WO2000079098A1 - Systeme et procede pour ameliorer la recuperation de fluides dans une formation - Google Patents

Systeme et procede pour ameliorer la recuperation de fluides dans une formation Download PDF

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Publication number
WO2000079098A1
WO2000079098A1 PCT/US2000/013409 US0013409W WO0079098A1 WO 2000079098 A1 WO2000079098 A1 WO 2000079098A1 US 0013409 W US0013409 W US 0013409W WO 0079098 A1 WO0079098 A1 WO 0079098A1
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WO
WIPO (PCT)
Prior art keywords
control device
flow control
rate
injection
lift fluid
Prior art date
Application number
PCT/US2000/013409
Other languages
English (en)
Inventor
Mark A. Schnatzmeyer
Clark E. Robison
Jerry W. Wauters
Original Assignee
Halliburton Energy Services, Inc.
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to AU51366/00A priority Critical patent/AU5136600A/en
Publication of WO2000079098A1 publication Critical patent/WO2000079098A1/fr

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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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/122—Gas lift
    • E21B43/123—Gas lift valves

Definitions

  • This invention relates in general to a system and method for enhancing recovery of hydrocarbon fluids from a formation and, in particular to. a controller for automating the injection rate of a lift fluid into the well to optimize the production therefrom.
  • One method of enhancing the recovery of hydrocarbons from a formation is to decrease the hydrostatic head of the column of fluid in the wellbore. Decreasing the hydrostatic head enhances recovery by reducing the amount of pressure required to lift the fluids to the surface. Decreasing the density of the column of fluid extending from the formation to the surface is a technique utilized to reduce the hydrostatic head of the fluid column. For example, mixing a lower density fluid with formation fluids reduces the overall density of the fluid column and consequently decreases the hydrostatic head.
  • a lift fluid typically a gas or hydraulic fluid having low density
  • the low density fluid is then injected into the production tubing at one or more predetermined locations where it mixes with formation fluids, lowering the density of the fluid column above the formation.
  • the injection of the low density fluid into the production tubing must be carefully controlled to avoid equipment damage while simultaneously providing for optimal recovery. For example, excessive injection rates can result in pressure surges in the tubing and related equipment. Such pressure surges may produce large and destructive forces within the production equipment.
  • Control of the injection rate is typically accomplished using an orifice, the size of which is typically determined using a trial and error procedure.
  • the operator attempts to "dial in” the well by regulating the rate of injection of the low density fluids with various size orifice valves until optimum production is reached.
  • the well operator will typically try several orifice settings, allowing the well to stabilize after each adjustment. Due to the distances and respective volumes involved, the operator may spend a significant amount of time in making the adjustments, stabilizing production after each adjustment and collecting comparative data from the different settings to establish performance trends.
  • a need has arisen for a control system to automate the process of adjusting the flow rate of a low density fluid to optimize production based upon well parameters.
  • a need has also arisen for such a system that reduces the operator time and attention required to "dial in” the well.
  • a need has arisen for a precise control system that periodically monitors and adjusts the injection rate of the low density fluid into the production tubing.
  • the present invention disclosed herein comprises a system and method to automate control over the flow of a lift fluid into a wellbore of a hydrocarbon producing well to enhance recovery of fluids from a formation.
  • the system and method maximize recovery based upon well parameters while minimizing the time and attention of the operator typically required to "dial in” the well.
  • the system and method provide precise control over the flow of the lift fluid into the wellbore by periodically monitoring and adjustment of the rate of injection of the lift fluid.
  • a flow control device such as a control valve or choke valve, is disposed within the wellbore.
  • the flow control device is adjustable between various positions to regulate the injection of the lift fluid into the tubing wherein formation fluids are being produced.
  • a sensor monitors the rate of recovery of the formation fluids.
  • the sensor providing signals indicative of the rate of recovery of the formation fluids to a controller.
  • the signals may be transmitted to the controller using an electronics package disposed downhole.
  • the controller receives the signals and adjusts the position of the flow control device in response to the signals to regulate the rate of injection of the lift fluid.
  • the low density fluids are injected into the tubing to reduce the hydrostatic head of the formation fluids in the tubing and provide artificial lift thereto.
  • the lift fluid may be either a gas or a liquid.
  • the controller includes a set of preprogrammed instructions for determining the optimum position of the flow control device by incrementally adjusting the position of the flow control device in response to the signals received from the sensor. For example, the controller may incrementally adjust the position of the flow control device to increase the rate of injection of the lift fluid when the sensor indicates that the rate of recovery of the fluids increased in response to a prior increase in the rate of injection of the lift fluid. Conversely, the controller may incrementally adjust the position of the flow control device to decrease the rate of injection of the lift fluid when the sensor indicates that the rate of recovery of the fluids decreased in response to a prior increase the rate of injection of the lift fluid.
  • the flow control device is incorporated into a downhole tool and is pneumatically or hydraulically actuated from a remote location.
  • the controller is positioned at or near the wellhead and includes a computer or programmable controller as well as line pressurization and bleed down actuators for regulating the flow control device.
  • the controller may also include a sensor to monitor control line pressure.
  • the controller will be capable of interfacing with any existing sensors for annulus pressure, tubing pressure, injection rate and flow rate. In the event that such sensors are not present, the controller may be provided with sensors adaptable for installation at the wellhead or on existing line fittings.
  • the method of the present invention involves disposing an adjustably positionable flow control device within the wellbore, determining the rate of recovery of the fluids with a sensor, generating signals indicative of the rate of recovery of the fluids and adjusting the position of the flow control device in response to the signals to regulate the injection of the lift fluid into the formation fluids, thereby enhancing the recovery of the formation fluids.
  • Figure 2 is a schematic illustration of a fluid injection control valve utilized in the practice of the present invention
  • Figure 3 is a graphical representation of the relationship between the injection rate of a density compensating fluid and the flow rate of formation fluids from a well;
  • Figure 4 is a block diagram illustrating various steps utilized in the system of the present invention to control the rate of fluid injection into a well.
  • FIG. 1 a well installation incorporating the features of the present invention is schematically illustrated and generally designated 10.
  • the well is cased with a normal casing 100.
  • a tubing string 102 extends through the casing 100 for conventional extraction of hydrocarbon fluids.
  • Hydrocarbon fluids are produced into tubing 102 at a point below seal assembly 104 that provides a sealing engagement between tubing 102 and casing 100.
  • formation fluid flow may be controlled by one or more choke or control valves 108.
  • fluid flow from the formation through the tubing 102 may be enhanced through the use of an artificial lift technique such as injection of a lift fluid.
  • an artificial lift technique such as injection of a lift fluid.
  • the optimum injection rate of the lift fluid must be determined.
  • a lift fluid source 105 such as a compressor or pump is provided to supply the low density lift fluid to injection tool 106.
  • the lift fluid travels through annulus 1 12 and enters tool 106 through inlet ports 130.
  • the injection rate of the lift fluid is monitored with flow sensor 107.
  • a lift fluid may be provided from a different location in the well or from another well, depending upon the particular location.
  • the lift fluid may be a gas or a liquid and. as used herein, the term "lift fluid" shall include both gases and s liquids utilized to adjust the density of formation fluids during the recovery process irrespective of the physical phase of the lift fluid into the tubing 102.
  • the system of the present invention is not limited to the use of a particular tool or injection means.
  • injection tool 106 includes a hydraulically actuated o control valve or downhole adjustable choke valve 134.
  • Hydraulic pump 103 provides control pressure via control line 114 to the tool 106.
  • the control pressure is regulated by a controller or control unit 101 that provides the desired hydraulic control pressure to tool 106.
  • control unit 101 is a portable unit, remotely positioned from the tool 106.
  • the control unit 101 may be located at or near the wellhead or at a more remote s location depending upon the particular application.
  • the control unit 101 includes a computer or an electronic programmable controller and line pressurization actuators, either hydraulic or gas, for the application and bleed-down of pressure to choke valve 134.
  • the control unit 101 may also incorporate instrumentation to monitor the pressure in control line 1 14 to determine when the pressure in the control line 1 14 has equalized.
  • the control 0 unit 101 is adaptable to interface with existing sensors to determine annulus pressure, tubing pressure, injection rate and flow rate.
  • control unit 101 may be provided with instrumentation suitable for installation at the wellhead or on existing line fittings.
  • the system of the present invention may also include a downhole electronics package communicably coupled to one or more sensors for 5 transmitting information to the remotely located control unit 101.
  • the control unit 101 may receive information from a variety of different sensors.
  • the pressure and/or flow rate of the lift fluid are measured with sensor 107 and transmitted to the control unit 101 as schematically represented by dashed line 120.
  • the pressure and/or flow rate of recovered formation fluids may be monitored with sensor 1 10 and relayed to the control unit 101 as indicated with dashed line 121.
  • the tool 106 may be equipped with a sensor and electronics package 135 for monitoring tubing pressure, casing pressure, temperature, valve position and other variables of interest that may be transmitted to the control unit 101 as schematically represented by dashed line 122. Transmission of data by the electronics package 135 may be accomplished in a variety of ways including, but not limited to. by electromagnetic, acoustical or hardwired telemetry as will be appreciated by those skilled in the art.
  • FIG. 2 there is illustrated a schematic cross-sectional view of a flow control system such as a downhole adjustable choke valve 134 disposed with tubing 102 and suitable for use in connection with the system of the present invention.
  • lift fluid flows down between tubing 102 and casing 100 through inlet ports 128 and into choke valve 134 as generally indicated by arrows 116.
  • the lift fluid travels through central bore 118 of choke valve 134.
  • the production fluids are diverted around choke valve 134 as generally indicated by arrows 126.
  • the lift fluid is injected into the production fluids above choke valve 134 inside of tubing 102.
  • the lift fluid is injected into the tubing 102 at a single location.
  • the lift fluid may be injected into tubing 102 at multiple locations. As illustrated in Figure 2 the lift fluid passes through central port 1 18 as generally indicated by arrows 116. The lift fluid to be injected into tubing 102 enters valve body 162 and passes through orifice plate 164 via orifice 166. The flow of lift fluid through valve body 162 is controlled with poppet 160 which is positioned relative to the orifice plate 164 by actuator 136. As illustrated, in order to adjust the flow of lift fluid through choke valve 134, poppet 160 is advanced or retracted relative to the orifice plate 164, thereby decreasing or increasing the effective opening of orifice 166.
  • choke valve 134 is actuated by a hydraulic actuator 136 operatively connected to choke valve 134.
  • choke valve 134 is illustrated as a poppet type valve, other variable position choke valves may be utilized in the practice of the invention.
  • Figure 3 the flow rate of formation fluids in a well as a function of the injection rate of the lift fluid is depicted. As shown, recovery as a function of injection rate reaches a maximum at the intersection of the axes designated y' and z' . Injecting additional lift fluid beyond the maximum rate indicated by the intersection of the designated y' and z' axes actually decreases the productivity of the well.
  • controller 101 includes preprogrammed instructions stored on a conventional memory device to generate a signal at step 200 to initialize or reset the flow rate of the lift fluid in response to an operator command, at predetermined intervals or in response to a change in flow rate.
  • the orifice position of the downhole adjustable choke valve 134 is set at step 210 to a predetermined initial position.
  • step 220 the flow rate and pressure are monitored to determine whether the well has stabilized at the particular injection rate. Flow rate and pressure data are then collected for the particular orifice position in step 230 via sensors 107, 110.
  • step 240 the orifice is incremented to the next position in step 240. If there are additional orifice positions in step 250, the well is again allowed to stabilize in step 220 and the process of data collection (step 230) and orifice incrementing (step 240) are repeated until all desired orifice positions have been tested. Once all the desired positions of the orifice have been tested, the data collected in step 230 is analyzed to determine the optimal orifice position in step 260. Thereafter, the operator is notified in step 270 that the process is complete and which orifice size is optimal for the well.
  • the flow rate of formation fluids from the well is monitored as a function of an incremental change in the rate of injection of the lift fluid.
  • the injection rate of the lift fluid is initially increased in increments 280 based upon preprogrammed instructions resident on control unit 101.
  • the magnitude of incremental increases 280 may be directly proportional to the changes in the flow rate or otherwise determined by control unit 101 and may be varied depending upon the particular application and well conditions.
  • the rate of injection increases, the flow rate reaches a maximum as shown by the intersection of axis y' and z'. Increasing the rate of injection beyond this point as indicated by incremental increases 290 decreases the flow rate of production fluids.
  • a zone of instability 300 may be entered.
  • the magnitude of the incremental increases are reduced to fine tune the system as shown by incremental increases 310.
  • the optimal flow rate is thus not the maximum flow rate depicted in the curve but rather a point close to, yet below, the zone of instability 300.
  • the instructions programmed into control unit 101 may also include commands to adjust or reduce the flow of lift fluid in the event that the flow of formation fluids becomes unstable or in the event of sudden changes in pressure or flow rate. While this invention has been described with a reference to illustrative embodiments, this description is not intended to be construed in a limiting sense. Various modifications and combinations of the illustrative embodiments as well as other embodiments of the invention, will be apparent to persons skilled in the art upon reference to the description. It is, therefore, intended that the appended claims encompass any such modifications or embodiments.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (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)
  • Flow Control (AREA)

Abstract

L'invention concerne un système et un procédé destinés à améliorer la récupération de fluides d'une formation traversée par un puits. Le système comprend un dispositif (134) de régulation de débit réglable dans une pluralité de positions pour réguler l'injection d'un fluide de poussée dans le fluide de la formation. Un détecteur (110) contrôle le débit de récupération des fluides de la formation et fournit les signaux (121) indiquant le débit de récupération. Un contrôleur (101) reçoit les signaux (121) du détecteur (110) et il règle de façon incrémentielle la position du dispositif (134) régulateur de débit sur la base d'un ensemble d'instructions préprogrammées afin d'identifier le débit optimal des fluides de la formation, en améliorant ainsi la récupération.
PCT/US2000/013409 1999-06-18 2000-05-16 Systeme et procede pour ameliorer la recuperation de fluides dans une formation WO2000079098A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU51366/00A AU5136600A (en) 1999-06-18 2000-05-16 System and method for enhancing the recovery of fluids from a formation

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US33555699A 1999-06-18 1999-06-18
US09/335,556 1999-06-18

Publications (1)

Publication Number Publication Date
WO2000079098A1 true WO2000079098A1 (fr) 2000-12-28

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PCT/US2000/013409 WO2000079098A1 (fr) 1999-06-18 2000-05-16 Systeme et procede pour ameliorer la recuperation de fluides dans une formation

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WO (1) WO2000079098A1 (fr)

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1867832A1 (fr) * 2006-06-14 2007-12-19 GeoForschungsZentrum Potsdam Stiftung des Öffentlichen Rechts Telegrafenberg Valve d'étranglement destinée à l'injection de liquide dans des formations géologiques
WO2016181154A1 (fr) * 2015-05-12 2016-11-17 Weatherford U.K. Limited Procédé et appareil de levage de gaz
US12024988B2 (en) 2022-03-29 2024-07-02 Sam and Gail LLC Gas lift system and method

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2197675A (en) * 1986-11-18 1988-05-25 British Petroleum Co Plc Controlling artificial lift in wells
US5535767A (en) * 1995-03-14 1996-07-16 Halliburton Company Remotely actuated adjustable choke valve and method for using same
US5732776A (en) * 1995-02-09 1998-03-31 Baker Hughes Incorporated Downhole production well control system and method
US5896924A (en) * 1997-03-06 1999-04-27 Baker Hughes Incorporated Computer controlled gas lift system

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2197675A (en) * 1986-11-18 1988-05-25 British Petroleum Co Plc Controlling artificial lift in wells
US5732776A (en) * 1995-02-09 1998-03-31 Baker Hughes Incorporated Downhole production well control system and method
US5535767A (en) * 1995-03-14 1996-07-16 Halliburton Company Remotely actuated adjustable choke valve and method for using same
US5896924A (en) * 1997-03-06 1999-04-27 Baker Hughes Incorporated Computer controlled gas lift system

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1867832A1 (fr) * 2006-06-14 2007-12-19 GeoForschungsZentrum Potsdam Stiftung des Öffentlichen Rechts Telegrafenberg Valve d'étranglement destinée à l'injection de liquide dans des formations géologiques
WO2016181154A1 (fr) * 2015-05-12 2016-11-17 Weatherford U.K. Limited Procédé et appareil de levage de gaz
US10655439B2 (en) 2015-05-12 2020-05-19 Weatherford U.K. Limited Gas lift method and apparatus
US12024988B2 (en) 2022-03-29 2024-07-02 Sam and Gail LLC Gas lift system and method

Also Published As

Publication number Publication date
AU5136600A (en) 2001-01-09

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