EP0897454A1 - Closed loop fluid-handling system for use during drilling of wellbores - Google Patents
Closed loop fluid-handling system for use during drilling of wellboresInfo
- Publication number
- EP0897454A1 EP0897454A1 EP97922650A EP97922650A EP0897454A1 EP 0897454 A1 EP0897454 A1 EP 0897454A1 EP 97922650 A EP97922650 A EP 97922650A EP 97922650 A EP97922650 A EP 97922650A EP 0897454 A1 EP0897454 A1 EP 0897454A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- vessel
- pressure
- fluid
- oil
- wellbore
- 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.)
- Granted
Links
- 238000005553 drilling Methods 0.000 title claims abstract description 54
- 239000012530 fluid Substances 0.000 claims abstract description 86
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 51
- 239000007787 solid Substances 0.000 claims abstract description 20
- 238000007599 discharging Methods 0.000 claims abstract description 9
- 239000007789 gas Substances 0.000 claims description 30
- 239000000654 additive Substances 0.000 claims description 16
- 230000000996 additive effect Effects 0.000 claims description 10
- 239000000470 constituent Substances 0.000 claims description 6
- 239000003921 oil Substances 0.000 claims description 6
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 4
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 4
- 239000003570 air Substances 0.000 claims description 4
- 239000000463 material Substances 0.000 claims description 3
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 2
- 239000001569 carbon dioxide Substances 0.000 claims description 2
- 238000005259 measurement Methods 0.000 claims description 2
- 229910052757 nitrogen Inorganic materials 0.000 claims description 2
- 239000011324 bead Substances 0.000 claims 1
- 239000011521 glass Substances 0.000 claims 1
- 238000000034 method Methods 0.000 claims 1
- 239000008188 pellet Substances 0.000 claims 1
- 230000015572 biosynthetic process Effects 0.000 description 11
- 238000005755 formation reaction Methods 0.000 description 11
- 239000000203 mixture Substances 0.000 description 8
- 230000004044 response Effects 0.000 description 8
- 239000007788 liquid Substances 0.000 description 6
- 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
- 238000000926 separation method Methods 0.000 description 2
- 230000037380 skin damage Effects 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 229910004413 SrSn Inorganic materials 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 230000004913 activation 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
- 239000006260 foam Substances 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 230000009545 invasion Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000011144 upstream manufacturing Methods 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/06—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 generally to drilling of wellbores and more particularly to a fluid-handling system for use in underbalanced 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.
- 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 present invention also provides means for controlling the wellbore pressure from the surface as a function of the downhole measured pressure.
- This invention provides a fluid-handling system for use in underbalanced drilling operations.
- 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 system of the present invention also determines the downhole pressures, including the formation pressure and controls the drilling fluid flow into the wellbore to maintain a desired pressure at the wellhead.
- the system also automatically controls the drilling fluid mix as a function of one or more desired operating parameters to control the density of the circulating fluid.
- 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
- FIG. 2 shows the fluid handling system of FIG. 1 in conjunction with a
- 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
- 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
- ESD emergency shut-down valve
- phase separator (primary separator) 110 The choke valve 102 creates a
- the primary separator 110 preferably is a four phase separator. The wellstream entering into the separator 110 passes to a first stage of the
- 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
- a sensor 113 detects the
- the operation of the sludge pump 114 is preferably controlled
- FIG. 1A shows a control
- control system 200 having a control unit or control circuit 201 , which receives signals
- 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
- a pressure sensor 118 placed in the separator 110 and
- control unit 201 coupled to the control unit 201 is used to continually monitor the pressure in
- the control unit 201 adjusts the control valve 120 so as to
- a pressure controller 118a 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.
- 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
- the control unit 201 may also be programmed to shut down the system
- the system 100 may be shut down upon the activation of
- the high-high pressure trip protects against failure of the upstream choke valves 102 and 104, while the low-low trip protects the
- 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.
- the control unit 201 which determines the level of the oil in the bucket 124.
- the level sensor 126 may provide a signal to a
- signals also may be used to activate alarms 210 when the oil level is above a maximum level or below a minimum level.
- water flows under the oil bucket 124 in the
- a level sensor 138 is placed in the water reservoir 136 and is
- control unit 201 which continually determines the water level
- the control unit 201 is programmed to control a valve
- the level sensor 128 may provide a signal to a level
- controller 138a which modulates the control valve 140 to discharge the water
- the liquid level in the main body of the separator is monitored by a level switch 142 which
- Any gas present in the water discharged into the water tank separates within the water tank 145. Such gas is discharged via a control valve 147 to
- a pressure sensor 148 associated with the water tank 145 is utilized to determine the pressure at which the water tank 145 is utilized.
- control the control valve 147 to maintain a desired pressure in the water tank
- the control valve 147 may be modulated by a pressure controller 148a
- control valve 147 may be controlled by the control unit 201 in response to the
- a level in the water tank 145 is monitored by a level sensor 150.
- controller 150a modulates a control valve 152 in response to the level sensor
- control unit 201 may be utilized to control the valve 152 in response to the
- the fluid level in the water tank 145 also is monitored
- a pump 155 which initiates an emergency shutdown of the system if the level inadvertently reaches a predetermined maximum level.
- 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
- the separated gas is discharged via a control valve 164 and
- the oil surge tank 160 is utilized to control the control valve 164 in order to
- control valve 164 may be modulated by a pressure controller 162a in response to signals from the pressure sensor 162. Alternatively, the operation of the control valve 164
- control unit 201 may be controlled by the control unit 201 in response to the signals from the
- 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 sensor 168 A level
- controller 168a modulates a control valve 170 in response to the level sensor
- control unit 201 may be utilized to control the valve 170 in
- 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
- control unit 201 may be placed at
- control unit 201 is coupled to one or more monitors
- control unit 201 contains one or more data processing units,
- control unit 201 receives signals from the various components
- 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.
- control unit 201 indicate that the control unit 201 receives signals and inputs from
- control unit 201 which is preferably
- 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
- the control unit 201 also controls the pressure in the
- prior art systems control the wellbore pressure by maintaining the pressure at the surface at a desired value. Based on the depth of the wellbore and the types of fluids utilized during drilling of the wellbore, the actual downhole pressure can vary from the desired pressure by several hundred pounds. In order to accurately control the pressure in the
- the present system includes a pressure sensor 222c for measuring
- sensors such as differential pressure sensors, may also be utilized for determining the differential pressures downhole.
- the control unit 201 periodically or continually monitors the
- the drill string 224 may also include other sensors, such as a temperature sensor
- FIG. 2 shows an embodiment 100a of the fluid handling system of the present invention which can automatically control the drilling fluid mix as a function of downhole measured operating parameters, such as the formation pressure, or any other selected parameters. As shown in FIG. 2, the system 100a
- additives from the source 302 pass to the mixer 310 via an electrically-
- the controller 201 receives information about the
- the selected parameters to be controlled such as the formation pressure.
- the system 100a is provided with a model 308 for use by the control unit 201 to determine the drilling fluid mix.
- the control unit 201 periodically or continually determines the required fluid mix as a function of one or more of the selected operating parameters and operates the control valve 304 via
- control line C q to discharge the correct amount of the additive materials to
- control unit 201 also controls the fluid control
- valve 306 via line C p to control the drilling fluid flow into the mixer 310.
- tank 154 and the additives from the source 302 are preferably mixed at a juncture or mixer 310 and discharged into the wellbore via line 312.
- the additives and the drilling fluid may be injected separately into the wellbore 225. In some applications it may be more desirable to inject the additives at or near the bottom of the drill string 224 via a separate line (not
- 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 and drilling fluid mixture 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 substantially less manpower to operate in contrast to known fluid-handling systems utilized during underbalanced drilling of wellbores.
Landscapes
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Earth Drilling (AREA)
- Physical Water Treatments (AREA)
Abstract
Description
Claims
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP00112899A EP1048819B1 (en) | 1996-05-03 | 1997-05-05 | Closed loop fluid-handling system for use during drilling of wellbores |
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 (en) | 1996-05-03 | 1997-05-05 | Closed loop fluid-handling system for use during drilling of wellbores |
Related Child Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP00112899A Division EP1048819B1 (en) | 1996-05-03 | 1997-05-05 | Closed loop fluid-handling system for use during drilling of wellbores |
Publications (2)
Publication Number | Publication Date |
---|---|
EP0897454A1 true EP0897454A1 (en) | 1999-02-24 |
EP0897454B1 EP0897454B1 (en) | 2001-02-28 |
Family
ID=26706419
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP97922650A Expired - Lifetime EP0897454B1 (en) | 1996-05-03 | 1997-05-05 | Closed loop fluid-handling system for use during drilling of wellbores |
Country Status (6)
Country | Link |
---|---|
EP (1) | EP0897454B1 (en) |
AU (1) | AU723022B2 (en) |
CA (1) | CA2252944C (en) |
DE (1) | DE69704158T2 (en) |
NO (1) | NO315755B1 (en) |
WO (1) | WO1997042395A1 (en) |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
MXPA06001754A (en) | 2003-08-19 | 2006-05-12 | Shell Int Research | 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 |
CA3010427A1 (en) * | 2016-01-25 | 2017-08-03 | Shell Internationale Research Maatschappij B.V. | Method and system for automated adjustment of drilling mud properties |
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 AU AU28268/97A patent/AU723022B2/en not_active Ceased
- 1997-05-05 CA CA002252944A patent/CA2252944C/en not_active Expired - Lifetime
- 1997-05-05 WO PCT/US1997/007533 patent/WO1997042395A1/en active IP Right Grant
- 1997-05-05 DE DE69704158T patent/DE69704158T2/en not_active Expired - Fee Related
- 1997-05-05 EP EP97922650A patent/EP0897454B1/en not_active Expired - Lifetime
-
1998
- 1998-11-02 NO NO19985098A patent/NO315755B1/en not_active IP Right Cessation
Non-Patent Citations (1)
Title |
---|
See references of WO9742395A1 * |
Also Published As
Publication number | Publication date |
---|---|
AU2826897A (en) | 1997-11-26 |
CA2252944C (en) | 2006-07-11 |
NO985098D0 (en) | 1998-11-02 |
DE69704158D1 (en) | 2001-04-05 |
EP0897454B1 (en) | 2001-02-28 |
DE69704158T2 (en) | 2001-08-02 |
NO985098L (en) | 1998-12-30 |
AU723022B2 (en) | 2000-08-17 |
WO1997042395A1 (en) | 1997-11-13 |
NO315755B1 (en) | 2003-10-20 |
CA2252944A1 (en) | 1997-11-13 |
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