EP3283727B1 - Système et procédé de forage par pression interstitielle - Google Patents

Système et procédé de forage par pression interstitielle Download PDF

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Publication number
EP3283727B1
EP3283727B1 EP15805067.4A EP15805067A EP3283727B1 EP 3283727 B1 EP3283727 B1 EP 3283727B1 EP 15805067 A EP15805067 A EP 15805067A EP 3283727 B1 EP3283727 B1 EP 3283727B1
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EP
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Prior art keywords
drilling
pore pressure
value
drill bit
calculating
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German (de)
English (en)
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EP3283727A1 (fr
Inventor
Reza MAJIDI
Martin ALBERTIN
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BP Corp North America Inc
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BP Corp North America Inc
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    • 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
    • E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
    • E21B44/02—Automatic control of the tool feed
    • E21B44/04—Automatic control of the tool feed in response to the torque of the drive ; Measuring drilling torque
    • 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
    • E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
    • E21B44/02—Automatic control of the tool feed
    • E21B44/06—Automatic control of the tool feed in response to the flow or pressure of the motive fluid of the drive
    • 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
    • E21B45/00—Measuring the drilling time or rate of penetration
    • 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
    • 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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/003—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by analysing drilling variables or conditions

Definitions

  • Some subterranean formations are porous, containing fluid such as water, gas, or crude oil within the pores.
  • the fluid within the formations is at a certain pressure termed the pore pressure.
  • the pore pressure supports part of the weight of the overburden (weight of the overlying rock matrix and pore fluid), while the other part is supported by the grains of the rock.
  • formation pore pressure, formation pressure and fluid pressure are synonymous, referring to pore pressure.
  • Pore pressure may be measured during the drilling operations. For example, pore pressure may be directly measured by sampling fluid from the formation using a downhole tool in contact with the borehole wall. Pore pressure measurements can be applied while drilling in the context of well control, in implementation of completion processes, and/or in reservoir development.
  • US 2014/0151121 discloses methods and systems for drilling to a target location which include a control system that receives an input comprising a planned drilling path to a target location and determines a projected location of a bottom hole assembly of a drilling system. The projected location of the bottom hole assembly is compared to the planned drilling path to determine a deviation amount. A modified drilling path is created to the target location as selected based on the amount of deviation from the planned drilling path, and drilling rig control signals that steer the bottom hole assembly of the drilling system to the target location along the modified drilling path are generated to intersect the planned drilling path if the amount of deviation from the planned path exceeds a first threshold amount of deviation.
  • the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to ".
  • the term “couple” is not meant to limit the interaction between elements to direct interaction between the elements and may also include indirect interaction between the elements described.
  • the term “software” includes any executable code capable of running on a processor, regardless of the media used to store the software. Thus, code stored in memory (e.g., non-volatile memory), and sometimes referred to as “embedded firmware,” is included within the definition of software.
  • the recitation “based on” is intended to mean “based at least in part on.” Therefore, if X is based on Y , X may be based on Y and any number of additional factors.
  • Embodiments of the present disclosure include an alternative to the d-exponent based pore pressure estimation methods. At least some embodiments of the pore pressure determination techniques disclosed herein exclude d-exponent computation.
  • the pore pressure measurement techniques disclosed herein calculate pore pressure from drilling mechanical specific energy (MSE) and drilling efficiency trends using a combination of downhole drilling mechanics parameters and subsurface rock and stress data.
  • Embodiments can compute formation pore pressure at the bit in real-time while drilling, and accordingly, can provide an advantage over conventional log-based methods.
  • embodiments apply drilling parameters measured at the bit to provide important information that logging while drilling (LWD) measurements taken behind the bit (further up the bottom hole assembly (BHA) where LWD resistivity and sonic measurements are commonly taken) cannot provide.
  • LWD logging while drilling
  • BHA bottom hole assembly
  • the pore pressure determination techniques disclosed herein provide pore pressure values much earlier than conventional methods because, using the techniques disclosed herein, the pressure values are provided for the formation material at the bit rather than at a tool some distance uphole of the bit.
  • drilling decisions can be made, and appropriate drilling control applied, much earlier (e.g., 1-1.5 hours or more earlier) than when pressure measurement techniques based on tools uphole of the bit are applied.
  • embodiments of the pore pressure determination method disclosed herein can reduce unnecessary drilling and more accurately identify drilling targets.
  • Figure 1 shows a schematic diagram of a system for drilling a borehole that calculates and applies pore pressure of the formation being drilled based on measurements made at the bit in accordance with principles disclosed herein.
  • the drilling system 100 includes a derrick 104 supported by a drilling platform 102.
  • the derrick 104 includes a floor 103 and a traveling block 106 for raising and lowering a drill string 108.
  • the derrick supports a rotary table 112 that is rotated by a prime mover such as an electric motor controlled by a motor controller.
  • a kelly 110 supports the drill string 108 as it is lowered through the rotary table 112.
  • the drill string 108 extends downward through the rotary table 112, and is made up of various components, including drill pipe 118 and components of the bottom hole assembly (BHA) 142 (e.g., bit 114, mud motor, drill collar, tools, etc.).
  • BHA bottom hole assembly
  • the drill bit 114 is attached to the lower end of the drill string 108.
  • the drill bit 114 disintegrates the subsurface formations 126 when it is rotated with weight-on-bit to drill the borehole 116.
  • the weight-on-bit which impacts the rate of penetration of the bit 114 through the formations 126, is controlled by a drawworks 136.
  • a top drive may be used to rotate the drill string 108 rather than rotation by the rotary table 112 and the kelly 110.
  • a downhole motor (mud motor) is disposed in the drilling string 108 to rotate the drill bit 114 in lieu of or in addition to rotating the drill string 108 from the surface.
  • the mud motor rotates the drill bit 114 when drilling fluid passes through the mud motor under pressure.
  • the rate of penetration (ROP) of the drill bit 114 into the borehole 116 for a given formation is dependent on weight-on-bit, drill bit rotational speed, and other factors.
  • a suitable drilling fluid 138 from a mud tank 124 is circulated under pressure through the drill string 108 by a mud pump 120.
  • the drilling fluid 138 passes from the mud pump 120 into the drill string 108 via fluid line 122 and the kelly 110.
  • the drilling fluid 138 is discharged at the borehole bottom through nozzles in the drill bit 114.
  • the drilling fluid 138 circulates to the surface through the annular space 140 between the drill string 108 and the sidewall of borehole 116, and returns to the mud tank 124 via a solids control system (not shown) and a return line 142.
  • the drilling fluid 138 transports cuttings from the borehole 116 into the reservoir 124 and aids in maintaining borehole integrity.
  • the solids control system separates the cuttings from the drilling fluid 138, and may include shale shakers, centrifuges, and automated chemical additive systems.
  • the density of the drilling fluid 138 may be adjusted based on the pore pressure of the formations 126.
  • a sensor disposed in the fluid line 122 measures and provides information about the drilling fluid flow rate and pressure.
  • a surface torque sensor and a rotational speed sensor associated with the drill string 108 measure and provide information about the torque applied to the drill string 108 and the rotational speed of the drill string 108, respectively.
  • a sensor associated with traveling block 106 may be used to measure and provide the hook load of the drill string 108.
  • Additional sensors are associated with the motor drive system to monitor proper drive system operation. These include, but are not limited to, sensors for detecting such parameters as motor speed (RPM), winding voltage, winding resistance, motor current, and motor temperature. Other sensors are used to indicate operation and control of the various solids control equipment.
  • the BHA 142 may also include a measurement-while-drilling and/or a logging-while-drilling assembly containing sensors for measuring drilling dynamics, drilling direction, formation parameters, downhole conditions, etc. Outputs of the sensors may be transmitted to the surface using any suitable downhole telemetry technology known in the art (e.g., wired drill pipe, mud pulse, etc.).
  • measurement data provided from the BHA may not accurately represent conditions at the drill bit 114.
  • measurements made at the BHA 142 may be substantially delayed relative to the time which the drill bit 114 was at the given borehole location.
  • Such measurement delay may cause corresponding undesirable delay in control of the drilling parameters. For example, if drilling is to be halted at a particular borehole location or when specified conditions are present at the drill bit 114, sensors in the BHA 142 may not identify the particular location or conditions until the drill bit 114 has advanced well past the location.
  • additional sensors may be included in or at the drill bit 114 to provide measurements of formation parameters, drilling parameters, etc. at the drill bit 114.
  • a torque sensor located at the drill bit 114 may measure torque applied at the drill bit 114 to remove material at the end of the borehole 116.
  • a sensor located at the drill bit 114 may measure weight on the drill bit 114.
  • Additional sensors at the drill bit 114 may measure formation parameters or other parameters of interest.
  • Outputs from the various sensors are provided to a drilling control system 128 via a connection 132 that may be wired or wireless.
  • the drilling control system 128 controls the various parameters of the drilling process ((e.g., applied torque and rotational speed of the drill string, the axial position and speed of the drill string, weight-on-bit, the density, pressure, and/or flow rate of the drilling fluid, etc.).
  • the drilling control system 128 may control the drawworks 138, a prime mover, a top drive, the mud pump 120 etc.
  • the drilling control system 128 processes the sensor outputs to evaluate and control the drilling process.
  • the drilling control system 128 includes a pore pressure calculator 144.
  • the pore pressure calculator 144 computes the pore pressure of the formations 126 at the drill bit 114 based on MSE determined from drilling parameters measured at the drill bit 114. Because the pore pressure values computed by the pore pressure calculator 144 are provided significantly earlier than pore pressure values derived from BHA measurements, the drilling control system 128 can provide more accurate and timely control of drilling than conventional drilling systems.
  • the pore pressure calculator 144 computes MSE while drilling.
  • MSE is a measure of drilling performance, and can be defined as the work required to pulverize a unit volume of rock with the drill bit 114.
  • MSE is related to the drilling parameters torque, rotary speed, weight on bit, and rate of penetration, all of which may be recorded during a drilling operation.
  • Embodiments of the pore pressure calculator 144 can use MSE to establish pore pressure because the stress state of rocks in the subsurface is determined in part by the pressure of the fluid contained in the rock pores. Therefore, pore pressure is a determining factor for the energy required to break the rock of formations 126 with drill bit 114.
  • Drilling efficiency is defined as the ratio of the rock's confined compressive strength (CCS) to the MSE, which is a measure of energy required to energy spent to break the rock with the bit 114 under in-situ conditions.
  • CCS rock's confined compressive strength
  • CCS unconfined compressive strength
  • CCS can be calculated from UCS for a given confining stress as follows:
  • CCS UCS + ⁇ ⁇ p 1 + sin ⁇ ⁇ 1 ⁇ sin ⁇ ⁇ , where ⁇ is the angle of internal friction.
  • UCS and ⁇ can be derived from acoustic log correlations.
  • differential pressure which is defined as the difference between the wellbore pressure (the equivalent circulating density, ECD) and the formation pore pressure.
  • ECD equivalent circulating density
  • drilling bit performance is affected by differential pressure, improved drilling performance can be expected when differential pressure decreases. For instance, during underbalance drilling, drilling performance generally improves as either pore pressure increases, or ECD is held low relative to pore pressure.
  • the pore pressure that influences drilling response at the instant of drilling is the local pressure at the depth of cut zone, which may be perturbed relative to the far-field pore pressure.
  • p _ Skempton pp ⁇ ⁇ OBG ⁇ ECD , where OBG is overburden pressure/stress.
  • MSE and bit performance are influenced by differential pressure, ⁇ p, because the energy required to break the rock depends on ⁇ p.
  • drilling efficiency Eq. (2)
  • the response of drilling efficiency to differential pressure for similar lithology indicates that DE can be utilized for pore pressure estimation.
  • Pore pressure can be estimated from log data by utilizing a comparison between a measured value such as sonic slowness or resistivity, and an estimate of what that value should be under normal pressure conditions - a value referred to as the normal compaction trendline.
  • embodiments of the pore pressure calculator 144 apply DE and MSE to compute pore pressure.
  • DE is a function of CCS as shown in equation (2)
  • Figure 5 shows an example of a drilling efficiency trendline 502 and pseudo drilling efficiency values 504.
  • the coefficients a and b in this trendline model can be derived using calibration pressure data from offset wells 134.
  • An advantage of a drilling efficiency trendline based on porosity is that the same porosity trendline models which are used in sonic and resistivity based pressure estimation methods can be used for the drilling efficiency approach.
  • the pore pressure calculator 144 applies MSE to calculate pore pressure in equation (11).
  • Some embodiments apply an alternative to equation 11, which directly applies MSE to compute pore pressure, as shown in equation (13).
  • p ECD ⁇ DE trend ⁇ MSE ⁇ UCS ⁇ 1 ⁇ sin ⁇ ⁇ 1 + sin ⁇ ⁇
  • the drill string 108 may extend from a surface platform through a riser assembly, a subsea blowout preventer, and a subsea wellhead into the subsea formations.
  • FIG. 2 shows a block diagram of the drilling control system 128.
  • the drilling control system 128 includes a processor 202, a display device 204, and program/data storage 208.
  • the processor 202 is also coupled to the various sensors 216 and actuators 228 of the drilling system 100, and to the stored offset well drilling data 206.
  • the processor 202 and program/data storage 208 may be embodied in computer, such as a desktop computer, notebook computer, a blade computer, a server computer, or other suitable computing device known in the art.
  • the actuators 228 include mechanisms and/or interfaces that are controlled by the processor 202 to affect drilling operations.
  • the processor 202 may control rotation speed of the drill string 108 by controlling an electric motor through a motor controller, or may similarly control weight-on-bit by controlling a motor in the drawworks 136.
  • Various other types of actuators controlled by the processor 202 include solenoids, telemetry transmitters, valves, etc.
  • the display 204 includes one or more display devices used to convey information to a drilling operator or other user.
  • the display 204 may be implemented using one or more display technologies known in that art, such as liquid crystal, cathode ray, plasma, organic light emitting diode, vacuum fluorescent, electroluminescent, electronic paper, or other display technology suitable for providing information to a user.
  • the sensors 216 are coupled to the processor 202, and, as discussed above, include sensors for measuring various drilling system operation parameters used by the processor 202 to compute pore pressure of the formations being drilled.
  • Weight-on-bit sensors e.g., a strain gauges
  • Torque sensors e.g., strain gauges
  • coupled to the drill string 108 e.g., at the drill bit 114) measure the torque applied to the drill bit 114.
  • Rate of penetration sensors detect motion of the traveling block 106 and/or extension of the line supporting the traveling block 106, or other indications of the drill string 108 descending into the borehole 116.
  • Speed sensors 224 e.g., angular position sensors disposed in the BHA 142, at the drill bit 114, or at the surface detect rotational speed of the drill bit 114.
  • the processor 202 is configured to execute instructions retrieved from storage 208.
  • the processor 202 may include any number of cores or sub-processors. Suitable processors include, for example, general-purpose processors, digital signal processors, and microcontrollers.
  • Processor architectures generally include execution units (e.g., fixed point, floating point, integer, etc.), storage (e.g., registers, memory, etc.), instruction decoding, peripherals (e.g., interrupt controllers, timers, direct memory access controllers, etc.), input/output systems (e.g., serial ports, parallel ports, etc.) and various other components and sub-systems.
  • the program/data storage 208 is a non-transitory computer-readable medium.
  • Computer-readable storage media include volatile storage such as random access memory, non-volatile storage (e.g., ROM, PROM, a hard drive, an optical storage device (e.g., CD or DVD), FLASH storage), or combinations thereof.
  • the program/data storage 208 includes a drilling control module 230 that when executed causes the processor 202 to control drilling operations.
  • the drilling control module 230 includes a pore pressure calculation module 212 that includes instructions that when executed cause the processor 202 to compute a pore pressure value for the formations at the drill bit 114 based on measurements provided by the sensors 216 and the stored offset well data 206 as described herein.
  • the pore pressure calculation module 212 includes MSE calculation instructions 226, DE calculation instructions 214, and pore pressure calculation instructions 214.
  • the MSE calculations cause the processor 202 to compute an MSE value based on measurements made at the drill bit 114 as described herein.
  • the DE calculations instructions 214 cause the processor 202 to compute pseudo drilling efficiency and a drilling efficiency trendline based on MSE and stored offset well data 206 as disclosed herein.
  • the pore pressure calculation instructions 214 cause the processor 202 to compute pore pressure for the formations 126 proximate the drill bit 114 based on MSE and drilling efficiency values as disclosed herein.
  • the stored offset well data 206 includes data acquired while drilling other wells in the vicinity of borehole 116, and may be stored local to the processor 202 (e.g., in storage disposed proximate to the drilling system 100) or remote from the processor 202 and accessed via a communication network (e.g., the internet).
  • the stored offset well data 206 may include acoustic log data, normal hydrostatic pressure data, downhole pressure (equivalent circulation density), and/or overburden pressure/stress data acquired while drilling one or more offset wells 134.
  • the drill settings module 210 includes instructions that when executed cause the processor 202 to manipulate the actuators 228 to control the drilling operation. More specifically, the drill settings module 210 may set or change parameter that affect drilling in response to formation pore pressure measurements provided by execution of the pore pressure calculation module 212.
  • the drill settings module 214 may also provide a control interface (e.g., via the display 204) and a user input device (e.g., keyboard, mouse, trackball, touchscreen, motion sensors, etc.) that allows a drilling operator to enter drilling control information into the drilling control system 128.
  • the drill settings module 214 may provide a user interface that allows the drilling operator to change WOB, drill string RPM, etc. applied to drill the borehole 116.
  • FIG. 3 shows a block diagram of an embodiment of the pore pressure calculator 144.
  • the pore pressure calculator 144 includes a processor 202, a display device 204, and program/data storage 208.
  • the processor 202 is also coupled to the stored offset well drilling data 206.
  • the processor 202 and program/data storage 208 may be embodied in computer, such as a desktop computer, notebook computer, a blade computer, a server computer, or other suitable computing device known in the art.
  • the various components of the pore pressure calculator 144 are as described herein with respect to the drilling control system 128.
  • Figure 4 shows a flow diagram for a method 400 for determining pore pressure of a formation based on MSE and drilling efficiency in accordance with principles disclosed herein. Though depicted sequentially as a matter of convenience, at least some of the actions shown can be performed in a different order and/or performed in parallel. Additionally, some embodiments may perform only some of the actions shown. In some embodiments, at least some of the operations of the method 400, as well as other operations described herein, can be implemented as instructions stored in a computer readable medium (e.g., storage 208) and executed by one or more processors (e.g., processor 202).
  • a computer readable medium e.g., storage 208
  • processors e.g., processor 202
  • Offset well data acquired and stored may include acoustic log data, normal hydrostatic pressure data, downhole pressure (equivalent circulation density), and/or overburden pressure/stress data.
  • the pore pressure calculator 144 computes CCS under normal pressure from the offset well data.
  • the pore pressure calculator 144 may compute CCS based on UCS and angle of internal friction as shown in equation (3), where UCS and angle of internal friction are provided from the stored offset well data 206.
  • the pore pressure calculator 144 computes a drilling efficiency trendline from the stored offset well data 206.
  • the pore pressure calculator 144 may compute the drilling efficiency trendline as shown in equation (10), where normal compaction trend porosity is provided from the stored offset well data 206.
  • the borehole 116 is being drilled and drilling parameters applied by the system 100 are being acquired while drilling.
  • the drilling parameters measured may include torque, weight on bit, rate of penetration, rotational speed, bit size, etc. Parameters may be measured at the surface, in the BHA 142, or other drilling equipment. Some of the drilling parameters are measured at the drill bit 114. For example, torque and weight on bit may be measured at the drill bit 114 and transmitted to the surface for use in pore pressure calculation.
  • embodiments of the pore pressure calculator 144 apply torque measured at the drill bit 114 to compute MSE and formation pore pressure.
  • Conventional d-exponent methods may not consider the effects of torque on pore pressure determination (e.g., d-exponent may apply only WOB).
  • the pore pressure calculator 144 computes MSE based on the acquired drilling parameters.
  • the pore pressure calculator 144 may compute MSE as shown in equation (1) using torque and/or weight on bit measured at the drill bit 114.
  • the pore pressure calculator 144 computes a pseudo drilling efficiency value for the drilling of the borehole 116.
  • the pore pressure calculator 144 may compute pseudo drilling efficiency as shown in equation (8) using CCS computed from the stored offset well data 206 and MSE computed using measurements at the drill bit 114.
  • the pore pressure calculator 144 computes the difference of the pseudo drilling efficiency and the drilling efficiency trendline as shown in equation (12).
  • the pore pressure calculator 144 may compute the drilling efficiency trendline as shown in equation (10) using normal compaction trend porosity from the stored offset well data 206.
  • the pore pressure calculator 144 computes pore pressure for the formations at the drill bit 114 (i.e., the formation material in contact with the drill bit 114) based on MSE and drilling efficiency as shown in equation (11).
  • the drilling control system 128 applies the formation pore pressure computed by the pore pressure calculator 144 to control various aspects of the drilling operation. For example, based on the pore pressure value, the drilling control system 128 may determine that that drilling of a hole section is complete and halt drilling of the hole section. Similarly, the drilling control system 128 may adjust the density of the drilling fluid circulated in the borehole 116 based on the calculated pore pressure.
  • the pore pressure calculator 144 significantly reduces the time required to determine the pore pressure at a given location of the borehole 116, and in turn provides a substantial improvement in drilling technology relative to conventional pore pressure estimation technologies.
  • FIG. 5 shows an example of pore pressure determined using conventional methods and pore pressure calculated based on MSE in accordance with principles disclosed herein.
  • the conventionally determined pore pressure values 506 are derived from sonic log data using conventional methods. Pore pressure values calculated as disclosed herein 508 are computed based on MSE and drilling efficiency using torque and weight on bit measurements made at the drill bit 114. As shown in Figure 5 , the MSE/DE derived pore pressure values 508 compare favorably with the sonic derived pore pressure values 506.
  • Figure 6 shows an example of pore pressure determined using conventional d-exponent methods 602 and pore pressure calculated based on MSE 604 in accordance with an embodiment disclosed herein.
  • the d-exponent methodology is often used to establish a quantitative estimate of formation pore pressure as well as qualitative detection of abnormal formation pressure.
  • a d-exponent equation modified to include mud weight, known as the corrected d-exponent (dXc), is shown in equation (14).
  • dXc log ROP 60 ⁇ RPM log 12 ⁇ WOB d p n p w where:
  • both the dXc method and the DE/MSE based technique of the present disclosure have been applied to a same well dataset.
  • the dXc method has been applied using a single normal trend line, which was established by fitting the dXc data through the normally pressured section between 10000-11000ft, Both dXc and the DE/MSE based technique provide a reasonable estimate of pore pressure for the bottom hole section.
  • pore pressure trends estimated using the dXc method are a poor match to the log derived pressure curve, while the DE/MSE technique yields a result with considerably less scatter, and which more closely follows the sonic-derived pore pressure curve.
  • the dXc parameter considers only weight on bit (compare equation (1) with equation (14)). Because dXc considers only WOB, changes in drilling variables that are not related to pore pressure, such as bit size, bit type, and mud properties, etc., can often lead to dXc variations that are misinterpreted as having pore pressure significance.
  • a common practice to compensate, when attempting to use dXc for pore pressure estimation, is to use multiple trendlines (e.g., for each hole section). But such trendline breakage leads to an increased level of subjectivity, and will adversely affect the confidence, in pore pressure estimates from the dXc approach.
  • a method for drilling a borehole in a subsurface formation includes 1) rotating a drill bit to remove formation material from the subsurface formation at an end of the borehole; 2) calculating a value of mechanical specific energy applied to remove the formation material; 3) calculating a value of drilling efficiency based on the value of mechanical specific energy; 4) calculating pore pressure of the subsurface formation in contact with the drill bit as a function of calculated drilling efficiency; and/or 5) controlling the drilling based on calculated pore pressure of the subsurface formation.
  • the method may also include acquiring a measurement of downhole torque applied at the drill bit and weight on bit applied at the drill bit to perform the rotating; and calculating the value of mechanical specific energy based on the acquired measurement of torque and weight on bit at the drill bit.
  • the method may also include calculating the pore pressure based on a product of the value of mechanical specific energy and the calculated drilling efficiency.
  • the method may also include calculating the pore pressure based on an angle of internal friction derived from offset well data.
  • the method may also include calculating confined compressive strength of the formation based on normal pore pressure; and calculating the value of drilling efficiency as a ratio of the calculated confined compressive strength to the value of mechanical specific energy.
  • the method may also include calculating a trend of normal drilling efficiency based on pressure data from an offset well; and calculating the pore pressure as a function of a difference of the value of drilling efficiency and the trend of normal drilling efficiency.
  • the method may also include determining whether the calculated pore pressure is within a predetermined pressure range; and controlling the drilling operation responsive to the calculated pore pressure being within the predetermined pressure range.
  • controlling the drilling may include at least one of changing drilling fluid density and changing drill bit movement.
  • the method may also calculate the pore pressure of the subsurface formation prior to a formation parameter measurement tool disposed uphole of the drill bit (e.g., disposed in a bottom hole assembly) reaching a location of the subsurface formation corresponding to the calculated pore pressure.
  • a system for drilling a borehole in a subsurface formation includes a drill string; a drill bit positioned at an end of the drill string to extend the borehole into the subsurface formation; and a drilling control system.
  • the drilling control system includes: a pore pressure calculator and drilling control logic.
  • the pore pressure calculator is configured to calculate pore pressure of the formation in contact with the drill bit.
  • the pore pressure calculator is further configured to: calculate a value of drilling efficiency for the drilling of the borehole based on a drilling parameter measured at the bit; and calculate the pore pressure as a function of the calculated value of drilling efficiency.
  • the drilling control logic is configured to control the drilling based on calculated pore pressure.
  • the pore pressure calculator may be configured to: calculate a value of mechanical specific energy applied to drill the formation; and calculate the value of drilling efficiency based on the value of mechanical specific energy.
  • the pore pressure calculator may be configured to: acquire a measurement of torque applied at the drill bit and weight on bit applied at the drill bit to drill the formation; and calculate the value of mechanical specific energy based on the acquired measurement of torque and weight on bit at the drill bit.
  • the measurement of torque applied at the drill bit may be acquired in a bottom hole assembly of the drill string.
  • the measurement of torque applied at the drill bit may be a measurement of torque applied in a portion (a percentage, e.g., 1/10th) of the drill string nearest the drill bit.
  • the pore pressure calculator may be configured to: calculate the pore pressure based on the value of mechanical specific energy.
  • the pore pressure calculator may be configured to: calculate confined compressive strength of the formation based on normal pore pressure; and calculate the value of drilling efficiency as a ratio of calculated confined compressive strength to the value of mechanical specific energy.
  • the pore pressure calculator may be configured to: calculate a trend of normal drilling efficiency based on pressure data from an offset well; and calculate the pore pressure as a function of a difference of the value of drilling efficiency and the trend of normal drilling efficiency.
  • the drilling control logic may be configured to: determine whether the calculated pore pressure is within a predetermined pressure range; and change at least one of drilling fluid density and drill bit movement based responsive to the calculated pore pressure being within the predetermined pressure range.
  • a system for calculating pore pressure of a subsurface formation includes a processor and a storage that is coupled to the processor.
  • the storage device contains instructions that when executed cause the processor to: 1) calculate a value of mechanical specific energy applied at a drill bit to remove material from the subsurface formation; 2) calculate a value of drilling efficiency for drilling the formation; and 3) calculate pore pressure of the formation in contact with the drill bit as a function of the value of drilling efficiency and the mechanical specific energy.
  • the instructions may also cause the processor to acquire a measurement of torque applied at the drill bit to remove the material from the subsurface formation; and calculate the value of mechanical specific energy based on the acquired measurement of torque applied at the drill bit.
  • the instructions may also cause the processor to calculate the pore pressure based on a product of the value of mechanical specific energy and the value of drilling efficiency.
  • the instructions may also cause the processor to calculate confined compressive strength of the formation based on normal pore pressure; and calculate the value of drilling efficiency as a ratio of the calculated confined compressive strength to the value of mechanical specific energy.
  • the instructions may also cause the processor to calculate a trend of normal drilling efficiency based on pressure data received from an offset well; and calculate the pore pressure as a function of a difference of the value of drilling efficiency and the trend of normal drilling efficiency.
  • the instructions may also cause the processor to calculate the pore pressure as shown in equation (11) or (13).
  • a method for drilling a borehole in a subsurface formation includes: 1) rotating a drill bit to remove formation material from the subsurface formation at an end of the borehole; 2) calculating a value of mechanical specific energy applied to remove the formation material; 3) calculating a value of drilling efficiency for drilling the borehole; 4) calculating pore pressure of the subsurface formation in contact with the drill bit as a function of the drilling efficiency and the mechanical specific energy; and 5) controlling the drilling based on calculated pore pressure of the subsurface formation.
  • the method may also include acquiring a measurement of downhole torque applied at the drill bit and weight on bit applied at the drill bit to perform the rotating, and calculating the value of mechanical specific energy based on the acquired measurement of torque and weight on bit at the drill bit.
  • the method may also include acquiring the measurement of downhole torque applied at the drill bit in a bottom hole assembly of a drill string, or acquiring the measurement of downhole torque applied at the drill bit in a 1/10 of a drill string nearest the drill bit.
  • the method may also include calculating the pore pressure based on an angle of internal friction derived from offset well data.
  • the method may also include calculating confined compressive strength of the formation based on normal pore pressure, and calculating the value of drilling efficiency as a ratio of the calculated confined compressive strength to the value of mechanical specific energy.
  • the method may also include determining whether the calculated pore pressure is within a predetermined pressure range, and controlling the drilling operation responsive to the calculated pore pressure being within the predetermined pressure range.
  • Controlling the drilling may include at least one of changing drilling fluid density and changing drill bit movement.
  • the pore pressure of the subsurface formation may be calculated prior to a formation parameter measurement tool disposed uphole of the drill bit reaching a location of the subsurface formation corresponding to the calculated pore pressure.
  • the method may also include calculating the pore pressure based on a product of the value of mechanical specific energy and the value of drilling efficiency.
  • the method may also include calculating a trend of normal drilling efficiency based on pressure data from an offset well, and calculating the pore pressure as a function of a difference of the value of drilling efficiency and the trend of normal drilling efficiency.
  • the method may also include calculating the pore pressure based on equation (11).
  • the method may also include calculating a trend of normal drilling efficiency based on pressure data from an offset well, and calculating the pore pressure as a product of the trend and the value of mechanical specific energy.
  • the method may also include calculating the pore pressure based on equation (13).
  • a system is configured to perform any of the operations of the method.

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  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Analytical Chemistry (AREA)
  • Geophysics (AREA)
  • Earth Drilling (AREA)

Claims (15)

  1. Procédé de forage d'un puits (116) dans une formation en sous-surface (126), comprenant :
    la rotation d'un trépan (114) afin d'éliminer la matière de formation de la formation en sous-surface (126) à une extrémité du puits (116) ;
    le calcul d'une valeur d'énergie spécifique mécanique appliquée afin de retirer la matière de formation ;
    le calcul d'une valeur d'efficacité de forage pour forer le puits (116) ;
    le calcul d'une pression de pore de la formation en sous-surface (126) en contact avec le trépan (114) en fonction de la valeur d'efficacité de forage et de l'énergie spécifique mécanique ; et
    le contrôle du forage sur la base de la pression de pore calculée de la formation en sous-surface.
  2. Procédé selon la revendication 1, comprenant en outre :
    l'acquisition d'une mesure du couple de fond appliqué au niveau du trépan (114) et du poids sur le trépan appliqué au niveau du trépan afin d'effectuer la rotation ; et
    le calcul de la valeur d'énergie spécifique mécanique sur la base de la mesure acquise du couple et du poids sur le trépan au niveau du trépan.
  3. Procédé selon la revendication 2, comprenant en outre l'acquisition de la mesure du couple de fond appliqué au niveau du trépan dans un ensemble de fond de puits (142) d'un train de forage (108).
  4. Procédé selon la revendication 2, comprenant en outre l'acquisition de la mesure du couple de fond appliqué au niveau du trépan (114) à 1/10 d'un train de forage (108) le plus proche du trépan.
  5. Procédé selon l'une quelconque des revendications 1 à 4, comprenant en outre le calcul de la pression de pore sur la base d'un angle de frottement interne dérivé de données de puits de limite.
  6. Procédé selon l'une quelconque des revendications 1 à 5, comprenant en outre :
    le calcul de la force de compression confinée de la formation sur la base d'une pression de pore normale ; et
    le calcul de la valeur d'efficacité de forage sous forme de rapport entre la force de compression confinée calculée et la valeur d'énergie spécifique mécanique.
  7. Procédé selon l'une quelconque des revendications 1 à 6, comprenant en outre :
    la détermination du fait que la pression de pore calculée se trouve ou non dans des limites de pression prédéterminées ; et
    le contrôle de l'opération de forage en réponse à la pression de pore calculée qui se trouve dans les limites de pression prédéterminées.
  8. Procédé selon l'une quelconque des revendications 1 à 7, dans lequel le contrôle du forage comprend au moins l'une de la modification de la densité du fluide de forage et de la modification du mouvement du trépan.
  9. Procédé selon l'une quelconque des revendications 1 à 8, comprenant en outre le calcul de la pression de pore de la formation en sous-surface (126) avant qu'un outil de mesure de paramètre de formation disposé en amont du trépan (114) atteigne un emplacement de la formation en sous-surface correspondant à la pression de pore calculée.
  10. Procédé selon l'une quelconque des revendications 1 à 9, comprenant en outre le calcul de la pression de pore sur la base d'un produit de la valeur de l'énergie spécifique mécanique et de la valeur d'efficacité de forage.
  11. Procédé selon l'une quelconque des revendications 1 à 10, comprenant en outre :
    le calcul d'une tendance de l'efficacité de forage normale sur la base de données de pression provenant d'un puits de limite ; et
    le calcul de la pression de pore en fonction d'une différence entre la valeur d'efficacité de forage et la tendance de l'efficacité de forage normale.
  12. Procédé selon l'une quelconque des revendications 1 à 11, comprenant en outre le calcul de la pression de pore sous la forme : p = p n + Δ ⁢ DE × MSE × 1 − sin ⁢ θ 1 + sin ⁢ θ ,
    Figure imgb0019
     où :
    p correspond à la pression de pore calculée ;
    pn correspond à la pression hydrostatique normale ;
    ΔDE correspond à une différence entre la valeur d'efficacité de forage et une tendance de l'efficacité de forage normale ;
    MSE correspond à la valeur de l'énergie spécifique mécanique ; et
    θ correspond à l'angle de frottement interne.
  13. Procédé selon l'une quelconque des revendications 1 à 9, comprenant en outre :
    le calcul d'une tendance d'efficacité de forage normale sur la pression de données de pression qui proviennent d'un puits limite ; et
    le calcul de la pression de pore sous forme d'un produit de la tendance et de la valeur d'énergie spécifique mécanique.
  14. Procédé selon l'une quelconque des revendications 1 à 9 et 13, comprenant en outre le calcul de la pression de pore comme suit : p = ECD − DE trend × MSE − UCS × 1 − sin ⁢ θ 1 + sin ⁢ θ ,
    Figure imgb0020
     où :
    p correspond à la pression de pore calculée ;
    ECD correspond à la densité de circulation équivalente ;
    DEtrend correspond à une tendance d'efficacité de forage normale ;
    MSE correspond à la valeur d'énergie spécifique mécanique ;
    UCS correspond à la force de compression confinée ; et
    θ correspond à l'angle de frottement interne.
  15. Système de calcul de la pression de pore d'une formation en sous-surface (126) comprenant un processeur (202) et un dispositif de stockage (208) qui est relié au processeur, dans lequel le dispositif de stockage contient des instructions qui, lorsqu'elles sont exécutées, permettent au processeur de :
    calculer une valeur d'énergie spécifique mécanique appliquée au niveau d'un trépan (114) afin de retirer une matière de la formation en sous-surface (126) ;
    calculer une valeur d'efficacité de forage pour forer la formation ; et
    calculer la pression de pore de la formation en contact avec le trépan en fonction de la valeur d'efficacité de forage et de l'énergie spécifique mécanique.
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