EP0897454B1 - Systeme de manutention de fluides en boucle fermee utilise au cours du forage de puits - Google Patents
Systeme de manutention de fluides en boucle fermee utilise au cours du forage de puits Download PDFInfo
- Publication number
- EP0897454B1 EP0897454B1 EP97922650A EP97922650A EP0897454B1 EP 0897454 B1 EP0897454 B1 EP 0897454B1 EP 97922650 A EP97922650 A EP 97922650A EP 97922650 A EP97922650 A EP 97922650A EP 0897454 B1 EP0897454 B1 EP 0897454B1
- Authority
- EP
- European Patent Office
- Prior art keywords
- fluid
- pressure
- vessel
- oil
- water
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Lifetime
Links
- 238000005553 drilling Methods 0.000 title claims description 27
- 239000012530 fluid Substances 0.000 claims description 76
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 49
- 239000007789 gas Substances 0.000 claims description 23
- 239000007787 solid Substances 0.000 claims description 20
- 238000007599 discharging Methods 0.000 claims description 8
- 239000000470 constituent Substances 0.000 claims description 7
- 239000003921 oil Substances 0.000 claims description 7
- 238000000926 separation method Methods 0.000 claims description 6
- 238000000034 method Methods 0.000 claims description 2
- 230000015572 biosynthetic process Effects 0.000 description 9
- 238000005755 formation reaction Methods 0.000 description 9
- 239000007788 liquid Substances 0.000 description 8
- 238000005520 cutting process Methods 0.000 description 4
- 239000010802 sludge Substances 0.000 description 4
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 230000037380 skin damage Effects 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 230000004913 activation Effects 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 230000000996 additive effect Effects 0.000 description 1
- 230000006378 damage Effects 0.000 description 1
- 238000013479 data entry Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000002500 effect on skin Effects 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 230000009545 invasion Effects 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 238000011144 upstream manufacturing Methods 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/06—Arrangements for treating drilling fluids outside the borehole
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
- E21B21/085—Underbalanced techniques, i.e. where borehole fluid pressure is below formation pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/14—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using liquids and gases, e.g. foams
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
Definitions
- This invention relates to a fluid-handling system for use in drilling of wellbores.
- wellbores are drilled utilizing a rig.
- a fluid comprising water and suitable additive, usually referred to in the art as "mud,” is injected under pressure through a tubing having a drill bit which is rotated to drill the wellbores.
- the pressure in the wellbore is maintained above the formation pressure to prevent blowouts.
- the mud is circulated from the bottom of the drill bit to the surface.
- the circulating fluid reaching the surface comprises the fluid pumped downhole and drill cuttings. Since the fluid pressure in the wellbore is greater than the formation pressure, it causes the mud to penetrate into or invade the formations surrounding the wellbore.
- Such mud invasion reduces permeability around the wellbore and reduces accuracy of measurements-while-drilling devices commonly used during drilling of the wellbores.
- Such wellbore damage also known as the skin damage or effect
- the skin damage results in a decrease in hydrocarbon productivity.
- a number of manually controlled valves are utilized to maintain the desired pressure in the separator and to discharge the fluids from the pressure vessel.
- These prior art systems also utilize manually controlled emergency shut down valves to shut down the drilling operations. Additionally, these systems rely upon pressure measured at the wellhead to control the mud pressure downhole. In many cases this represents a great margin of error.
- These prior art fluid-handling systems require the use of high pressure vessels, which are (a) relatively expensive and less safe than low pressure vessels, (b) relatively inefficient, and (c) require several operators to control the fluid-handling system.
- the flow from the mainfold is directed to a pressurized separator vessel, in which the gas rises to the top and is removed through a flow rate meter and a back pressure control valve while separated oil is removed through the valve controlled by a liquid level control.
- the remaining fluids in the pressurized separator which are primarily drilling fluids, are removed through the valve controlled by a liquid level control.
- These drilling fluids flow into a further separation vessel where the pressure is reduced to atmospheric pressure. Any gas released in said further separation vessel is removed by mixing with large volume of air, while fluids and particular matter are separated and withdrawn separately from said further vessel.
- the present invention addresses the above-noted deficiencies of the prior art fluid-handling systems and provides a relatively low pressure fluid-handling system which utilizes remotely controlled fluid flow control devices and pressure control devices, along with other sensors to control the separation of the constituents of the wellstream.
- the system includes a first vessel which acts a four phase separator.
- the first vessel includes a first stage for separating solids. Oil and gas are separated at a second stage into separate reservoirs.
- a pressure sensor associated with the first vessel provides a signal to a pressure controller which modulates a gas flow valve coupled to the vessel for discharging gas from the first vessel.
- the pressure controller maintains the pressure in the first vessel at a predetermined value.
- An oil level sensor placed in the first vessel provides a signal to an oil level controller.
- the oil level controller modulates an oil flow valve coupled to the vessel to discharge oil from the first vessel into a second vessel.
- the oil level controller operates the oil flow valve so as to maintain the oil level in the first vessel at a predetermined level.
- water fluid that is substantially free of oil and solids
- a third vessel Water from the third vessel is discharged via a water flow control valve, which is modulated by a level controller as a function of the water level in the third vessel.
- Any gas in the third vessel is discharged by modulating a gas control valve as a function of the pressure in the third vessel.
- a central control unit or circuit is utilized to control the operations of all the flow valves. Signals from the pressure sensors and level sensors are fed to the control unit, which controls the operations of each of the flow control valves based on the signals received from the various sensor and in accordance with programmed instructions. During operations, the control unit maintains the pressure in each of the vessels at their respective predetermined values. The control unit also maintains the fluid levels in each of the vessels at their respective predetermined values.
- the fluid handling system of the present invention provides a closed loop fluid handling system which automatically separates the wellstream into its constituent parts, discharges the separated constituent parts into their desired storage facilities.
- the system also automatically controls the pressure in the wellbore as a function of selected operating parameters.
- the above-described system requires substantially less manpower to operate in contrast to known fluid-handling systems utilized during underbalanced drilling of wellbores.
- the pressure in the main separator 110 is relatively low compared to known prior art systems, which typically operate at a pressure of more than 70 bar (1000 psi). Low pressure operations reduce the costs associated with manufacture of separators. More importantly, the low pressure operations of the present system are inherently safer that the relatively high pressure operations of the prior art systems.
- the control of the wellhead pressure mix based on the downhole measurements during the drilling operations provides more accurate control of the pressure in the wellbore.
- FIG. 1 shows a schematic of a fluid handling system according to the present invention.
- FIG. 1A shows a functional block diagram of a control system for use with the system of FIG. 1 for controlling the operation of the fluid handling system.
- FIG. 1 shows a schematic of a fluid-handling system 100 according to the present invention.
- a drilling fluid also referred to as the "mud”
- the fluid returning from the wellbore annulus typically contains the drilling fluid originally injected into the wellbore, oil, water and gas from the formations, and drilled cuttings produced by the drilling of the wellbore.
- the wellstream passes from a wellhead equipment 101 through a choke valve 102 which is duty-cycled at a predetermined rate.
- a second choke valve 104 remains on one hundred percent (100%) standby.
- the duty-cycled valve 102 is electrically controlled so as to maintain a predetermined back pressure.
- the wellstream then passes through an emergency shut-down valve ("ESD") 106 via a suitable line 108 into a four phase separator (primary separator) 110 .
- ESD emergency shut-down valve
- the choke valve 102 creates a predetermined pressure drop between the wellhead equipment 110 and the primary separator 110 and discharges the wellstream into the primary vessel at a relatively low pressure, typically less than 7 bar (100 psi). In some applications, it may be desirable to utilize more that one choke valve in series to obtain a sufficient pressure drop.
- Such choke valves are then preferably independently and remotely controlled as explained in more detail later.
- the primary separator 110 preferably is a four phase separator.
- the wellstream entering into the separator 110 passes to a first stage of the separator 110 .
- Solids (sludge), such as drilled cuttings, present in the wellstream are removed in the first stage by gravity forces that are aided by centrifugal action of an involute entry device 112 placed in the separator 110 .
- Such separation devices 112 are known in the art and, thus, are not described in detail. Any other suitable device also may be utilized to separate the solids from the wellstream.
- the solids being heavier than the remaining fluids collect at the bottom of the primary separator 100 and are removed by a semi-submersible sludge pump 114 .
- FIG. 1A shows a control system 200 having a control unit or control circuit 201 , which receives signals from a variety of sensors associated with the fluid-handling system 100 , determines a number of operating parameters and controls the operation of the fluid-handling system 100 according to programmed instruction and models provided to the control unit 201 .
- the operation of the control system 200 is described in more detail later.
- the fluid that is substantially free of solids passes to a second stage, which is generally denoted herein by numeral 116 .
- the second stage 116 essentially acts as a three phase separator to separate gas, oil and water present in the fluids entering the second stage.
- the gas leaves the separator 110 via a control valve 120 and line 122 .
- the gas may be flared or utilized in any other manner.
- a pressure sensor 118 placed in the separator 110 and coupled to the control unit 201 is used to continually monitor the pressure in the separator 110 .
- the control unit 201 adjusts the control valve 120 so as to maintain the pressure in the vessel 110 at a predetermined value or within a predetermined range.
- a signal from the pressure sensor 118 may be provided to a pressure controller 118a , which in turn modulates the control valve 120 to maintain the pressure in the separator at a predetermined value.
- Both a high and a low pressure alarm signals are also generated from the pressure sensor 118 signal.
- two pressure switches may be utilized, wherein one switch is set to provide a high pressure signal and the other to provide a low pressure signal.
- the control unit 201 activates an alarm 210 (FIG. 1a) when the pressure in the separator is either above the high level or when it falls below the low level.
- the control unit 201 may also be programmed to shut down the system 100 when the pressure in the separator is above a predetermined maximum level (“high-high”) or below a predetermined minimum level (“low-low”).
- the system 100 may be shut down upon the activation of pressure switches placed in the separator, wherein one such switch is activated at the high-high pressure and another switch is activated at the low-low pressure.
- the high-high pressure trip protects against failure of the upstream choke valves 102 and 104
- the low-low trip protects the system against loss of containment within the vessel 110 .
- the oil contained in the fluid at the second stage 116 collects in a bucket 124 placed in the second stage 116 of the separator 110 .
- a level sensor 126 associated with the bucket 124 is coupled to the control unit 201 , which determines the level of the oil in the bucket 124 .
- the control unit 201 controls a valve 128 to discharge the oil from the separator 110 into an oil surge tank 160 .
- the level sensor 126 may provide a signal to a level controller 126a , which modulates the control valve 128 to control the oil flow from the bucket 124 into the oil surge tank 160 .
- the oil level sensor signals also may be used to activate alarms 210 when the oil level is above a maximum level or below a minimum level.
- fluid that is substantially free of oil flows under the oil bucket 124 and then over a weir 134 and collects into a water chamber or reservoir 136 .
- a level sensor 138 is placed in the water reservoir 136 and is coupled to the control unit 201 , which continually determines the water level in the reservoir 136 .
- the control unit 201 is programmed to control a valve 140 to discharge the water from the separator 110 into a water tank 145 via a line 142 .
- the level sensor 138 may provide a signal to a level controller 138a which modulates the control valve 140 to discharge the water from the separator 110 into the water tank 145 .
- the liquid level in the main body of the separator is monitored by a level switch 142' which provides a signal when the liquid level in the main body of the separator 110 is above a maximum level, which signal initiates the emergency shut down.
- This emergency shut down prevents any liquid passing into the gas vent 122a or into any flare system used.
- Any gas present in the water discharged into the water tank 145 separates within the water tank 145 . Such gas is discharged via a control valve 147 to flare.
- a pressure sensor 148 associated with the water tank 145 is utilized to control the control valve 147 to maintain a desired pressure in the water tank 145 .
- the control valve 147 may be modulated by a pressure controller 148a in response to signals from the pressure sensor 148 .
- the control valve 147 may be controlled by the control unit 201 in response to the signals from the pressure sensor 148 .
- Alarms are activated when the pressure in the water tank 145 is above or below predetermined limits. Water level in the water tank 145 is monitored by a level sensor 150 .
- a level controller 150a modulates a control valve 152 in response to the level sensor signals to maintain a desired liquid level in the water tank 145 .
- control unit 201 may be utilized to control the valve 152 in response to the level sensor signals.
- the fluid level in the water tank 145 also is monitored by a level switch 151 , which initiates an emergency shutdown of the system if the level inadvertently reaches a predetermined maximum level.
- a pump 155 passes the fluids from the water tank 145 to the control valve 152 .
- the fluid leaving the valve 152 discharges via a line 153 into a drilling fluid tank 154 .
- Any gas present in the oil surge tank 160 separates within the oil surge tank 160 .
- the separated gas is discharged via a control valve 164 and a line 165 to the gas line 122 to flare.
- a pressure sensor 162 associated with the oil surge tank 160 is utilized to control the control valve 164 in order to maintain a desired pressure in the oil surge tank 160 .
- the control valve 164 may be modulated by a pressure controller 162a in response to signals from the pressure sensor 162 .
- the operation of the control valve 164 may be controlled by the control unit 201 in response to the signals from the pressure sensor 162 .
- Alarms 210 are activated when the pressure in the oil surge tank 160 is either above or below their respective predetermined limits. Oil level in the oil surge tank 160 is monitored by a level sensor 168 .
- a level controller 168a modulates a control valve 170 in response to the level sensor signals to maintain a desired liquid level in the oil surge tank 160 .
- the control unit 201 may be utilized to control the valve 170 in response to the signals from the level sensor 168 .
- the liquid level in the oil surge tank 160 also is monitored by a level switch 169 , which initiates an emergency shutdown of the system if the level inadvertently reaches a predetermined maximum level.
- a pump 172 passes the fluids from the oil surge tank 160 to the control valve 170 .
- the fluid leaving the valve 170 discharges via a line 174 into an oil tank or oil reservoir 176 .
- control unit 201 may be placed at a suitable place in the field or in a control cabin having other control equipment for controlling the overall operation of the drilling rig used for drilling the wellbore.
- the control unit 201 is coupled to one or more monitors or display screens 212 for displaying various parameters relating to the fluid-handling system 100 .
- Suitable data entry devices such as touch-screens or keyboards are utilized to enter information and instructions into the control unit 201 .
- the control unit 201 contains one or more data processing units, such as a computer, programs and models for operating the fluid-handling system 100 .
- control unit 201 receives signals from the various sensors described above and any other sensors associated with the fluid-handling system 100 or the drilling system.
- the control unit 201 determines or computes the values of a number of operating parameters of the fluid-handling system and controls the operation of the various devices based on such parameters according to the programs and models provided to the control unit 201 .
- the ingoing or input lines S 1 -S n connected to the control unit 201 indicate that the control unit 201 receives signals and inputs from various sources, including the sensors of the system 100 .
- the outgoing or output lines C 1 -C m are shown to indicate that the control unit 201 is coupled to the various devices in the system 201 for controlling the operations of such devices, including the control valves 102 , 104 , 120 , 128 147 , 152 , 64 , 168 and 170 , and pumps 124, 155 and 170 .
- an operator stationed at the control unit 201 which is preferably placed at a safe distance from the fluid-handling system 100 , enters desired control parameters, including the desired levels or ranges of the various parameters, such as the fluid levels and pressure levels.
- desired control parameters including the desired levels or ranges of the various parameters, such as the fluid levels and pressure levels.
- the control unit 201 starts to control the flow of the wellstream from the wellbore 225 by controlling the valves 102 and 104 so as to maintain a desired back pressure.
- the control unit 201 also controls the pressure in the separator 110 , the fluid levels in the separator 110 and each of the tanks 145 and 160 , the discharge of solids from the separator 110 and the discharge of the gases and fluids from the tanks 145 and 170 .
- the present system includes a pressure sensor for measuring the pressure at the wellhead 101 , a pressure sensor in the drill string for measuring the pressure of the drilling fluid in the drill string and a pressure sensor in the drill string for measuring the pressure in the annulus between the drill string and the wellbore.
- a pressure sensor for measuring the pressure at the wellhead 101
- a pressure sensor in the drill string for measuring the pressure of the drilling fluid in the drill string
- a pressure sensor in the drill string for measuring the pressure in the annulus between the drill string and the wellbore.
- Other types of sensors such as differential pressure sensors, may also be utilized for determining the differential pressures downhole.
- control unit 201 periodically or continually monitors the pressures from the sensors and controls the fluid flow rate into the wellbore by controlling so as to maintain the wellbore pressure at a predetermined value or within a predetermined range.
- the drill string may also include other sensors, such as a temperature sensor, for measuring the temperature in the wellbore.
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- Environmental & Geological Engineering (AREA)
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Claims (16)
- Système (100) de manutention de fluide utilisant une cuve (110) pour séparer les constituants d'un fluide de puits de forage revenant à la surface pendant le forage d'un puits, ladite cuve (110) comprenant :(a) un premier étage (112) pour séparer les solides contenus dans le fluide de puits de forage ;(b) un dispositif (118) de détection de pression pour déterminer la pression dans la cuve (110) ;(c) un dispositif (120) de commande d'écoulement de gaz pour décharger du gaz de la cuve (110) ; et(d) un dispositif (118a) de commande de pression pour commander automatiquement le fonctionnement du dispositif (120) de commande d'écoulement de gaz de manière à maintenir la pression dans la cuve (110) à une valeur prédéterminée ou à l'intérieur d'une plage prédéterminée.
- Système de manutention de fluide selon la revendication 1, dans lequel le dispositif (118a) de commande de pression module le dispositif (120) de commande d'écoulement de gaz de manière à commander la décharge du gaz hors de la cuve (110).
- Système de manutention de fluide selon la revendication 1 ou 2, dans lequel le dispositif (118) de détection de pression est un capteur de pression ou un pressostat.
- Système de manutention de fluide selon l'une des revendications 1 à 3, comprenant en outre un deuxième étage (116) pour séparer l'huile et l'eau présentes dans le fluide de puits de forage.
- Système de manutention de fluide de selon l'une des revendications 1 à 4, comprenant en outre un circuit de commande (201) qui commande un dispositif (102, 104) d'entrée de fluide pour réguler la pénétration du fluide de puits de forage dans la cuve (110) en réponse au signal provenant du dispositif (118) de détection de pression.
- Système (100) de manutention de fluide utilisant une cuve (110) pour séparer les constituants d'un fluide de puits de forage revenant à la surface pendant le forage d'un puits, comprenant :(a) un premier étage (112) pour séparer les solides contenus dans le fluide;(b) un dispositif (118) de détection de pression pour déterminer la pression dans la cuve (110) ;(c) un deuxième étage (116) pour séparer l'huile et l'eau et les envoyer dans un réservoir à eau (136) et un réservoir à huile (124) ;(d) des détecteurs de niveau (138, 126) séparés, associés au réservoir à eau (136) et au réservoir à huile (124), pour déterminer respectivement le niveau d'eau et le niveau d'huile dans les réservoirs (136, 124) respectifs ; et(e) un circuit de commande, ledit circuit de commande (201) recevant des signaux du dispositif (118) de détection de pression et de chacun des détecteurs de niveau (126, 138) pour, en réponse à ces signaux, commander la pression, le niveau d'huile et le niveau d'eau dans la cuve (110).
- Système de manutention de fluide selon la revendication 6, comprenant en outre une pompe (114) servant à décharger les solides hors de la cuve (110).
- Système de manutention de fluide selon la revendication 6 ou 7, comprenant en outre un dispositif (120) de commande d'écoulement de gaz associé à la cuve (110) pour décharger le gaz hors de la cuve (110).
- Système de manutention de fluide selon l'une des revendications 6 à 8, comprenant en outre un premier dispositif (128) de commande d'écoulement associé à la cuve (110) pour décharger l'huile hors de la cuve (110).
- Système de manutention de fluide selon l'une des revendications 6 à 9, comprenant en outre un deuxième dispositif (140) de commande d'écoulement associé à la cuve (110) pour décharger l'eau hors de la cuve (110).
- Système de manutention de fluide selon l'une des revendications 6 à 10, dans lequel le circuit de commande (201) commande l'écoulement de gaz hors de la cuve (110) de manière à maintenir la pression dans la cuve (110) à l'intérieur d'une plage prédéterminée.
- Système de manutention de fluide selon l'une des revendications 6 à 11, dans lequel le circuit de commande (201) commande la décharge de l'huile et de l'eau hors de la cuve (110) de manière à maintenir le niveau d'huile et le niveau d'eau dans la cuve (110) en deçà de leur limite prédéterminée respective.
- Système de manutention de fluide selon la revendication 12, dans lequel le circuit de commande (201) commande la décharge de l'huile et de l'eau en commandant des vannes (128, 140) séparées de commande d'écoulement associées respectivement à l'eau et à l'huile.
- Procédé de séparation des solides, de l'huile, du gaz et de l'eau d'un fluide de puits de forage à pression relativement élevée, la séparation étant réalisée à des pressions relativement basses, comprenant :(a) la réduction de la pression du fluide de puits de forage jusqu'à une pression relativement basse en faisant passer le fluide de puits de forage par un dispositif (102, 104) qui commande l'écoulement du fluide par modulation ;(b) la décharge du fluide à pression relativement basse dans un séparateur (110) et l'élimination des solides du fluide dans un premier étage (112) du séparateur (110), pour éliminer les solides ;(c) la commande d'un dispositif (120) de commande d'écoulement de gaz en modulant le dispositif (120) de commande d'écoulement de gaz à l'aide d'une unité de commande (201) de manière à maintenir la pression dans le séparateur (110) en dessous d'une valeur prédéterminée ;(d) la séparation de l'huile de l'eau dans le séparateur (110) ;(e) la commande d'un dispositif (128) d'écoulement d'huile en modulant le dispositif (128) d'écoulement d'huile à l'aide de l'unité de commande (201) de manière à maintenir le niveau d'huile dans le séparateur (110) en dessous d'une valeur prédéterminée ; et(f) la commande d'un dispositif (140) d'écoulement d'eau en modulant le dispositif (140) d'écoulement d'eau à l'aide de l'unité de commande (201) de manière à maintenir le niveau d'eau dans le séparateur (110) en dessous d'une valeur prédéterminée.
- Système de manutention de fluide pour séparer les constituants d'un fluide de puits de forage qui se trouve à une pression relativement élevée, la séparation étant réalisée à des pressions relativement basses, comprenant :(a) un dispositif (102, 104) de commande d'écoulement de fluide pour recevoir le fluide de puits de forage à la pression relativement élevée et décharger le fluide reçu à une pression relativement basse ;(b) une cuve (110) pour recevoir le fluide de puits de forage à une pression relativement basse provenant du dispositif (102, 104) de commande d'écoulement de fluide et pour séparer les constituants du fluide de puits de forage, ladite cuve (110) présentant :(i) un premier étage (112) pour séparer les solides contenus dans le fluide ;(ii) un détecteur de pression (118) pour déterminer la pression dans la cuve (110) ;(iii) un deuxième étage (116) pour séparer l'huile et l'eau dans des réservoirs (124, 136) séparés ;(iv) des détecteurs de niveau (138, 126) séparés associés au réservoir d'eau (136) et au réservoir d'huile (124) pour déterminer respectivement le niveau d'eau et le niveau d'huile dans leur réservoir (136, 124) respectif ; et(e) un circuit de commande (201), ledit circuit de commande (201) recevant des signaux du détecteur de pression (118) et de chacun des détecteurs de niveau (126, 138) pour commander la pression, le niveau d'huile et le niveau d'eau dans la cuve (110).
- Système de manutention de fluide selon la revendication 15, dans lequel le dispositif (102, 104) de commande d'écoulement de fluide est une soupape à étranglement.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP00112899A EP1048819B1 (fr) | 1996-05-03 | 1997-05-05 | Système de manutention de fluides en boucle fermée utilisé au cours du forage de puits |
Applications Claiming Priority (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US08/642,828 US5857522A (en) | 1996-05-03 | 1996-05-03 | Fluid handling system for use in drilling of wellbores |
US642828 | 1996-05-03 | ||
US3075296P | 1996-10-29 | 1996-10-29 | |
US30752P | 1996-10-29 | ||
PCT/US1997/007533 WO1997042395A1 (fr) | 1996-05-03 | 1997-05-05 | Systeme de manutention de fluides en boucle fermee utilise au cours du forage de puits |
Related Child Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP00112899A Division EP1048819B1 (fr) | 1996-05-03 | 1997-05-05 | Système de manutention de fluides en boucle fermée utilisé au cours du forage de puits |
Publications (2)
Publication Number | Publication Date |
---|---|
EP0897454A1 EP0897454A1 (fr) | 1999-02-24 |
EP0897454B1 true EP0897454B1 (fr) | 2001-02-28 |
Family
ID=26706419
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP97922650A Expired - Lifetime EP0897454B1 (fr) | 1996-05-03 | 1997-05-05 | Systeme de manutention de fluides en boucle fermee utilise au cours du forage de puits |
Country Status (6)
Country | Link |
---|---|
EP (1) | EP0897454B1 (fr) |
AU (1) | AU723022B2 (fr) |
CA (1) | CA2252944C (fr) |
DE (1) | DE69704158T2 (fr) |
NO (1) | NO315755B1 (fr) |
WO (1) | WO1997042395A1 (fr) |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7350597B2 (en) | 2003-08-19 | 2008-04-01 | At-Balance Americas Llc | Drilling system and method |
GB2521374A (en) | 2013-12-17 | 2015-06-24 | Managed Pressure Operations | Drilling system and method of operating a drilling system |
GB2521373A (en) | 2013-12-17 | 2015-06-24 | Managed Pressure Operations | Apparatus and method for degassing drilling fluid |
EP3408491B1 (fr) * | 2016-01-25 | 2020-04-29 | Shell International Research Maatschappij B.V. | Procédé et système de réglage automatique des propriétés de la boue de forage |
Family Cites Families (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4247312A (en) * | 1979-02-16 | 1981-01-27 | Conoco, Inc. | Drilling fluid circulation system |
US4449594A (en) * | 1982-07-30 | 1984-05-22 | Allied Corporation | Method for obtaining pressurized core samples from underpressurized reservoirs |
US5010966A (en) * | 1990-04-16 | 1991-04-30 | Chalkbus, Inc. | Drilling method |
US5249635A (en) * | 1992-05-01 | 1993-10-05 | Marathon Oil Company | Method of aerating drilling fluid |
US5415776A (en) * | 1994-05-02 | 1995-05-16 | Northland Production Testing Ltd. | Horizontal separator for treating under-balance drilling fluid |
US5411105A (en) * | 1994-06-14 | 1995-05-02 | Kidco Resources Ltd. | Drilling a well gas supply in the drilling liquid |
-
1997
- 1997-05-05 DE DE69704158T patent/DE69704158T2/de not_active Expired - Fee Related
- 1997-05-05 WO PCT/US1997/007533 patent/WO1997042395A1/fr active IP Right Grant
- 1997-05-05 CA CA002252944A patent/CA2252944C/fr not_active Expired - Lifetime
- 1997-05-05 AU AU28268/97A patent/AU723022B2/en not_active Ceased
- 1997-05-05 EP EP97922650A patent/EP0897454B1/fr not_active Expired - Lifetime
-
1998
- 1998-11-02 NO NO19985098A patent/NO315755B1/no not_active IP Right Cessation
Also Published As
Publication number | Publication date |
---|---|
DE69704158D1 (de) | 2001-04-05 |
CA2252944C (fr) | 2006-07-11 |
AU2826897A (en) | 1997-11-26 |
NO985098D0 (no) | 1998-11-02 |
CA2252944A1 (fr) | 1997-11-13 |
NO315755B1 (no) | 2003-10-20 |
EP0897454A1 (fr) | 1999-02-24 |
AU723022B2 (en) | 2000-08-17 |
WO1997042395A1 (fr) | 1997-11-13 |
DE69704158T2 (de) | 2001-08-02 |
NO985098L (no) | 1998-12-30 |
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