CN103635655A - Optimized pressure drilling with continuous tubing drill string - Google Patents
Optimized pressure drilling with continuous tubing drill string Download PDFInfo
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- CN103635655A CN103635655A CN201180071386.XA CN201180071386A CN103635655A CN 103635655 A CN103635655 A CN 103635655A CN 201180071386 A CN201180071386 A CN 201180071386A CN 103635655 A CN103635655 A CN 103635655A
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/08—Wipers; Oil savers
- E21B33/085—Rotatable packing means, e.g. rotating blow-out preventers
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency
- E21B47/135—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency using light waves, e.g. infrared or ultraviolet waves
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
- G01V1/42—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators in one well and receivers elsewhere or vice versa
Abstract
A method of drilling a wellbore can include drilling the wellbore with a continuous tubing drill string, and sensing at least one parameter with an optical waveguide in the drill string. A well system can include a continuous tubing drill string, and an optical waveguide in the drill string. The optical waveguide may sense at least one parameter distributed along the drill string.
Description
Technical field
The present invention relates generally in conjunction with the equipment of drilling well use and the operation of enforcement, and in described in the text embodiment, provides particularly the optimization pressure probing with continuous tubular drill string.
Background technology
In traditional drilling operation, can survey the various parameters that affect drilling operation with the sensor in drill string surface and bottom hole assembly.Yet so sensor is not measured the parameter along drill string, flow into pit shaft or survey fluid while running off from pit shaft surveying fluid, so the purposes of sensor is limited.
Therefore, should be realized that need to there be improvement aspect the detection technology of drilling operation.These improvement can be used in the situation that situation discussed above neutralizes other.
Accompanying drawing explanation
Fig. 1 is the partial sectional view of the signal of well system and the correlation technique that can implement the principle of the invention.
Fig. 2 is the block diagram of signal of Process Control System that can be used for the well system and method for Fig. 1.
Fig. 3 is the schematic diagram of another well System Construction.
Fig. 4 is the signal partial sectional view of the amplification of a well system part.
Fig. 5 is temperature along the pit shaft schematic graph to the degree of depth, and this figure comprises the indication that fluid runs off from pit shaft.
Fig. 6 is temperature along the pit shaft schematic graph to the degree of depth, and this figure comprises the indication that fluid flows into cylinder.
Fig. 7 is the indicative flowchart of surveying influx and adjusting the method for choke according to response, and the method can be implemented principle of the present invention.
Fig. 8 is the indicative flowchart of surveying fluid number of dropouts and adjusting the method for choke according to response, and the method can be implemented principle of the present invention.
The specific embodiment
What in Fig. 1, schematically show is well system 10 and the relevant method that can implement the principle of the invention.In system 10, by rotating the drill bit 14 on tubular drill string 16 ends, drill out pit shaft 12.
The so-called mud of drilling fluid 18, it flows out drill bit 14 by drill string 16 circulation downwards, and upwards flow through the ring cavity 20 being formed between drill string and pit shaft 12, to cooling drill bit, lubricated drill string, remove drill cuttings, and provide the measurement that bottom pressure is controlled.Irrevocable valve 21(is the flap valve of hinge type normally) stop drilling fluid 18 upwards to flow through drill string 16.
Being controlled in stress management and underbalance probing of bottom pressure, and seem extremely important in the optimization pressure drilling operation of other types.Preferably, bottom pressure is optimized, to prevent that excessive fluid is lost to pit shaft 12 stratum 64, undesirable stratum breaking, undesirable formation fluid around and flows in pit shaft etc.
At typical pressure, control in probing, wish to keep bottom pressure to be greater than the pore pressure on stratum 64, be no more than formation fracture pressure.In typical drilled underbalanced, wish to keep bottom pressure to be slightly less than pore pressure, thus, from stratum, 64 fluids that flow into are controlled.
Nitrogen or other gas or other lightweight fluid, can add in drilling fluid 18, to carry out pressure control.This technology is for example in underbalance drilling operation, or useful especially in the pressure probing of isolation density (such as two gradients) management.
In system 10, the control device 22(RCD rotating by use) for example close ring cavity 20(, isolated ring cavity is communicated with atmosphere, and can to ring cavity, pressurize at place, ground or near place, ground), obtain the additional control to bottom pressure.This RCD22 seals around drill string 16 above well head 24.Although do not give and illustrating in Fig. 1, drill string 16 extends upward by RCD22, to be connected to for example standpipe pipeline 26 and/or other traditional drilling equipment.
Drilling fluid 18 flows out well head 24 by flutter valve 28, and this wing valve position RCD22 below is communicated with ring cavity 20.Then drilling fluid 18 flow through fluid return line 30, flows to chokes collector 32, and chokes collector 32 comprises the choke 34 of redundancy.By limit fluid changeably 18 by redundancy choke 34 the flowing an of choke of operation, back pressure is applied to ring cavity 20.
The restriction that fluid flows through choke 34 is larger, and for given flow, the back pressure that is applied to ring cavity 20 is just larger.Therefore, the restriction that can flow through by changing convection cell choke changes the back pressure that is applied to ring cavity 20, just can regulate easily bottom pressure.As hereinafter more complete description, can determine that place, ground or Near Ground are applied to the pressure of ring cavity 20 with a hydraulic model, this pressure will cause desired bottom pressure, so, operator's (or automation control system) can easily determine the pressure (this pressure can be measured easily) that how to regulate place, ground or Near Ground to be applied to ring cavity, to obtain desired bottom pressure.
Also can wish to control the pressure along other positions of pit shaft 12.For example, the pressure at the casing shoe place in the substantially vertical or horizontal component of pit shaft 12 or lateral bores heel place, or the pressure at any other position, all can be controlled by principle of the present invention.
The pressure that is applied to ring cavity 20 can pass through various pressure sensors 36,38,40, on ground or Near Ground measure, each sensor is communicated with ring cavity.Pressure sensor 36 sensing RCD22 belows but at the pressure of stacking 42 tops of preventer (BOP).The pressure of stacking 42 belows of BOP in pressure sensor 38 sensing well heads.Pressure in the fluid return line 30 of pressure sensor 40 sensing chokes collector 32 upstreams.
Pressure in another pressure sensor 44 sensing standpipe pipelines 26.Also have another pressure sensor 46 sensing chokes collector 32 downstreams but at the pressure of eliminator 48, vibrator 50 and mud pit 52 upstreams.Other sensor comprises temperature pick up 54,56, Coriolis (Coriolis) flow meter 58 and flow meter 62,66.
Not all these sensors are all necessary.For example, system 10 can only comprise in flow meter 62,66.Yet, from the input of sensor, can be used for hydraulic model, in order to determine in drilling operation process, should be which pressure is applied to ring cavity 20.
In addition, drill string 16 can comprise the sensor 60 of himself, for example, is used for direct measuring well bottom pressure.So sensor 60 can be that type known by the technical staff in the art, the sensing system of record (LWD) when they measure (MWD) and/or probing when pressure (PWD), probing during as probing.These drill string sensing systems usually provide at least pressure measxurement, and also can provide temperature survey, survey drill string feature (such as weight, stick-slip etc. on vibration, drill bit), stratum characteristic (such as resistivity, density etc.) and/or other measurement.Can use various forms of telemetries (sound, pressure pulse, electromagnetism, optics, wired etc.), will creep into measurement value sensor downwards and be sent to ground.Drill string 16 can be provided with conductor, fiber waveguide etc., for seeing Fig. 2 at sensor 60 and the Process Control System 74(that will describe below) between transmit data and/or instruction.
If necessary, system 10 also can comprise other sensor.For example, can measure with another flow meter 67 flow of the fluid 18 that flows out well head 24, another coriolis flowmeter (not shown) can direct interconnection in upstream or the downstream of stand slush pump 68 grades.
If necessary, system 10 also can comprise less sensor.For example, stroke that can be by meter-pump rather than use traffic meter 62 or any other flow meter, determine the output of stand slush pump 68.
It should be noted that, eliminator 48 can be the eliminator of 3 phases or 4 phases, or gas-mud separater (being sometimes called " mud gas separator ").Yet, in system 10, not necessarily to use eliminator 48.
Drilling fluid 18 is pumped into drill string 16 inside by means of stand slush pump 68 by standpipe pipeline 26.Pump 68 is accepted fluid 18 from mud pit 52, and by not shown in standpipe collector 86(Fig. 1, can be referring to Fig. 3) make fluid flow to standpipe pipeline 26.Then, fluid 18 cycles through drill string 16 downwards, upwards, by ring cavity 20, by mud return line 30, by chokes collector 32, then by eliminator 48 and vibrator 50, flows to mud pit 52, for regulating and recycling.
It should be noted that, till in system 10 described above, choke 34 can not be used for controlling the back pressure that is applied to ring cavity 20 of bottom pressure being implemented to control, remove nonfluid 18 and flow through choke.In the drilling operation of traditional overbalance, in the time of will connecting in drill string 16 (for example, along with pit shaft 12 is drilled more and more deeplyer, the drill pipe of another length need be added on drill string), the shortage of circulation will occur, and the shortage of circulation only will require to regulate bottom pressure by the density of fluid 18.
Yet, in system 10, even if fluid does not cycle through drill string 16 and ring cavity 20, also can maintain fluid 18 flowing by choke 34.Therefore, by limit fluid 18, pass through flowing of choke 34, still pressure can be applied to ring cavity 20.For example, when drill string 16 moves into and shifts out pit shaft 12, this ability can be of great use.
In system 10 as shown in Figure 1, by pumping fluid in another position of ring cavity 20 or chokes collector upstream, just can use back pressure pump 70, fluid is flowed and is fed to the return line 30 of chokes collector 32 upstreams.As shown in Figure 1, pump 70 is connected to ring cavity 20 by BOP stacking 42, but in other examples, pump 70 can be connected to return line 30 or chokes collector 32.
Alternatively, or additionally, when needed, can be described in international patent application series No.PCT/US08/87686, as U.S. Patent application series No.13/022, described in 964, or use other technology, make fluid redirect to return line 30 from standpipe collector (or alternate manner ground is from stand pump 68).
Thus, 34 pairs of mobile restrictions of fluid like this from stand pump 68 and/or back pressure pump 70 of choke, cause pressure to be applied on ring cavity 20.If use back pressure pump 70, flow meter 72 can be used to measure the output of pump.
, in addition with reference to Fig. 2, the block diagram of an example of Process Control System 74 is schematically shown in figure now.In other example, Process Control System 74 can comprise other quantity, type, combination of element etc., and any element can be positioned on different positions, or can form one with another element, to accord with scope of the present invention.
As shown in Figure 2, Process Control System 74 comprises data acquisition and control interface 118, hydraulic model 120, prediction unit 122, data verification device 124 and controller 126.These elements can be similar to the element described in the international patent application series No.PCT/US10/56433 submitting on November 12nd, 2010.
Data acquisition and control interface 118 receives data from various sensors 36,38,40,44,46,54,56,58,60,62,66,67,72, and together with receiving stand and creeping into data downwards, data transfer is arrived to hydraulic model 120 and data verification device 124.In addition, interface 118 is transferred to data verification device 124 by the inner-ring gas pressure of the requirement from hydraulic model 120.
Like this, choke 34, pump 70 and flow control apparatus 128 can be automatically controlled, to reach in ring cavity 20 and to keep required pressure.The interior actual pressure of ring cavity 20 is measured (for example, using sensor 36,38,40) conventionally near well head 24 places or well head 24, and it is land or under water that well head 24 can be positioned at.
, in addition with reference to Fig. 3, in figure, show typically and schematically the another kind structure of well drilling system 10 now.In this structure, flow control apparatus 76 is connected to the upstream end of stand standpipe collector 86.Flow control apparatus 76 can be interconnected between stand pump 68 and standpipe collector 86, such as using quick connector 84(such as high pressure union etc.) interconnect.This will make flow control apparatus 76 be applicable to easily the interconnection of various stand pump line lines.
In order to control, flow through flowing of standpipe pipeline 26, for example can use particularly suitable full automatic flow control apparatus 76(, a kind of as in the flow control apparatus 128 of being controlled by controller 126 automations), replace using the traditional standpipe valve in stand standpipe collector 86.Flow control apparatus 76, together with one or more additional flow control apparatus 78,80,82, can be used to make fluid 18 redirect to chokes collector 32 from stand pump 68 by by-pass line 75.
, in addition with reference to Fig. 4, in figure, show typically the structure of well system 10 now.In this structure, drill string 16 comprises the continuous-tube of coil pipe or other form, its have at least one fiber waveguide 88(of extending along its length such as, optical fiber, light belt etc.).
In Fig. 4, waveguide 88 is illustrated as the inside longitudinal flow passage 90 that extends through drill string 16, but in other example, and waveguide is extensible in the sidewall of drill string, outside drill string etc.Waveguide 88 can be the form of ring, and this ring starts to extend to bottom at place, coil pipe top, turns over the curved surface that turns back to, to improve temperature survey characteristic.
The pipeline of a plurality of optical waveguides 88 together with other type (for example, electric wire pipeline and/or waterpower pipeline etc.) can be provided.Various pipelines can be brought in the cable with optional feature, such as armouring, insulation, foreskin, electric wire pipeline, waterpower pipeline and/or shielding etc., or they can be arranged in drill string 16 individually.
Fiber waveguide 88 can be arranged on the pipe of drill string 16 or control in pipeline.Preferably, can provide single mode and multi-modal fiber waveguide 88, but this is dispensable, to accord with principle of the present invention.
The left-hand side of Fig. 4 illustrates such situation, and wherein, fluid 18 is lost in stratum 64.That is, fluid 18 flows into stratum 64 from pit shaft 12.
For example, when the pressure in pit shaft 12 is greater than the fracture pressure on stratum 64, will there is this kind of situation.So situation can be avoided conventionally, but also can advantages ground use (for example, be used for determining easily fracture pressure etc.), this will more completely describe hereinafter.
The right-hand side of Fig. 4 illustrates another kind of situation, and wherein, formation fluid 94 is in the 64 inflow pit shafts 12 of stratum.For example, when the pressure in pit shaft 12 is less than the pore pressure on stratum 64, will there is this kind of situation.
In general, in underbalance drilling operation (for example,, in when probing, formation fluid 94 controlledly flows in pit shaft 12), so situation is desirable, but for example, is undesirable in the drilling operation (, having the pressure probing of management, traditional overbalance probing etc.) of other types.In the technology of more complete description, formation fluid 94 flows in pit shaft 12, can be used to determine easily the pore pressure on stratum 64 below.
It should be noted that, when fluid 94 flows in pit shaft 12, fluid 18 can not flow in stratum 64 (as shown on Fig. 4 right-hand side).Therefore, the situation shown on Fig. 4 left-hand side and right-hand side can not occur simultaneously, but contrary, is used for showing generable situation of separating in drilling operation process.
In Fig. 5, for the part of the pit shaft 12 shown in Fig. 4, and the situation of the loss of the fluid shown on Fig. 4 left-hand side, Fig. 5 shows temperature for the representative chart 96 of the degree of depth.It should be noted that, at fluid 18, enter the position on stratum 64, detected the reduction by 98 of temperature.
The reduction by 98 of temperature is owing to entering the position on stratum at fluid, the cause on stratum 64 that fluid 18 is cooling partly.So temperature anomaly reduction by 98 can be used to survey fluid 18 loss events have occurred where and when, and can be used to determine when the fracture pressure that has reached stratum 64.
In Fig. 6, for the part of the pit shaft 12 shown in Fig. 4, and the situation of 94 inflows of the fluid shown on Fig. 4 right-hand side, Fig. 6 shows temperature for the representative chart 100 of the degree of depth.It should be noted that, at fluid 94, enter the position of pit shaft 12, detected the rising 102 of temperature.
The rising 102 of temperature is that fluid 94 has heated the cause of pit shaft 12 partly owing to entering the position of pit shaft at fluid.So temperature anomaly rises and 102 can be used to survey fluid 94 inflow events have occurred where and when, and can be used to determine when that pit shaft internal pressure becomes is less than the pore pressure on stratum 64.
Preferably, use well-known districution temperature perception (DTS) technology, adopt fiber waveguide 88 to measure temperature.DTS can be used to measure the technology along the Temperature Distribution of fiber waveguide 88.
Can use the lasing light emitter of pulse, send light pulse to pass through fiber waveguide 88, can record the characteristic of back light.This back light (" back scatter ") comprises the absorption of luminous energy and re-emissions.
The light of back scatter comprises different spectral components, for example, and Rayleigh (Rayleigh), Brillouin (Brillouin) and Raman (Ramen) band.Raman band can be used to obtain the temperature information along optical fiber.
Raman back scatter has two components, that is, Stokes (Stokes) and anti-Stokes (Anti-Stokes), the former depends on temperature a little less than being, and the latter's temperature influence is very large.Relative intensity between Stokes and anti-Stokes is the function that the temperature of back scatter place occurs.
Because the speed of light in glass is known, therefore by trackings, reflect the time of advent with backscattered light, just can determine the exact position that backscattered light originates from.DTS follows the tracks of or curve (such as the curve 96,100 of Fig. 5 and 6) is one group of measured temperature or sampled point, and they are along fiber waveguide 88 length spacing equidistantly.
Brillouin's backscattered light wavelength is also that temperature relies on, and therefore, can be used for DTS.Yet Brillouin's backscattered light also depends on the local train in waveguide 88, so for temperature survey, can eliminate the components of strain (for example,, by guaranteeing that waveguide is without undergoing strain), counteracting etc.
In the example of Fig. 4, fiber waveguide 88 is monitored for DTS.Yet, if necessary, also can use the photo measure of other distributions.The vibration-sensing (DVS) that for example, can use the sound sensing (DAS) of distribution, the straining and sensing (DSS) distributing or distribute.
As discussed above, Raman back scatter sensing is generally used for DTS monitoring, but if necessary, also can use Brillouin's back scatter sensing.Brillouin or rayleigh back scattering sensing can be used for DAS, DSS or DVS monitoring, preferably sensing Brillouin back scatter gain or relevant rayleigh back scattering.Also can use the light perception of (or alternatively) interferometry.
In an example, DAS can be used to sensing fluid 94 from stratum 64 voice signals that for example, produce while flowing into (, fluid flows into) in pit shafts 12, or for example, because fluid 18 flows into reducing of the magnitude of sound that causes on stratum (, fluid runs off) from pit shaft.Also can (or alternatively) by fiber waveguide 88, measure other features (such as the vibration of drill string 16, stick-slip, rotation, strain etc.) of drilling operation.
DAS can be used to survey from stratum 64 and enters the voice signal of the gas of pit shaft 12, and/or flows through the voice signal of the gas of ring cavity 20.For example, waveguide 88 will indicate drill string 16 to be exposed to the sound sound that in the interior gas of pit shaft 12, part weakens, so, for this purpose, can survey the acoustic resonance distributing in drill string with the optical device that is connected to waveguide.
This can provide gas early stage blowout detection system, thus, not only may detect inflow event, and may detect the position in fluid inflow pit shaft 12, and position and the speed of ring cavity 20 interior gases.So information can allow stand personnel to make suitable adjustment in the suitable time, so that gas circulation goes out outside pit shaft 12, and stops further and flows into.
DAS can be used to survey another near the sound wave of another drill string (not shown) generation in pit shaft (not shown).When another drill string is drilled another pit shaft, the sound wave that another drill string produces is surveyed in waveguide 88, so, can easily determine that another pit shaft is with respect to the position of pit shaft 12, so that guiding pit shaft intersects each other or avoids crossing.
DAS can be used to survey in pit shaft 12 or outer other events that can produce voice signal of pit shaft.For example, available waveguide 88 is surveyed and is occurred in washing away in pit shaft 12.As another example, on the ground, in other pit shaft etc., can cause the seismic origin, with the vibration of waveguide 88 detectable earthquakes.
Except the measurement distributing, can make with one or more sensors 104 point measurement of characteristic.For example, sensor 104 can comprise pressure sensor, chemical ion or pH sensor, ionization radiation sensor, magnetic field sensor etc.Sensor 104 can be sensors optics or other types, and can be connected to or be free of attachment to the part of waveguide 88, part that can yes or no waveguide 88.
In another example, sensor 104 is not necessarily coupled to waveguide 88 with optical mode.On the contrary, sensor 104 can be communicated with waveguide 88 by voice mode.In this example, sensor 104 can be launched acoustic signal, measured value (for example can be modulated on signal, frequency of utilization, phase place or amplitude transformation key entry etc.), acoustic signal can be accepted also (back scatter variation) photographically by waveguide 88 and be sent at a distance (such as earth surface, probing stand, subsea wellheads etc.).
If necessary, also can provide additional one or more pipelines 106.In an example, pipeline 106 comprises electric conductor, and it is used as antenna to induce magnetic field in stratum 64.Changes of magnetic field can show the variation of stratum 64 interior resistivity.
The interior well-known Faraday effect of detectable waveguide 88, this effect indicates stratum 64 internal magnetic fields and changes.In this example, drill string 16 can be made with compound or other nonmagnetic substances, like this, and its not disturbing magnetic field propagation of 64 to stratum, and the not variation of interference detection stratum internal magnetic field.
In an example, in drilling operation process, record is carried out in available waveguide 88.For example, waveguide 88 may detect the 64 γ radiation of sending from stratum.Like this, when operator can know when the stratum of penetrable specific subsurface formations, contiguous drill string 16 can be relevant to the subsurface formations of expection etc.In this example, drill string 16 can preferably be made by composite material or other nonmetals.
By covering phosphorescence or fluorescence is provided in waveguide, just may detect the ionization radiation along waveguide 88.Different stratum can have different spectral absorption characteristics, based on these characteristics, can allow identification and checking stratum.
Although below only described some examples of distribution and detection technology point that utilizes waveguide 88, should be expressly understood that, any quantity of any detection technology and detection technology or combination all can be used, to accord with principle of the present invention.
In addition referring to Fig. 7, Fig. 7 shows the method 108 of well system 10 structures that can be used for Fig. 4 typically with flow chart form now.Certainly, method 108 can be put into practice in other well systems, to accord with principle of the present invention.
In method 108, detect formation fluid 94 and flow into, it shows the pore pressure on stratum 64.When pit shaft 12 internal pressures at certain position are less than stratum 64 pore pressure at this position, pressure reduction inductively layer fluid 94 flows to and flows in pit shaft.
Therefore, flowing into point that stream starts is that pit shaft 12 internal pressures become and are less than that point of stratum 64 pore pressures.When so inflow and outflow is current, can easily record pit shaft 12 internal pressures (for example, using sensor 60,104 etc.), and for example can record easily, near the pressure in the ring cavity 20 on ground (, using sensor 38,40 etc.).
It should be noted that, pressure in the pit shaft 12 that flows into position can comprise the friction pressure (also referred to as equivalent circulating density) that flows and cause due to fluid 18, so, in determine flowing into position pit shaft, during actual pressure, preferably consider this pressure (if present).Yet, when method 108 is implemented, not necessarily require fluid 18 to cycle through drill string 16 and ring cavity 20.On the contrary, can in method 108 implementation processes, use pump 70(to see Fig. 1) or/or stand pump 68(see Fig. 3), accommodating fluid flows through choke 34, does not allow fluid 18 cycle through drill string 16 and ring cavity 20.
At step 110 place of method 108, choke 34 is adjusted to the pressure reducing gradually in pit shaft 12.For example, by reducing the flow resistance (, by little by little opening choke) by choke 34, just can reduce the pressure of choke upstream, therefore, the pressure that is applied to ring cavity 20 on close ground reduces.
At step 112 place, detection flows becomes a mandarin.For example, use DAS or DTS with above-mentioned waveguide 88, for example just can easily detect, about flowing into sound indication or the heat indication (, as shown in Figure 6) of stream.
On the time period flowing into, measurable flow enters the pressure (for example, using sensor 60,104 etc.) in the pit shaft 12 at position, and/or for example can record, near the pressure in the ring cavity 20 on ground (, using sensor 38,40 etc.).These pressure measuring values will represent the pore pressure on the stratum 64 at inflow position.
At step 114 place, according to the needs of special drilling operation, adjust choke 34.For example, in the pressure probing of management, capable of regulating choke 34, makes pit shaft 12 internal pressures be slightly higher than the pore pressure (after choke adjustment, this pressure can be verified by lacking the inflow stream of waveguide 88 detections thereafter) on stratum 64.In drilled underbalanced, capable of regulating choke 34 to allow to control inflow flow (after choke adjustment, this flow can be verified by waveguide 88 thereafter) in drilling process.
In addition referring to Fig. 8, Fig. 8 shows the other method 130 of well system 10 structures that can be used for Fig. 4 typically with flow chart form now.Certainly, method 130 can be put into practice in other well systems, to accord with principle of the present invention.
In method 130, to survey fluid 18 and be lost to stratum 64, it shows the fracture pressure on stratum.When pit shaft 12 internal pressures at certain position are greater than the fracture pressure on stratum 64 at this position, can rupture in stratum, and fluid 18 can easily flow in stratum.
Therefore the point that, fluid 18 runs off is that pit shaft 12 internal pressures become and are greater than that point of stratum 64 fracture pressures.At fluid 18, run off on the time period, can easily record pit shaft 12 internal pressures (for example, using sensor 60,104 etc.), and for example can record easily, near the pressure in the ring cavity 20 on ground (, using sensor 38,40 etc.).
It should be noted that, pressure in the pit shaft 12 at fluid loss position can comprise the friction pressure (also referred to as equivalent circulating density) that flows and cause due to fluid 18, so, in the pit shaft of definite fluid loss position, during actual pressure, preferably consider this pressure (if present).Yet, when method 130 is implemented, not necessarily require fluid 18 to cycle through drill string 16 and ring cavity 20.On the contrary, can in method 130 implementation processes, use pump 70(to see Fig. 1) or/or stand pump 68(see Fig. 3), accommodating fluid flows through choke 34, does not allow fluid 18 cycle through drill string 16 and ring cavity 20.
At step 132 place of method 130, choke 34 is adjusted to the pressure increasing gradually in pit shaft 12.By increase, pass through the flow resistance (for example, by little by little closing choke) of choke 34, just can increase the pressure of choke upstream, therefore, near the pressure increase that is applied to ring cavity 20 on ground.
At step 134 place, survey the loss of fluid 18.For example, use DAS or DTS with above-mentioned waveguide 88, just can easily detect sound indication or the heat indication (for example, as shown in Figure 5) of about fluid 18, running off.
On the time period of running off, the pressure in the pit shaft 12 at measurable flow body loss position (for example, using sensor 60,104 etc.), and/or for example can record, near the pressure in the ring cavity 20 on ground (, using sensor 38,40 etc.).These pressure measuring values will represent the fracture pressure on the stratum 64 at fluid loss position.
At step 136 place, according to the needs of special drilling operation, adjust choke 34.For example, in the pressure probing of management, capable of regulating choke 34, makes pit shaft 12 internal pressures be slightly higher than the pore pressure (after choke adjustment, this pressure can be verified by lacking the inflow stream that waveguide 88 surveys thereafter) on stratum 64 and is less than the fracture pressure on stratum.In drilled underbalanced, capable of regulating choke 34 to allow to control inflow flow (after choke adjustment, this flow can be verified by waveguide 88 thereafter) in drilling process.
Can recognize now, above invention provides good several progress to parameter sensing technology in wellbore pressure control and drilling operation.In the example of Fig. 4, the tubular drill string 16 of coiling or other forms are continuous comprises fiber waveguide 88, and it provides sensing distribution and/or point of various parameters.Here use the continuous tubular drill string 16 with fiber waveguide 88, make drill string and fiber waveguide can move into easily and shift out pit shaft 12, when drill string each several part is connected to drill string or pulls down from drill string, without fiber waveguide being attached to drill string outside or pulling down from drill string outside.
More than the method for probing pit shaft 12 has been described in invention.The method can comprise with continuous tubular drill string 16 probing pit shafts 12, and carry out at least one parameter of sensing by the interior fiber waveguide 88 of drill string 16.
At least one parameter of sensing can comprise the parameter that sensing distributes along drill string 16.
The sound sensing (DAS) distributing, the temperature sensing (DTS) distributing, the vibration-sensing (DVS) distributing and/or the straining and sensing (DSS) distributing can be included in the sensing of at least one parameter.
The parameter of sensing can be selected from following cohort, and it comprises pressure, temperature, chemical ion, ionization radiation, pH, magnetic field and γ radiation.Certainly, can sensing any other parameter, and any quantity or the combination of parameter, to accord with principle of the present invention.
More than well system 10 has also been described in invention.This well system 10 can comprise continuous tubular drill string 16 and the fiber waveguide 88 in drill string 16.Fiber waveguide 88 can sensing along at least one parameter of drill string 16.
Should be understood that, various embodiment of the present invention as described herein can be used in various orientations and in various structure, various orientations such as that tilt, inverted, level, vertical orientation etc., and do not depart from principle of the present invention.Described various embodiment is only the example as the useful application of the principle of the invention, and the present invention is not limited to any concrete details of these embodiment.
Certainly, technician in the art, think over above to the description of exemplary embodiment of the present invention after, can easily recognize, for specific embodiment, can make many modifications, interpolation, substitute, delete and other change, so change and all can from principle of the present invention, conceive out.Therefore, should be expressly understood that above detailed description only provides by means of diagram and example, the spirit and scope of the present invention are only limited by attached claims and equivalent thereof.
Claims (30)
1. a method of drilling pit shaft, the method comprises:
With continuous tubular drill string probing pit shaft; And
By at least one parameter of fiber waveguide sensing in drill string.
2. the method for claim 1, is characterized in that, the described drill string at least bottom hole assembly from ground location to drill string is continuous.
3. the method for claim 1, is characterized in that, at least one parameter of sensing comprises the parameter that sensing distributes along drill string.
4. the method for claim 1, is characterized in that, at least one parameter of sensing comprises the sound sensing of distribution.
5. the method for claim 1, is characterized in that, at least one parameter of sensing comprises the temperature sensing of distribution.
6. the method for claim 1, is characterized in that, at least one parameter of sensing comprises the vibration-sensing of distribution.
7. the method for claim 1, is characterized in that, at least one parameter of sensing comprises the straining and sensing of distribution.
8. the method for claim 1, is characterized in that, at least one parameter is selected from following: pressure, temperature, chemical ion, ionization radiation, pH, magnetic field and γ radiation.
9. the method for claim 1, is characterized in that, also comprises adjustment choke, and thus, inducing fluid flows in pit shaft, and wherein, at least one parameter of sensing also comprises detection influx.
10. method as claimed in claim 9, is characterized in that, is also included in measuring well cylinder pressure while surveying influx, thus, makes pit shaft internal pressure and the stratum inner pore pressure correlation that intersects at pit shaft.
11. methods as claimed in claim 9, is characterized in that, also comprise in response to surveying influx and adjust choke.
12. the method for claim 1, is characterized in that, also comprise adjustment choke, and thus, inducing fluid runs off from pit shaft, and wherein, at least one parameter of sensing also comprises the loss of surveying fluid.
13. methods as claimed in claim 12, is characterized in that, are also included in measuring well cylinder pressure when surveying fluid and running off, and thus, in making pit shaft internal pressure and intersecting at the stratum of pit shaft, fracture pressure is relevant.
14. methods as claimed in claim 12, is characterized in that, also comprise in response to surveying fluid and run off to adjust choke.
15. the method for claim 1, is characterized in that, described fiber waveguide is positioned in the inner flow passage of drill string.
16. 1 kinds of well systems, comprising:
Continuous tubular drill string; And
Fiber waveguide in drill string,
Wherein, fiber waveguide sensing is along at least one parameter of drill string.
17. systems as claimed in claim 16, is characterized in that, the described drill string at least bottom hole assembly from ground location to drill string is continuous.
18. systems as claimed in claim 16, is characterized in that, at least one parameter that described fiber waveguide sensing distributes along drill string.
19. systems as claimed in claim 16, is characterized in that, described at least one parameter comprises the sound wave of distribution.
20. systems as claimed in claim 16, is characterized in that, described at least one parameter comprises the temperature of distribution.
21. systems as claimed in claim 16, is characterized in that, described at least one parameter comprises the vibration of distribution.
22. systems as claimed in claim 16, is characterized in that, described at least one parameter comprises the strain of distribution.
23. systems as claimed in claim 16, is characterized in that, at least one parameter is selected from following: pressure, temperature, chemical ion, ionization radiation, pH, magnetic field and γ radiation.
24. systems as claimed in claim 16, is characterized in that, also comprise choke, adjust choke inducing fluid and flow in pit shaft, and wherein, described at least one parameter comprises the indication of influx.
25. systems as claimed in claim 24, is characterized in that, the pit shaft internal pressure of indication influx and the stratum inner pore pressure correlation that intersects at pit shaft.
26. systems as claimed in claim 24, is characterized in that, in response to the indication of influx, adjust choke.
27. systems as claimed in claim 16, is characterized in that, also comprise choke, adjust choke inducing fluid and run off from pit shaft, and wherein, described at least one parameter comprises the indication that fluid runs off.
28. systems as claimed in claim 27, is characterized in that, the pit shaft internal pressure that indication fluid runs off to intersect at the stratum of pit shaft in fracture pressure relevant.
29. systems as claimed in claim 27, is characterized in that, choke is adjusted in the indication of running off in response to fluid.
30. systems as claimed in claim 16, is characterized in that, described fiber waveguide is positioned in the inner flow passage of drill string.
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| PCT/US2011/038838 WO2012166137A1 (en) | 2011-06-02 | 2011-06-02 | Optimized pressure drilling with continuous tubing drill string |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN103635655A true CN103635655A (en) | 2014-03-12 |
| CN103635655B CN103635655B (en) | 2016-03-30 |
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201180071386.XA Expired - Fee Related CN103635655B (en) | 2011-06-02 | 2011-06-02 | A kind of method and well system of drilling pit shaft |
Country Status (8)
| Country | Link |
|---|---|
| EP (1) | EP2715035A4 (en) |
| CN (1) | CN103635655B (en) |
| AU (1) | AU2011369403B2 (en) |
| BR (1) | BR112013030718A2 (en) |
| CA (1) | CA2837859C (en) |
| MY (1) | MY164665A (en) |
| RU (1) | RU2565299C2 (en) |
| WO (1) | WO2012166137A1 (en) |
Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103688020A (en) * | 2011-07-12 | 2014-03-26 | 哈里伯顿能源服务公司 | Formation testing in managed pressure drilling |
| US9759064B2 (en) | 2011-07-12 | 2017-09-12 | Halliburton Energy Services, Inc. | Formation testing in managed pressure drilling |
| CN109375266A (en) * | 2018-12-18 | 2019-02-22 | 清华大学 | A kind of underground water seal cave depot safety monitoring system using plagioclase distribution type fiber-optic |
| CN110382814A (en) * | 2017-01-16 | 2019-10-25 | 恩斯科国际公司 | Depressurize manifold in seabed |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| RU2661747C2 (en) * | 2013-12-17 | 2018-07-20 | Хэллибертон Энерджи Сервисиз Инк. | Distributed acoustic measurement for passive range measurement |
| GB2526255B (en) | 2014-04-15 | 2021-04-14 | Managed Pressure Operations | Drilling system and method of operating a drilling system |
| US10718204B2 (en) | 2015-06-15 | 2020-07-21 | Halliburton Energy Services, Inc. | Identifying fluid level for down hole pressure control with depth derivatives of temperature |
| RU2640844C1 (en) * | 2017-03-23 | 2018-01-12 | Федеральное государственное бюджетное учреждение науки Институт Земной коры Сибирского отделения Российской академии наук | Method for running casing string in horizontal long-distance wellbore |
| RU2649204C1 (en) * | 2017-04-13 | 2018-03-30 | Федеральное государственное бюджетное образовательное учреждение высшего образования "Кубанский государственный технологический университет" (ФГБОУ ВО "КубГТУ") | Method for drilling-in at controlled drawdown |
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- 2011-06-02 WO PCT/US2011/038838 patent/WO2012166137A1/en active Application Filing
- 2011-06-02 BR BR112013030718A patent/BR112013030718A2/en not_active IP Right Cessation
- 2011-06-02 MY MYPI2013004098A patent/MY164665A/en unknown
- 2011-06-02 EP EP11866637.9A patent/EP2715035A4/en not_active Withdrawn
- 2011-06-02 RU RU2013158132/03A patent/RU2565299C2/en not_active IP Right Cessation
- 2011-06-02 CA CA2837859A patent/CA2837859C/en not_active Expired - Fee Related
- 2011-06-02 CN CN201180071386.XA patent/CN103635655B/en not_active Expired - Fee Related
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| US20070221407A1 (en) * | 2002-11-05 | 2007-09-27 | Bostick F X Iii | Permanent downhole deployment of optical sensors |
| CN2727395Y (en) * | 2004-05-28 | 2005-09-21 | 徐凌堂 | High temperature high pressure optical waveguide well logging system |
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|---|---|---|---|---|
| CN103688020A (en) * | 2011-07-12 | 2014-03-26 | 哈里伯顿能源服务公司 | Formation testing in managed pressure drilling |
| US9759064B2 (en) | 2011-07-12 | 2017-09-12 | Halliburton Energy Services, Inc. | Formation testing in managed pressure drilling |
| CN110382814A (en) * | 2017-01-16 | 2019-10-25 | 恩斯科国际公司 | Depressurize manifold in seabed |
| CN109375266A (en) * | 2018-12-18 | 2019-02-22 | 清华大学 | A kind of underground water seal cave depot safety monitoring system using plagioclase distribution type fiber-optic |
| CN109375266B (en) * | 2018-12-18 | 2024-02-02 | 清华大学 | Underground water seal cave depot safety monitoring system adopting inclined long distributed optical fibers |
Also Published As
| Publication number | Publication date |
|---|---|
| RU2565299C2 (en) | 2015-10-20 |
| CN103635655B (en) | 2016-03-30 |
| EP2715035A1 (en) | 2014-04-09 |
| EP2715035A4 (en) | 2014-11-26 |
| WO2012166137A1 (en) | 2012-12-06 |
| AU2011369403B2 (en) | 2014-03-13 |
| BR112013030718A2 (en) | 2016-12-06 |
| CA2837859A1 (en) | 2012-12-06 |
| MY164665A (en) | 2018-01-30 |
| AU2011369403A1 (en) | 2013-11-14 |
| RU2013158132A (en) | 2015-07-20 |
| CA2837859C (en) | 2016-05-24 |
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