CN103635655B - A kind of method and well system of drilling pit shaft - Google Patents
A kind of method and well system of drilling pit shaft Download PDFInfo
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- CN103635655B CN103635655B CN201180071386.XA CN201180071386A CN103635655B CN 103635655 B CN103635655 B CN 103635655B CN 201180071386 A CN201180071386 A CN 201180071386A CN 103635655 B CN103635655 B CN 103635655B
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- 238000000034 method Methods 0.000 title claims abstract description 52
- 238000005553 drilling Methods 0.000 title description 28
- 239000000835 fiber Substances 0.000 claims abstract description 30
- 239000012530 fluid Substances 0.000 claims description 79
- 238000001514 detection method Methods 0.000 claims description 27
- 239000011148 porous material Substances 0.000 claims description 14
- 230000004941 influx Effects 0.000 claims description 10
- 230000004044 response Effects 0.000 claims description 9
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- 230000009467 reduction Effects 0.000 description 4
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Classifications
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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
-
- 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
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- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Remote Sensing (AREA)
- Mechanical Engineering (AREA)
- Electromagnetism (AREA)
- Geophysics (AREA)
- Earth Drilling (AREA)
- Geophysics And Detection Of Objects (AREA)
- Investigating Or Analysing Materials By Optical Means (AREA)
- Measuring Fluid Pressure (AREA)
Abstract
The method of probing pit shaft can comprise with continuous print tubular drill string probing pit shaft, and senses at least one parameter by the fiber waveguide in drill string.Well system can comprise the fiber waveguide in the tubular drill string of continuous print and drill string.Fiber waveguide can sense at least one parameter along drill string distribution.
Description
Technical field
The present invention relates generally to the operation of equipment and the enforcement used in conjunction with drilling well, and in embodiment described in the text, provides the probing of the optimization pressure with continuous tubular drill string particularly.
Background technology
In traditional drilling operation, the sensor in drill string surface and bottom hole assembly can be used detect the various parameters affecting drilling operation.But the parameter along drill string do not measured by sensor so, when detecting fluid inflow pit shaft or detection fluid runs off from pit shaft, the purposes of sensor like this is limited.
Therefore, should be realized that, in the detection technology of drilling operation, need improvement.These improvement can be used on situation discussed above and neutralize in other situation.
Accompanying drawing explanation
Fig. 1 is the partial sectional view of the signal of well system and the correlation technique can implementing the principle of the invention.
Fig. 2 is the block diagram of the signal of the Process Control System of the well system and method that can be used 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 that this figure comprises the instruction that fluid runs off from pit shaft along the temperature of pit shaft to the schematic graph of the degree of depth.
Fig. 6 is along the temperature of pit shaft to the schematic graph of the degree of depth, and this figure comprises the instruction that fluid flows into cylinder.
Fig. 7 is the indicative flowchart of detection influx and the method according to response adjustment choke, and the method can implement principle of the present invention.
Fig. 8 is the indicative flowchart of detection fluid number of dropouts and the method according to response adjustment choke, and the method can implement principle of the present invention.
Detailed description of the invention
What schematically show in Fig. 1 is well system 10 and the relevant method can implementing the principle of the invention.In system 10, by rotating the drill bit 14 on tubular drill string 16 end, pit shaft 12 is drilled out.
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 be formed between drill string and pit shaft 12, to cool drill bit, lubricate drill string, remove drill cuttings, and provide the measurement that bottom pressure is controlled.The flap valve of irrevocable valve 21(normally hinge type) stop drilling fluid 18 upwards to flow through drill string 16.
The control of bottom pressure in stress management and underbalance probing, and seems extremely important in the optimization pressure drilling operation of other types.Preferably, be optimized bottom pressure, to prevent the stratum 64 around excessive fluid loss to pit shaft 12, undesirable stratum breaking, undesirable formation fluid flow in pit shaft.
In typical Stress control probing, it is desirable 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, it is desirable to keep bottom pressure to be slightly less than pore pressure, thus, the fluid flowed into from stratum 64 is controlled.
Nitrogen or other gas or other lightweight fluid, can add in drilling fluid 18, to carry out Stress control.This technology such as in underbalance drilling operation, or isolation density (such as two gradient) manage pressure probing in useful especially.
In system 10, by using the control device 22(RCD rotated) close ring cavity 20(such as, isolated ring cavity is communicated with air, and can pressurize to ring cavity at ground place or near ground place), obtain the additional control to bottom pressure.This RCD22 seals around drill string 16 above well head 24.Illustrate although do not give in FIG, drill string 16 extends upward through RCD22, to be connected to such as lift line 26 and/or other traditional drilling equipment.
Drilling fluid 18 flows out well head 24 by flutter valve 28, is communicated with below this wing valve position RCD22 with ring cavity 20.Then drilling fluid 18 flow through fluid return lines 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 in the flowing of the choke run, 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 being applied to ring cavity 20 is larger.Therefore, the restriction flowing through choke by changing convection cell changes the back pressure being applied to ring cavity 20, just can regulate bottom pressure easily.As hereinafter more complete description, a hydraulic model can be used to determine that ground place or Near Ground are applied to the pressure of ring cavity 20, this pressure will cause required bottom pressure, so, operator's (or automation control system) easily can determine how to regulate ground place or Near Ground to be applied to the pressure (this pressure can be measured easily) of ring cavity, to obtain required bottom pressure.
Also can wish to control the pressure along other positions of pit shaft 12.Such as, the pressure at the casing shoe place in the substantially vertical of pit shaft 12 or horizontal component or lateral bores heel place, or the pressure at other position any, all can use principle of the present invention to be controlled.
Be applied to the pressure of ring cavity 20 by various pressure sensor 36,38,40, measure on ground or Near Ground, each sensor is communicated with ring cavity.Pressure sensor 36 to sense below RCD22 but pressure above preventer (BOP) stacking 42.Pressure sensor 38 senses the pressure below BOP in well head stacking 42.Pressure sensor 40 senses the pressure in the fluid return lines 30 of chokes collector 32 upstream.
Another pressure sensor 44 senses the pressure in lift line 26.Another pressure sensor 46 is also had to sense chokes collector 32 downstream but pressure in eliminator 48, vibrator 50 and mud pit 52 upstream.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.Such as, system 10 only can comprise in flow meter 62,66.But the input carrying out sensor can be used for hydraulic model, in order to determine it should is which pressure is applied to ring cavity 20 in drilling operation process.
In addition, drill string 16 can comprise himself sensor 60, such as, is used for direct measuring well bottom pressure.Sensor 60 so can be that type known by the technical staff in the art, and they are as the sensing system of record (LWD) when measuring (MWD) and/or probing during probing when pressure (PWD), probing.These drill string sensing systems usually provide at least pressure measxurement, and also can provide temperature survey, detection drill string feature (such as vibration, weight on bit, stick-slip etc.), stratum characteristic (such as resistivity, density etc.) and/or other measurement.Can use various forms of telemetry (sound, pressure pulse, electromagnetism, optics, wired etc.), be sent to ground by creeping into measurement value sensor downwards.Drill string 16 can be provided with conductor, fiber waveguide etc., for seeing Fig. 2 at sensor 60 and the following Process Control System 74(that will describe) between transmit data and/or instruction.
If necessary, system 10 also can comprise other sensor.Such as, another flow meter 67 can be used to measure the flow of fluid 18 flowing out well head 24, another coriolis flowmeter (not shown) can direct interconnection in the upstream of stand slush pump 68 grade or downstream.
If necessary, system 10 also can comprise less sensor.Such as, by the stroke of meter-pump instead of use traffic meter 62 or other flow meter any, the output of stand slush pump 68 is determined.
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 ").But, not necessarily to use eliminator 48 in system 10.
It is inner that drilling fluid 18 is pumped into drill string 16 by means of stand slush pump 68 by lift line 26.Pump 68 accepts fluid 18 from mud pit 52, and by not shown in standpipe collector 86(Fig. 1, can see Fig. 3) make fluid flow to lift line 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 flows to mud pit 52 by eliminator 48 and vibrator 50, for regulating and recycling.
It should be noted that, in the system 10 to described above, choke 34 can not be used for controlling the back pressure being applied to ring cavity 20 to bottom pressure enforcement control, except nonfluid 18 flows through choke.In the drilling operation of traditional overbalance, when will connect in drill string 16 (such as, along with pit shaft 12 is drilled more and more darker, the drill pipe of another length need be added on drill string), the shortage circulated will occur, and the shortage of circulation will require that density by means of only fluid 18 is to regulate bottom pressure.
But, in system 10, even if fluid does not cycle through drill string 16 and ring cavity 20, the flowing of fluid 18 by choke 34 also can be maintained.Therefore, by the flowing of limit fluid 18 by choke 34, still pressure can be applied to ring cavity 20.Such as, when drill string 16 moves into and shifts out pit shaft 12, this ability can be very useful.
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 flowing being fed to the return line 30 of chokes collector 32 upstream.As shown in Figure 1, pump 70 is connected to ring cavity 20 by BOP stacking 42, but in other instances, pump 70 can be connected to return line 30 or chokes collector 32.
Alternatively, or additionally, when needed, can as described in international patent application series No.PCT/US08/87686, as US Pat Appl Ser No.13/022, described in 964, or use other technology, make fluid can redirect to return line 30 from standpipe collector (or alternate manner ground is from stand pump 68).
Thus, choke 34, to the restriction of the fluid flowing like this from stand pump 68 and/or back pressure pump 70, causes pressure to be applied on ring cavity 20.If use back pressure pump 70, then flow meter 72 can be used to the output of measuring pump.
Choke 34 and back pressure pump 70 are examples of pressure control device, and pressure control device can be used to control the pressure in Near Ground ring cavity 20.If necessary, the pressure control device (such as international patent application series No.PCT/US08/87686 and US Pat Appl Ser No.13/022, those devices described in 964 grades) of other type can be used.
Now in addition with reference to the block diagram that an example of Process Control System 74 is schematically shown in Fig. 2, figure.In other example, Process Control System 74 can comprise other quantity, type, combination etc. of element, and any element can be positioned on different positions, or can form one, to accord with scope of the present invention with another element.
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 of international patent application series described in No.PCT/US10/56433 submitted on November 12nd, 2010.
Hydraulic model 120 is used for determining required pressure in ring cavity 20, and thus, some position in pit shaft 12 meets the requirements of pressure.Hydraulic model 120 uses the data of the revolutions per minute, translational speed, mud type etc. of such as mine shaft depth, drill string, carrys out simulation wellbore hole 12, flowing (comprising the circulating density due to the equivalence so flowed) etc. that drill string 16, fluid flow through drill string and ring cavity 20.
Data acquisition and control interface 118 receives data from various sensor 36,38,40,44,46,54,56,58,60,62,66,67,72, and together with receiving stand and creeping into data downwards, by data transfer to hydraulic model 120 and data verification device 124.In addition, the inner-ring gas pressure of the requirement from hydraulic model 120 is transferred to data verification device 124 by interface 118.
Prediction unit 122 can be included in this example, and to determine should receive which sensing data at present according to the data in past, and what the inner-ring gas pressure required should be.Prediction unit 122 can comprise neutral net, genetic algorithm, fuzzy logic etc., or any combination of prediction element, to produce prediction to the inner-ring gas pressure of sensing data and requirement.
Data verification device 124 utilizes these to predict, determines that whether the data of any special sensor are proper, whether the inner-ring gas pressure of the requirement of hydraulic model 120 output is suitable.If properly, the inner-ring gas pressure required is sent to controller 126(such as programmable logic controller by data verification device 124, it can comprise PID (PID) controller), it controls choke 34, pump 70 and various flow control apparatus 128(such as valve etc.) operation.
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.In ring cavity 20, actual pressure measures (such as, use sensor 36,38,40) usually near well head 24 place or well head 24, and well head 24 can be positioned at land or under water.
Construct with the another kind schematically illustrating well drilling system 10 typically with reference in Fig. 3, figure in addition now.In this configuration, 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, use quick connector 84(such as high pressure union etc.) interconnect.This interconnection that will flow control apparatus 76 made to be applicable to various stand pump line line easily.
In order to control the flowing flowing through lift line 26, particularly suitable full automatic flow control apparatus 76(can be used such as, one as in the flow control apparatus 128 by controller 126 Automated condtrol), 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.
Now in addition with reference to the structure representatively illustrating well system 10 in Fig. 4, figure.In this configuration, drill string 16 comprises the continuous-tube of coil pipe or other form, and it has at least one fiber waveguide 88(of extending along its length such as, optical fiber, light belt etc.).
In the diagram, waveguide 88 is illustrated as the inside Longitudinal flow channels 90 extending through drill string 16, but in other example, waveguide extensible in the sidewall of drill string, drill string is outer etc.Waveguide 88 can in the form of ring, and this ring starts at coil pipe top place to extend to bottom, turns over curvedly to turn back to surface, to improve temperature survey characteristic.
Multiple optical waveguide 88 can be provided together with the pipeline (such as, electric wire pipeline and/or waterpower pipeline etc.) of other type.Various pipeline can be brought into be had in the cable of 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 drill string 16 pipe or control in pipeline.Preferably, single mode and multi-modal fiber waveguide 88 can be provided, but this is dispensable, to accord with principle of the present invention.
Drill string 16 preferably at least from well head 24 to close bottom hole assembly (such as, include but not limited to: sensor 60, irrevocable valve 21, drill bit 14, MTR 92(are shown in Fig. 1), this motor response is in flowing through the flowing of fluid 18 of drill string and rotary drill bit etc.) be continuous print (not being such as, connect or segmentation).Fiber waveguide 88 before or after drill string is transferred in pit shaft 12, can be arranged in drill string 16.
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.
Such as, when the pressure in pit shaft 12 is greater than the fracture pressure on stratum 64, this kind of situation will be there is.Situation so can be avoided usually, but also can use (such as, being used for determining fracture pressure etc. easily) in advantages ground, and this will more completely describe hereinafter.
The right-hand side of Fig. 4 illustrates another kind of situation, and wherein, formation fluid 94 flows in pit shaft 12 from stratum 64.Such as, when the pressure in pit shaft 12 is less than the pore pressure on stratum 64, this kind of situation will be there is.
In general, in underbalance drilling operation (such as, drill time, formation fluid 94 controlledly flows in pit shaft 12), situation so is desirable, but is undesirable in the drilling operation (such as, have the pressure of management to drill, traditional overbalance probing etc.) of other types.In the technology of more complete description below, formation fluid 94 flows in pit shaft 12, can be used to the pore pressure determining stratum 64 easily.
It should be noted that, while fluid 94 flows in pit shaft 12, fluid 18 can not flow into (as shown on Fig. 4 right-hand side) in stratum 64.Therefore, the situation shown on Fig. 4 left-hand side and right-hand side can not occur simultaneously, but on the contrary, is used for generable situation of separating in display drilling operation process.
In Figure 5, for the part of the pit shaft 12 shown in Fig. 4, and the situation of the fluid loss shown on Fig. 4 left-hand side, Fig. 5 shows the representative chart 96 of temperature for the degree of depth.It should be noted that, enter the position on stratum 64 at fluid 18, detected the reduction by 98 of temperature.
The reduction by 98 of temperature is the position owing to entering stratum at fluid, and fluid 18 cools the cause on stratum 64 partly.Temperature anomaly so reduces by 98 and can be used to detection where and when there occurs fluid 18 to run off event, and can be used to the fracture pressure that determines when to reach stratum 64.
In figure 6, for the part of the pit shaft 12 shown in Fig. 4, and the situation that the fluid 94 shown on Fig. 4 right-hand side flows into, Fig. 6 shows the representative chart 100 of temperature for the degree of depth.It should be noted that, enter the position of pit shaft 12 at fluid 94, detected the rising 102 of temperature.
The rising 102 of temperature is the position owing to entering pit shaft at fluid, and fluid 94 heated the cause of pit shaft 12 partly.Temperature anomaly rising 102 so can be used to detection where and when there occurs fluid 94 flow into event, and can be used to determine when that well cylinder pressure becomes the pore pressure being less than stratum 64.
Preferably, use well-known districution temperature perception (DTS) technology, adopt fiber waveguide 88 to carry out measuring tempeature.DTS can be used to measure the technology along the Temperature Distribution of fiber waveguide 88.
The lasing light emitter of pulse can be used, send light pulse by fiber waveguide 88, the characteristic of back light can be recorded.This back light (" back scatter ") comprises the absorption of luminous energy and re-emissions.
The light of back scatter comprises different spectral components, such as, 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), and the former weakly depends on temperature, and the latter's temperature influence is very large.Relative intensity between Stokes and anti-Stokes is the function of the temperature that back scatter place occurs.
Because the speed of light in glass is known, therefore by following the tracks of the time of advent of reflection and backscattered light, the exact position that backscattered light originates from just can be determined.DTS follows the tracks of or curve (curve 96,100 of such as 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 temperature-independent, therefore, can be used for DTS.But Brillouin's backscattered light also depends on the local train in waveguide 88, so for temperature survey, may correspond to that variation amount (such as, by guaranteeing that waveguide is without undergoing strain) carries out eliminating, counteracting etc.
In the example in figure 4, fiber waveguide 88 is monitored for DTS.But, if necessary, other photo measures distributed also can be used.Such as, the sound of distribution can be used to sense (DAS), the straining and sensing (DSS) of distribution or the vibration-sensing (DVS) of distribution.
As discussed above, Raman back scatter sensing is generally used for DTS monitoring, but if necessary, Brillouin's back scatter also can be used to sense.Brillouin or rayleigh back scattering sensing can be used for DAS, DSS or DVS monitoring, preferably sense Brillouin's back scatter gain or relevant rayleigh back scattering.Also the light perception of (or alternatively) interferometry can be used.
In an example, DAS can be used to the voice signal produced sensing fluid 94 flows into (such as, fluid flows into) in pit shaft 12 during from stratum 64, or to flow into the reduction of the magnitude of sound that stratum (such as, fluid loss) is caused from pit shaft due to fluid 18.Also can (or alternatively) fiber waveguide 88 be used to measure other features (vibration, stick-slip, rotation, strain etc. of such as drill string 16) of drilling operation.
DAS can be used to the voice signal detecting the gas entering pit shaft 12 from stratum 64, and/or flows through the voice signal of gas of ring cavity 20.Such as, waveguide 88 will indicate drill string 16 to be exposed to the acoustic waves that in pit shaft 12, in gas, part weakens, so, for this purpose, the optical device being connected to waveguide can be used to detect the acoustic resonance of distribution in drill string.
This can provide gas early stage blowout detection system, thus, not only may detect inflow event, and may detect fluid and flow into position in pit shaft 12, and the position of gas and speed in ring cavity 20.Information so can allow stand personnel to make suitable adjustment in the suitable time, to make gas recycle outside pit shaft 12, and stops inflow further.
DAS can be used to detect another sound wave that another drill string (not shown) produces in pit shaft (not shown).When another drill string drills another pit shaft, waveguide 88 detects the sound wave that another drill string produces, so, easily can determine the position of another pit shaft relative to pit shaft 12, to guide pit shaft to intersect each other or to avoid intersecting.
DAS can be used to detect other events that can produce voice signal in pit shaft 12 or outside pit shaft.Such as, available waveguide 88 detection occurs in washing away in pit shaft 12.As another example, on the ground, in other pit shaft etc., the seismic origin can be caused, with the vibration of the detectable earthquake of waveguide 88.
Except the measurement of distribution, one or more sensor 104 can be used to measure to the point making characteristic.Such as, sensor 104 can comprise pressure sensor, chemical ion or pH sensor, ionizing irradiation sensor, magnetic field sensor etc.Sensor 104 can be the sensor of optics or other types, and can be connected to or be free of attachment to the part of waveguide 88, can the part of yes or no waveguide 88.
In another example, sensor 104 is not necessarily coupled to waveguide 88 to be optically.On the contrary, sensor 104 can audibly be communicated with waveguide 88.In this example, sensor 104 can launch acoustic signal, measured value can carry out modulating (such as on signal, frequency of utilization, phase place or amplitude transformation key entry etc.), acoustic signal can be accepted by waveguide 88 and (back scatter change) is sent at a distance (such as earth surface, probing stand, subsea wellheads etc.) photographically.
If necessary, additional one or more pipelines 106 can also be provided.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 change of resistivity in stratum 64.
Well-known Faraday effect in detectable waveguide 88, this effect indicates stratum 64 internal magnetic field change.In this example, drill string 16 can with compound or other nonmagnetic substances make, like this, it not disturbing magnetic field to the propagation on stratum 64, and the change of not interference detection stratum internal magnetic field.
In an example, in drilling operation process, record is carried out in available waveguide 88.Such as, waveguide 88 may detect the γ radiation sent from stratum 64.Like this, operator can know when to penetrate specific subsurface formations, when the stratum of 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 phosphorescence is provided in waveguide or the covering of fluorescence, just may detect the ionizing irradiation along waveguide 88.Different stratum can have different spectral absorption characteristics, can allow to identify and checking stratum based on these characteristics.
Although that above only describes the distribution utilizing waveguide 88 with some examples of detection technology that are point, should be expressly understood that, any quantity or the combination of any detection technology and detection technology all can be used, to accord with principle of the present invention.
The other method 108 representatively illustrating well system 10 structure that can be used for Fig. 4 see Fig. 7, Fig. 7 in flow diagram 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 in the pit shaft 12 at certain position, pressure is less than stratum 64 pore pressure at this position, pressure reduction inductively layer fluid 94 flows to and flows in pit shaft.
Therefore, the point flowing into stream beginning is that in pit shaft 12, pressure becomes that point being less than stratum 64 pore pressure.When inflow and outflow so is current, easily can record pressure in pit shaft 12 (such as, using sensor 60,104 etc.), and the pressure (such as, using sensor 38,40 etc.) in the ring cavity 20 on ground can be recorded easily.
It should be noted that, pressure in the pit shaft 12 flowing into position can comprise because fluid 18 flows the friction pressure (also referred to as equivalent circulating density) caused, so, when determining to flow into actual pressure in the pit shaft of position, preferably consider this pressure (if present).But, when method 108 is implemented, not necessarily require that fluid 18 cycles through drill string 16 and ring cavity 20.On the contrary, can pump 70(be used to see Fig. 1 in method 108 implementation process) 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 reduced gradually in pit shaft 12.By being reduced by the flow resistance (such as, by little by little opening choke) of choke 34, just can reduce the pressure of choke upstream, therefore, the pressure being applied to ring cavity 20 near ground reduces.
In step 112 place, detection flows becomes a mandarin.Such as, using DAS or DTS of the above-mentioned waveguide 88 of band, just easily can detecting sound instruction or heat instruction (such as, as shown in Figure 6) about flowing into stream.
On the time period flowed into, measurable flow enters the pressure (such as, using sensor 60,104 etc.) in the pit shaft 12 at position, and/or can record the pressure (such as, using sensor 38,40 etc.) in the ring cavity 20 on ground.These pressure measuring values will represent the pore pressure on the stratum 64 flowing into position.
In step 114 place, according to the needs of special drilling operation, adjustment choke 34.Such as, in the pressure probing of management, adjustable choke 34, makes slight pressure in pit shaft 12 higher than the pore pressure (after choke adjustment, this pressure can be verified by lacking inflow stream that waveguide 88 detect thereafter) on stratum 64.In drilled underbalanced, adjustable choke 34 to allow control flow check inbound traffics (after choke adjustment, this flow can be verified by waveguide 88 thereafter) in drilling process.
The other other method 130 representatively illustrating well system 10 structure that can be used for Fig. 4 see Fig. 8, Fig. 8 in flow diagram 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, detection fluid 18 is lost to stratum 64, and it shows the fracture pressure on stratum.When in the pit shaft 12 at certain position, pressure is 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 in pit shaft 12, pressure becomes that point being greater than stratum 64 fracture pressure.Run off on the time period at fluid 18, easily can record pressure in pit shaft 12 (such as, using sensor 60,104 etc.), and the pressure (such as, using sensor 38,40 etc.) in the ring cavity 20 on ground can be recorded easily.
It should be noted that, pressure in the pit shaft 12 at fluid loss position can comprise because fluid 18 flows the friction pressure (also referred to as equivalent circulating density) caused, so, when determining actual pressure in the pit shaft of fluid loss position, preferably consider this pressure (if present).But, when method 130 is implemented, not necessarily require that fluid 18 cycles through drill string 16 and ring cavity 20.On the contrary, can pump 70(be used to see Fig. 1 in method 130 implementation process) 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 increased gradually in pit shaft 12.By increasing the flow resistance (such as, by little by little closing choke) by choke 34, just can increase the pressure of choke upstream, therefore, the pressure being applied to ring cavity 20 near ground increases.
In step 134 place, the loss of detection fluid 18.Such as, use DAS or DTS of the above-mentioned waveguide 88 of band, just easily can detect the sound instruction or heat instruction (such as, as shown in Figure 5) of running off about fluid 18.
On the time period of running off, the pressure (such as, using sensor 60,104 etc.) in the pit shaft 12 at measurable flow body loss position, and/or the pressure (such as, using sensor 38,40 etc.) in the ring cavity 20 on ground can be recorded.These pressure measuring values will represent the fracture pressure on the stratum 64 at fluid loss position.
In step 136 place, according to the needs of special drilling operation, adjustment choke 34.Such as, in the pressure probing of management, adjustable choke 34, makes slight pressure in pit shaft 12 higher than the pore pressure (after choke adjustment, this pressure can be verified by lacking inflow stream that waveguide 88 detect thereafter) on stratum 64 and is less than the fracture pressure on stratum.In drilled underbalanced, adjustable choke 34 to allow control flow check inbound traffics (after choke adjustment, this flow can be verified by waveguide 88 thereafter) in drilling process.
Can recognize now, above invention controls wellbore pressure and in drilling operation, parameter sensing technology has provided several progress.In the example in figure 4, coil or the tubular drill string 16 of other form continuous print comprises fiber waveguide 88, sensing that is that it provides the distribution of various parameter and/or that put.Here the tubular drill string 16 of continuous print with fiber waveguide 88 is used, make drill string and fiber waveguide can move into and shift out pit shaft 12 easily, when drill string each several part is connected to drill string or pulls down from drill string, pull down without the need to fiber waveguide being attached to outside drill string or outside drill string.
More than invention describes the method for probing pit shaft 12.The method can comprise drills pit shaft 12 with the tubular drill string 16 of continuous print, and senses at least one parameter by fiber waveguide 88 in drill string 16.
Drill string 16 can at least from ground location to drill string the bottom hole assembly of 16 be all continuous print.
Sense at least one parameter and can comprise the parameter of sensing along drill string 16 distribution.
Sound sensing (DAS) of distribution, the temperature sensing (DTS) of distribution, the vibration-sensing (DVS) of distribution and/or the straining and sensing (DSS) of distribution 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, ionizing irradiation, pH, magnetic field and γ radiation.Certainly, any other parameter can be sensed, and any quantity of parameter or combination, to accord with principle of the present invention.
Method 108 can comprise adjustment choke 34, and thus, inducing fluid 94 flows in pit shaft 12, and senses at least one parameter and can comprise detection influx.The method 108 also can comprise the pressure in the pit shaft 12 when measuring detection influx, thus, makes pressure and the stratum 64 inner pore pressure correlation intersecting at pit shaft 12 in pit shaft 12.The method 108 also can comprise detection in response to influx to adjust choke 34.
Method 130 can comprise adjustment choke 34, and thus, inducing fluid 18 runs off from pit shaft 12, and senses at least one parameter and can comprise and detect the loss of fluid 18.The method 130 also can comprise the pressure in the pit shaft 12 when measurement detection fluid 18 runs off, and thus, makes pressure in pit shaft 12 relevant to fracture pressure in the stratum 64 intersecting at pit shaft 12.The method 130 also can comprise in response to fluid 18 run off detection to adjust choke 34.
Fiber waveguide 88 can be positioned in drill string 16 inner flow passage 90.
More than invention also describes well system 10.This well system 10 can comprise the fiber waveguide 88 in the tubular drill string 16 of continuous print and drill string 16.Fiber waveguide 88 can sense at least one parameter along drill string 16.
Should be understood that, various embodiment of the present invention as described herein can be used in various orientation and in various structure, that various orientation such as tilts, inverted, level, vertical orientation etc., and does not depart from principle of the present invention.Described various embodiments are only the examples of the useful application as the principle of the invention, and the present invention is not limited to any concrete details of these embodiments.
Certainly, technician in the art, after thinking over the above description to representative embodiment of the present invention, can easily recognize, can make many amendments, interpolation for specific embodiment, substitute, delete and other change, change so all can conceive out from principle of the present invention.Therefore, should be expressly understood that above description in detail 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 (28)
1. drill a method for pit shaft, the method comprises:
With continuous print tubular drill string probing pit shaft;
Sense at least one parameter by the fiber waveguide in drill string, sensing comprises along the scattering of described fiber waveguide detection optical back; And
Adjustment choke, thus, inducing fluid flows in pit shaft, wherein, senses at least one parameter and also comprises detection influx.
2. the method for claim 1, is characterized in that, the bottom hole assembly of described drill string at least from ground location to drill string is continuous print.
3. the method for claim 1, is characterized in that, senses at least one parameter and comprises the parameter of sensing along drill string distribution.
4. the method for claim 1, is characterized in that, senses the sound sensing that at least one parameter comprises distribution.
5. the method for claim 1, is characterized in that, senses the temperature sensing that at least one parameter comprises distribution.
6. the method for claim 1, is characterized in that, senses the vibration-sensing that at least one parameter comprises distribution.
7. the method for claim 1, is characterized in that, senses the straining and sensing that at least one parameter comprises distribution.
8. the method for claim 1, is characterized in that, at least one parameter is selected from following: pressure, temperature, chemical ion, ionizing irradiation, pH, magnetic field and γ radiation.
9. the method for claim 1, is characterized in that, is also included in measuring well cylinder pressure when detecting influx, wherein, and well cylinder pressure and the stratum inner pore pressure correlation intersecting at pit shaft.
10. the method for claim 1, is characterized in that, also comprises in response to detection influx to adjust described choke.
11. the method for claim 1, is characterized in that, also comprise the described choke of adjustment, thus, inducing fluid runs off from pit shaft, wherein, sense the loss that at least one parameter also comprises detection fluid.
12. methods as claimed in claim 11, is characterized in that, be also included in measuring well cylinder pressure when detecting fluid loss, wherein, well cylinder pressure is relevant to fracture pressure in the stratum intersecting at pit shaft.
13. methods as claimed in claim 11, is characterized in that, also comprise in response to detection fluid loss to adjust described choke.
14. the method for claim 1, is characterized in that, described fiber waveguide is positioned in the inner flow passage of drill string.
15. 1 kinds of well systems, comprising:
The tubular drill string of continuous print;
Fiber waveguide in drill string; And
Choke,
Wherein, fiber waveguide is by sensing at least one parameter along drill string along the scattering of described fiber waveguide detection optical back, adjust described choke inducing fluid and flow in pit shaft, wherein, at least one parameter described comprises the instruction of influx.
16. systems as claimed in claim 15, it is characterized in that, the bottom hole assembly of described drill string at least from ground location to drill string is continuous print.
17. systems as claimed in claim 15, is characterized in that, described fiber waveguide sensing is along at least one parameter of drill string distribution.
18. systems as claimed in claim 15, it is characterized in that, at least one parameter described comprises the sound wave of distribution.
19. systems as claimed in claim 15, it is characterized in that, at least one parameter described comprises the temperature of distribution.
20. systems as claimed in claim 15, it is characterized in that, at least one parameter described comprises the vibration of distribution.
21. systems as claimed in claim 15, it is characterized in that, at least one parameter described comprises the strain of distribution.
22. systems as claimed in claim 15, it is characterized in that, at least one parameter is selected from following: pressure, temperature, chemical ion, ionizing irradiation, pH, magnetic field and γ radiation.
23. systems as claimed in claim 15, is characterized in that, well cylinder pressure and the stratum inner pore pressure correlation intersecting at pit shaft of instruction influx.
24. systems as claimed in claim 15, is characterized in that, in response to the instruction of influx, adjust described choke.
25. systems as claimed in claim 15, is characterized in that, adjust described choke inducing fluid and run off from pit shaft, wherein, at least one parameter described comprises the instruction of fluid loss.
26. systems as claimed in claim 25, is characterized in that, the well cylinder pressure of instruction fluid loss is relevant to fracture pressure in the stratum intersecting at pit shaft.
27. systems as claimed in claim 25, is characterized in that, in response to the instruction of fluid loss, adjust described choke.
28. systems as claimed in claim 15, it 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 CN103635655A (en) | 2014-03-12 |
| CN103635655B true CN103635655B (en) | 2016-03-30 |
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| 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) |
Families Citing this family (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US8783381B2 (en) | 2011-07-12 | 2014-07-22 | Halliburton Energy Services, Inc. | Formation testing in managed pressure drilling |
| BR112014000553B8 (en) * | 2011-07-12 | 2021-02-17 | Halliburton Energy Services Inc | method of testing a soil formation |
| US20160259079A1 (en) * | 2013-12-17 | 2016-09-08 | Halliburton Energy Services Inc. | Distributed Acoustic Sensing for Passive Ranging |
| GB2526255B (en) | 2014-04-15 | 2021-04-14 | Managed Pressure Operations | Drilling system and method of operating a drilling system |
| WO2016204725A1 (en) | 2015-06-15 | 2016-12-22 | Halliburton Energy Services, Inc. | Application of depth derivative of distributed temperature survey (dts) to identify fluid level as a tool of down hole pressure control |
| US10538986B2 (en) * | 2017-01-16 | 2020-01-21 | Ensco International Incorporated | Subsea pressure reduction manifold |
| 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 |
| 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 |
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| US20070221407A1 (en) * | 2002-11-05 | 2007-09-27 | Bostick F X Iii | Permanent downhole deployment of optical sensors |
| CN101975057A (en) * | 2010-10-28 | 2011-02-16 | 华东理工大学 | Real-time control drilling and production system for deep and ultra-deep wells |
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| US3905010A (en) * | 1973-10-16 | 1975-09-09 | Basic Sciences Inc | Well bottom hole status system |
| RU2199006C2 (en) * | 2001-03-30 | 2003-02-20 | Общество с ограниченной ответственностью "Кубаньгазпром" | Device for drilling of inclined and horizontal wells |
| EA006928B1 (en) * | 2002-08-15 | 2006-04-28 | Шлюмбергер Текнолоджи Б.В. | Use of distributed temperature sensors during wellbore treatments |
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| US7597142B2 (en) * | 2006-12-18 | 2009-10-06 | Schlumberger Technology Corporation | System and method for sensing a parameter in a wellbore |
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2011
- 2011-06-02 AU AU2011369403A patent/AU2011369403B2/en not_active Ceased
- 2011-06-02 MY MYPI2013004098A patent/MY164665A/en unknown
- 2011-06-02 CN CN201180071386.XA patent/CN103635655B/en not_active Expired - Fee Related
- 2011-06-02 WO PCT/US2011/038838 patent/WO2012166137A1/en active Application Filing
- 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 BR BR112013030718A patent/BR112013030718A2/en not_active IP Right Cessation
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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 |
| CN101975057A (en) * | 2010-10-28 | 2011-02-16 | 华东理工大学 | Real-time control drilling and production system for deep and ultra-deep wells |
Also Published As
| Publication number | Publication date |
|---|---|
| RU2565299C2 (en) | 2015-10-20 |
| WO2012166137A1 (en) | 2012-12-06 |
| EP2715035A4 (en) | 2014-11-26 |
| AU2011369403A1 (en) | 2013-11-14 |
| CA2837859C (en) | 2016-05-24 |
| BR112013030718A2 (en) | 2016-12-06 |
| CA2837859A1 (en) | 2012-12-06 |
| MY164665A (en) | 2018-01-30 |
| EP2715035A1 (en) | 2014-04-09 |
| AU2011369403B2 (en) | 2014-03-13 |
| CN103635655A (en) | 2014-03-12 |
| RU2013158132A (en) | 2015-07-20 |
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