WO2013115824A1 - Mécanisme de régulation d'injection chimique - Google Patents

Mécanisme de régulation d'injection chimique Download PDF

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Publication number
WO2013115824A1
WO2013115824A1 PCT/US2012/023701 US2012023701W WO2013115824A1 WO 2013115824 A1 WO2013115824 A1 WO 2013115824A1 US 2012023701 W US2012023701 W US 2012023701W WO 2013115824 A1 WO2013115824 A1 WO 2013115824A1
Authority
WO
WIPO (PCT)
Prior art keywords
fluid
flow
valve
well
injection
Prior art date
Application number
PCT/US2012/023701
Other languages
English (en)
Inventor
Dinesh Patel
David Himmel
Original Assignee
Schlumberger Technology Corporation
Schlumberger Canada Limited
Services Petroliers Schlumberger
Schlumberger Holdings Limited
Schlumberger Technology B.V.
Prad Research And Development Limited
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 Schlumberger Technology Corporation, Schlumberger Canada Limited, Services Petroliers Schlumberger, Schlumberger Holdings Limited, Schlumberger Technology B.V., Prad Research And Development Limited filed Critical Schlumberger Technology Corporation
Priority to BR112014018933A priority Critical patent/BR112014018933A8/pt
Priority to GB1413655.0A priority patent/GB2514033A/en
Publication of WO2013115824A1 publication Critical patent/WO2013115824A1/fr
Priority to NO20140959A priority patent/NO20140959A1/no

Links

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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells

Definitions

  • the well is often outfitted with chemical injection equipment to enhance ongoing recovery efforts without the requirement of intervention.
  • most of the well may be defined by a smooth steel casing that is configured for the rapid uphole transfer of hydrocarbons and other fluids from a formation.
  • a buildup of irregular occlusive scale, wax and other debris may occur at the inner surface of the casing or tubing and other architecture restricting flow there -through.
  • Such debris may even form over perforations in the casing, screen, or slotted pipe thereby also hampering hydrocarbon flow into the main borehole of the well from the surrounding formation.
  • the noted chemical injection equipment includes an injection line that may be run from surface and directed at different downhole points of interest such as within production tubing, at a production screen or into formation fluid prior to entering the noted tubing. Regardless, the need to halt production or run expensive interventions in order to address undesirable buildup may be largely eliminated.
  • regulating the delivery of the chemical injection mixture to the points of interest may come with pressure related challenges over the life of the well.
  • a given downhole point of interest within the well may display a fairly high pressure at the outset of operations.
  • well pressures may exceed 10,000 PSI. Therefore, the chemical injection line may be pressurized from surface so as to ensure that a proper chemical injection delivery rate is maintained.
  • a series of check valves may also be incorporated into the line to help avoid potentially caustic production uphole through the line.
  • pressurizing the line may overcome a well pressure of 10,000 PSI.
  • the line may begin to leak chemical mixture into the well even without the application of positive pressure from surface. That is to say, depending on the depth of the line, the inherent fluid pressure therein may begin to exceed well pressure.
  • a chemical injection regulation mechanism which includes inlet and outlet lines.
  • a regulation device is coupled to the lines for regulating chemical flow therebetween based on a fluid flow directed thereat.
  • a method of regulating fluid flow between the lines is provided. The method includes directing a fluid downhole through the inlet line at a given rate and guiding the fluid to a regulator of the device having a pressure based on the given rate. The fluid may then be released through the outlet line and into a well where the pressure is below a predetermined level.
  • Fig. 1 is a side view of a downhole assembly employing an embodiment of a chemical injection regulation mechanism.
  • Fig. 2 is an overview of an oilfield with a well accommodating the assembly of Fig. 1 with the regulation mechanism incorporated therein.
  • Fig. 3 A is an enlarged sectional view of the regulation mechanism of Figs. 1 and 2 in an open position to allow chemical flow therethrough.
  • Fig. 3B is an enlarged sectional view of the mechanism of Fig. 3A in a closed position to seal off chemical flow to the well.
  • Fig. 4 is an alternate embodiment of a chemical injection regulation mechanism employing multiple regulators in tandem for flexibility in flow control.
  • Fig. 5 is another alternate embodiment of a regulation mechanism incorporated into a downhole assembly and utilizing electric line control.
  • FIG. 6 is a flow-chart summarizing an embodiment of employing a chemical injection regulation mechanism is disclosed.
  • Embodiments are described with reference to certain configurations of completions hardware that make use of chemical injection assemblies.
  • completions are depicted and described which utilize a chemical injection assembly to help prevent scale and other buildup in an adjacent production tubular.
  • a variety of different completion architectures may benefit from utilization of regulated chemical injection as detailed herein.
  • chemical injection directed at a well annulus, casing, production screen or a variety of other locations may benefit from a regulation mechanism as detailed herein.
  • a side view of a downhole assembly 101 is shown.
  • the assembly 101 utilizes an embodiment of a chemical injection regulation mechanism 100 to help manage the flow of chemical injection fluid into adjacent production tubing 180.
  • a chemical injection application may be directed at a variety of different completion hardware target locations.
  • the regulation mechanism 100 may be particularly adept at preventing the undesirable drainage of a column of the injection fluid from a chemical injection line 120.
  • a chemical injection mixture and application protocol at the depicted location of Fig. 1 may be directed by an operator positioned a significant distance away at an oilfield 200 of Fig. 2. As detailed below, this results in a pressure exerted by the column of fluid in the line 120 which, depending on downhole conditions, may exceed pressure within the tubing 180. Thus, the regulation mechanism 100 may be of significant benefit in deterring chemical fluid leakage into the depicted tubing 180.
  • the assembly 101 is configured to support production in an uphole direction (see arrow 110).
  • the assembly 101 is outfitted with the chemical injection features such as the referenced line 120.
  • an ongoing metered amount of chemical injection fluid may be delivered to the tubing 180 so as to help minimize scale 190 or other production inhibiting buildup.
  • the assembly 101 may be outfitted with one way check valves 175 to ensure that production does not enter the tubing port 177 of the chemical injection system.
  • These valves 175 may be located near the port 177 to protect as much of the line 120, regulation mechanism 100, and other chemical injection hardware from exposure to downhole fluids as possible.
  • a pump unit 227 may be utilized to drive up pressure and deliver a metered rate of injection.
  • the role of the regulation mechanism 100 is again considered.
  • the mechanism 100 is shown with a coupling 140 for securing to the chemical injection line 120 which originates at the surface of the oilfield 200 as alluded to above.
  • this means that the noted column of fluid in the line 120 may span a distance of several thousand feet in vertical height.
  • the fluid pressure at the coupling 140 and mechanism 100 may be far in excess of about 500 PSI (depending on the fluid type).
  • the tubing pressure at the location 179 adjacent the depicted tubing port 177 may be well under 500 PSI as in the example above. Indeed, this is often the case for wells that are offshore, substantially depleted, of extended life, or some combination thereof. Whatever the noted above, the disposal of the regulation mechanism 100 between the noted location 179 and the line 120 may be utilized to help avoid the undesirable chemical injection leakage into the tubing 180.
  • FIG. 2 an overview of an oilfield 200 is shown which accommodates the assembly 101 of Fig. 1 within a well 285. More specifically, the assembly 101 is isolated with a packer 275 adjacent a perforated production region 297. So, for example, the interior of the production tubing 180 is exposed to the region 297 for production but isolated from the remaining annulus 250 of the well 285. Once more, as detailed above, debris such as scale and other buildup in the tubing 180 are kept at a minimum by the use of a chemical injection system that incorporates a regulation mechanism 100, among other features. [0026] In the embodiment shown, the noted injection system is directed at delivery through a port 177 and into the tubing 180 as described above.
  • the location of the delivery is such that uphole fluid flow via production may be utilized to distribute chemical injection mix through the tubing 180 keeping buildup therein at a minimum.
  • chemical injection may be directed at hardware directly adjacent the production region 297, within the annulus 250, or anywhere downhole that may be of operational benefit.
  • downhole pressure e.g. in the tubing 180
  • the regulation mechanism 100 may help prevent uncontrolled injection fluid drainage, thereby avoiding any potential catastrophic results from such leakage.
  • the well 285 is outfitted with a casing 280 and traverses various formation layers 290, 295 in reaching the noted production region 297.
  • the chemical injection line 120 of the assembly 101 may traverse several thousand feet from surface before reaching the regulation mechanism 100.
  • the significance of the mechanism 100 in holding back a column of injection fluid mixture may be appreciated, for example, where the corresponding downhole pressure is of a negligible level.
  • a host of equipment 220 is positioned at the oilfield 200 for running production, chemical injection, and other operations.
  • this includes a conventional well head 225 with production line 223 emerging therefrom along with a rig 221 for supporting a host of potential interventional tools.
  • pump 227 and control 229 units are also positioned adjacent the well head 225 for directing operations.
  • the pump unit 227 may be supplied by chemical tanks and utilized to circulate a tailored chemical fluid mixture down through the injection line 120.
  • the pump unit 227 may be configured to effect a pressure and rate sufficient for overcoming any high pressure downhole conditions.
  • changes to this rate, the ratio of constituents of the fluid mixture, or responsiveness to changing downhole pressures may be accounted for and directed by the control unit 229.
  • this may even include directing the pump unit 227 to halt positive pressure applied to the line 120 when downhole pressure becomes sufficiently low.
  • the effectiveness of the regulation mechanism 100 in preventing chemical loss from the line 120 may be appreciated as noted above and detailed further below.
  • another advantage of utilizing the regulation mechanism 100 relates to testing of the injection system as a whole. That is, upon outfitting hardware within the well 285 as shown, a series of functional tests may be performed. For example, this may include testing seals and other features of the chemical line 120. With the regulation mechanism 100 incorporated into the line 120, such tests may now be performed at reasonably low pressures and without significant loss of chemical fluid. That is, flow rate and pressure may be introduced into the line 120 in order to close off the mechanism 100 as described and test fluid sealing thereof.
  • Figs. 3A and 3B enlarged sectional views depicting internal features of the regulation mechanism 100 of Figs. 1 and 2 are shown. More specifically, Fig. 3 A is a view of the mechanism 100 in an open position to allow chemical flow therethrough, whereas 3B depicts the mechanism 100 closed to seal off the chemical flow.
  • the mechanism 100 is depicted with the coupling 140 at one end for securing to the chemical line 120 and an outlet 360 leading to check valves 175 and other injection features (see Figs. 1 and 2).
  • the flow rate of the noted chemical fluid mix 300 may determine whether or not the regulation mechanism 100 is left open or is closed.
  • the fluid mix 300 may be directed to the regulation mechanism 100 at a rate of about 0.1 gallons per minute. With added reference to Fig. 2, this may be achieved by operation of the pump 227 and control 229 units which may direct and monitor flow on an ongoing basis as well as account for factors such as the length and dimensions of the line 120. Regardless, in the embodiment shown, and by way of example only, a flow rate of 0.1 gal./min. may translate into about a 150 lbs. of force applied to a valve 325 of within the mechanism 100.
  • a biasing device 330 in this case, a spring
  • a valve 325 would remain open and allow the fluid 300 to continue to flow through the regulation mechanism 100.
  • valve 325 be closed so as to stop the flow of chemical mix 300.
  • low pressure conditions in the well 280 may constitute such circumstances.
  • the column of chemical mix 300 in the line 120 may naturally begin to flow at a greater rate due to a reduced pressure differential.
  • the flow rate may be increased, whether naturally or as directed by surface equipment 220.
  • a rate increase to 0.2 gallons per minute might raise the forces exerted on the valve 325 to a predetermined 300 lbs., thereby overcoming the biasing device 330 and closing off flow through the mechanism 100.
  • valve 325 is equipped with a piston 350 and sealing head 355 which extends toward an exit channel 365 of the outlet 360.
  • the valve 325 is a shuttle valve disposed in a chamber 320 defined by a body 301 of the mechanism 100 and outfitted with a seal ring 329 and flow restrictor 327.
  • the flow of fluid 300 into this chamber 320 from the line 120 translates into a force on the valve 325 that is enhanced primarily based on the dimensions of the restrictor 327. That is, the smaller the restrictor 327, the greater the magnification of the force. Regardless, with the restrictor 327 inherently of smaller dimension than the chamber 320 and the line 120, some degree of force amplification results.
  • the particular degree of force amplification may be tailored to the particular operational parameters in which the regulation mechanism 100 is to be utilized. So, for example, in certain embodiments a wide range and high rate of chemical injection delivery protocols may be utilized. Therefore, the amount of flow rate increase necessary to close off the regulation mechanism and injection may be greater than in applications where tighter tolerances or more precision is to be displayed in chemical injection delivery.
  • Such design choices may be implemented through the use of flow restrictors 327 of varying sizes as noted above or through dimensional variations in the body of the valve 325 itself. Indeed, for added variability a manifold 400 of differently tailored regulator mechanisms may be utilized simultaneously (see Fig. 4).
  • the diameter of the body of the piston head 355 is notably less than that of the spring and interfacing support structure.
  • the effective diameter of the seal is limited in a manner that may allow for an equilibrium to develop between the pressure in the chamber 320 and pressure surrounding the spring. Therefore, to ensure that the valve 325 remains closed, continuous flow of fluid 300 may be maintained.
  • the effective diameter of the seal may be increased by enlarging the piston head 355 to a degree that continuous flow of fluid 300 may not be necessary.
  • each regulator 410, 420, 430 may be set to close off at a different flow rate threshold as determined by spring, restrictor and other internal component factors as noted above.
  • a first regulator 430 may be configured for sealing upon exposure to a flow rate of 0.3 gallons per minute, a second regulator 420 for sealing upon exposure to 0.2 gallons per minute and a third regulator 410 to close off at 0.1 gallons per minute.
  • the regulators 430, 420, 410 would be sequentially closed off.
  • the sequential closing off of the regulators 430, 420, 410 as described above provides a system in which an overall wider range of flow rates and pressures may be utilized to achieve injection before completely shutting down an injection application.
  • a manifold 400 may be configured to govern a metered rate of injection where flow rate from the line 120 ranges up to about 0.3 gallons per minute and imparts up to several thousand PSI on any of the individual regulators 430, 420, 410.
  • a regulation mechanism 500 operates to regulate a flow of chemical injection fluid 300 with the aid of a control line 510, most likely of an electric variety, although other signaling platforms may be utilized.
  • the mechanism 500 regulates or meters the delivery of the injection fluid 300 by way of a valve 525, in this case shifted open or closed via signaling over the noted line 510. That is, in this embodiment, electric signaling may be utilized in place of flow control for regulating the chemical injection application. Regardless, this technique helps avoid undesired release of injection fluid 300 in circumstances where downhole pressures are substantially low.
  • the valve 525 may be directed to release the chemical injection fluid 300 through a port 579 as shown.
  • this ported release may again be directed at a variety of locations. This may include directing the fluid 300 to flow upstream with production fluid 110 before release into the tubing 180 so as to help prevent buildup at a port 577 thereat.
  • the fluid 300 is actually routed toward a flow control valve 527 that more directly meters the release of fluid 300 into the production tubing 180.
  • this valve 527 may be further guided by input from a viscosity 560, flow 540 or other sensor for tighter precision over the chemical injection release into the tubing 180 via a release port 577.
  • a regulation mechanism 500 may be utilized at a variety of site specific locations.
  • the mechanism 500 is utilized to guide and regulate chemical injection at a specific isolated zone of a downhole assembly. That is, the mechanism 500 is disposed in a region of the well 285 that is cased 280 and isolated by packers, 275, 575 in a manner targeting production from the specific production region 297.
  • a variety of different such production zones may be a part of the overall well architecture, each with its own discrete hardware and independently operating regulation mechanism 500 tailored to the production and conditions thereat.
  • a more site specific and overall tailored injection profile for the entire well 285 may be developed.
  • an injection line leading through a well may be supplied with a chemical fluid mixture as indicated at 610.
  • a column of fluid with its own column-based pressure at its downhole end is provided.
  • the mix may be flowed through the line to a downhole target location as indicated at 630.
  • downhole pressure is less than the column-based pressure, the potential exists for this to be achieved without the use of surface pumps or the like.
  • positive pressure may also be utilized as needed.
  • the system is equipped with a regulation mechanism that provides for the sealing off of the flow when desired by exceeding the rate to above a predetermined level (see 670).
  • a regulation mechanism that provides for the sealing off of the flow when desired by exceeding the rate to above a predetermined level (see 670).
  • this sealing may take place sole based on the flow resulting from a column-based pressure differential (see 610 proceeding directly to 670) or by intentionally pumping at a higher rate from surface.
  • the presence of the mechanism allows for early stage seal testing of the injection line and/or periodic testing during the life of the well without significant risk of such chemical fluid losses.
  • Embodiments described hereinabove include a chemical injection regulation mechanism that may be utilized to avoid expenses associated with the loss of chemical injection fluid into a well as a result of low downhole pressures. Once more, more dramatic consequences related to chemical fluid leakage and/or corresponding vacuum induced line closure may also be avoided. Such regulation is achieved in a manner which avoids any undesired downtime in injection capacity and even allows for early stage testing of chemical injection line sealing capacity. [0046] The preceding description has been presented with reference to presently preferred embodiments. Persons skilled in the art and technology to which these embodiments pertain will appreciate that alterations and changes in the described structures and methods of operation may be practiced without meaningfully departing from the principle, and scope of these embodiments. Regardless, the foregoing description should not be read as pertaining only to the precise structures described and shown in the accompanying drawings, but rather should be read as consistent with and as support for the following claims, which are to have their fullest and fairest scope.

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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)
  • Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)
  • Fire-Extinguishing By Fire Departments, And Fire-Extinguishing Equipment And Control Thereof (AREA)
  • Infusion, Injection, And Reservoir Apparatuses (AREA)

Abstract

L'invention concerne un mécanisme de régulation configuré pour fermer automatiquement un écoulement de fluide à travers une conduite sur la base d'un débit dépassant un niveau prédéterminé. Ce mécanisme peut être particulièrement utile lorsqu'il est employé conjointement avec des systèmes d'injection de produits chimiques de fond de puits qui sont dirigés vers des emplacements de puits enclins à devenir à basse pression par nature. Autrement dit, dans un système classique, une fois que la pression inhérente à l'extrémité de fond de puits d'une conduite d'injection dépasse celle de l'environnement de fond de puits adjacent, le débit de la colonne de fluide dans la conduite peut naturellement augmenter alors que du produit chimique est vidé dans le puits de façon non intentionnelle. Cependant, l'utilisation de modes de réalisation du mécanisme de régulation basé sur l'écoulement décrit en détail ici peut empêcher de façon quasi-automatique une telle vidange non désirable de produit chimique dans un puits à basse pression.
PCT/US2012/023701 2012-02-02 2012-04-10 Mécanisme de régulation d'injection chimique WO2013115824A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
BR112014018933A BR112014018933A8 (pt) 2012-02-02 2012-04-10 Mecanismo de regulagem de injeção química, conjunto de válvula, conjunto de distribuidor de injeção química, e método para regular injeção em um poço
GB1413655.0A GB2514033A (en) 2012-02-02 2012-04-10 Chemical injection regulation mechanism
NO20140959A NO20140959A1 (no) 2012-02-02 2014-08-04 Kjemikalieinjeksjons-reguleringsmekanisme

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US13/364,785 2012-02-02
US13/364,785 US20120199365A1 (en) 2011-02-03 2012-02-02 Chemical injection regulation mechanism

Publications (1)

Publication Number Publication Date
WO2013115824A1 true WO2013115824A1 (fr) 2013-08-08

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ID=46599885

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Application Number Title Priority Date Filing Date
PCT/US2012/023701 WO2013115824A1 (fr) 2012-02-02 2012-04-10 Mécanisme de régulation d'injection chimique

Country Status (5)

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US (1) US20120199365A1 (fr)
BR (1) BR112014018933A8 (fr)
GB (1) GB2514033A (fr)
NO (1) NO20140959A1 (fr)
WO (1) WO2013115824A1 (fr)

Families Citing this family (6)

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Publication number Priority date Publication date Assignee Title
US8714254B2 (en) 2010-12-13 2014-05-06 Schlumberger Technology Corporation Method for mixing fluids downhole
US8708049B2 (en) * 2011-04-29 2014-04-29 Schlumberger Technology Corporation Downhole mixing device for mixing a first fluid with a second fluid
US8826981B2 (en) 2011-09-28 2014-09-09 Schlumberger Technology Corporation System and method for fluid processing with variable delivery for downhole fluid analysis
US10030513B2 (en) 2012-09-19 2018-07-24 Schlumberger Technology Corporation Single trip multi-zone drill stem test system
CN103603640A (zh) * 2013-09-17 2014-02-26 南通中远船务工程有限公司 一种钻井泥浆系统的化学药品加药系统及其加药方法
GB2570582B (en) 2018-01-16 2022-04-20 Schlumberger Technology Bv Back flow restriction system and methodology for injection well

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US4932435A (en) * 1989-07-17 1990-06-12 Sundstrand Corporation Multi-stage flow regulating valve
US5487405A (en) * 1993-06-01 1996-01-30 Skoglund; Paul K. Flow control valve having flow adjustable by variable ring
US20050098210A1 (en) * 2003-10-27 2005-05-12 Strattan Scott C. Chemical injection check valve incorporated into a tubing retrievable safety valve
US20090078428A1 (en) * 2007-09-25 2009-03-26 Schlumberger Technology Corporation Flow control systems and methods

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US4010770A (en) * 1976-03-01 1977-03-08 W-K-M Wellhead Systems, Inc. Velocity flow control valve for fluid line
US4727903A (en) * 1987-06-26 1988-03-01 Malcolm B. Sturgis Fluid shutoff valve
US5215113A (en) * 1991-06-20 1993-06-01 Terry Paul E Precision safety shut-off valve
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US20090107563A1 (en) * 2005-09-06 2009-04-30 Donald Gary Eichler Safety valve having piston with modified orifice
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Publication number Priority date Publication date Assignee Title
US4932435A (en) * 1989-07-17 1990-06-12 Sundstrand Corporation Multi-stage flow regulating valve
US5487405A (en) * 1993-06-01 1996-01-30 Skoglund; Paul K. Flow control valve having flow adjustable by variable ring
US20050098210A1 (en) * 2003-10-27 2005-05-12 Strattan Scott C. Chemical injection check valve incorporated into a tubing retrievable safety valve
US20090078428A1 (en) * 2007-09-25 2009-03-26 Schlumberger Technology Corporation Flow control systems and methods

Also Published As

Publication number Publication date
GB201413655D0 (en) 2014-09-17
GB2514033A (en) 2014-11-12
BR112014018933A2 (fr) 2017-06-20
NO20140959A1 (no) 2014-08-13
US20120199365A1 (en) 2012-08-09
BR112014018933A8 (pt) 2017-07-11

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