energy Services, Inc System and Method for Managed Pressure Drilling
US20160282503A1 (en) * 2013-12-27 2016-09-29 Halliburton Energy Services, Inc. Multifrequency processing to determine formation properties
US20180195354A1 (en) * 2015-07-13 2018-07-12 Halliburton Energy Services, Inc. Real-time frequency loop shaping for drilling mud viscosity and density measurements
WO2018076006A1 (fr) * 2016-10-21 2018-04-26 Schlumberger Technology Corporation Procédé et système de détermination de profondeurs de déblais de forage

Also Published As

Publication number Publication date
GB2596479A (en) 2021-12-29
NO20211157A1 (en) 2021-09-27
GB2596479B (en) 2022-10-26
AU2019443517B2 (en) 2025-02-27
GB202113777D0 (en) 2021-11-10
US20210238938A1 (en) 2021-08-05
AU2019443517A1 (en) 2021-09-23
BR112021018655A2 (pt) 2021-11-23

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