WO2009081088A2 - Procédés d'introduction de pulsations dans les opérations de cimentation - Google Patents

Procédés d'introduction de pulsations dans les opérations de cimentation Download PDF

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Publication number
WO2009081088A2
WO2009081088A2 PCT/GB2008/003566 GB2008003566W WO2009081088A2 WO 2009081088 A2 WO2009081088 A2 WO 2009081088A2 GB 2008003566 W GB2008003566 W GB 2008003566W WO 2009081088 A2 WO2009081088 A2 WO 2009081088A2
Authority
WO
WIPO (PCT)
Prior art keywords
fluid
casing
well bore
pulses
cement
Prior art date
Application number
PCT/GB2008/003566
Other languages
English (en)
Other versions
WO2009081088A3 (fr
Inventor
Earl Webb
Henry E Rogers
Roger Schultz
Original Assignee
Halliburton Energy Services, Inc.
Curtis, Philip, Anthony
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., Curtis, Philip, Anthony filed Critical Halliburton Energy Services, Inc.
Publication of WO2009081088A2 publication Critical patent/WO2009081088A2/fr
Publication of WO2009081088A3 publication Critical patent/WO2009081088A3/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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
    • 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
    • E21B28/00—Vibration generating arrangements for boreholes or wells, e.g. for stimulating production

Definitions

  • the present invention relates to cementing operations, and, more particularly, methods and apparatuses for providing more competent cement bonds during and after cementing operations in well bores.
  • Settable compositions such as cement slurries may be used in primary cementing operations in which pipe strings, such as casing and liners, are cemented in well bores.
  • a cement may be pumped through the casing into an annulus between the walls of a well bore and the casing disposed therein.
  • the cement typically is pumped into this annulus until it reaches a predetermined height in the well bore to provide zonal isolation.
  • the cement cures in the annulus, thereby forming an annular sheath of hardened cement (e.g., a cement sheath) that supports and positions the pipe string in the well bore and bonds the exterior surface of the pipe string to the walls of the well bore.
  • Fluid or gas influx into the annulus and cement therein during the cement curing or "gelling" stage is quite common.
  • This fluid or gas influx can damage the cement bond between the well bore formation and the exterior surface of the casing.
  • the buildup of residues such as filter cake on or in the surface of the well bore also can prevent a complete bond between the cement and the well bore.
  • Figure 1 illustrates an example of such damage and incomplete bonding in a small section of formation 100 containing well bore 101 with casing 102.
  • Cement 103 fills annulus 104 between the walls of well bore 101 and the exterior surface of casing 102.
  • Pockets 105 and 106 illustrate examples of damage caused by fluid or gas influx.
  • channels will form between formation 100 and the exterior surface of casing 102, such as channels 107 and 108.
  • Influx damage can occur at the interface between cement 103 and well bore 100, or in the cement 103 itself.
  • Filter cake 109 also can prevent complete bonding between well bore 101 and cement 103.
  • Conventional methods of filter cake removal often rely on mechanical means such as scratchers with pipe reciprocation or require that cement 103 reach a specific annular velocity. These removal methods can be time-consuming and often leave filter cake residues behind, impeding bonding between cement 103 and well bore 101.
  • the present invention relates to cementing operations, and, more particularly, methods and apparatuses for providing more competent cement bonds during and after cementing operations in well bores.
  • a method for bonding a well bore to a casing therein may comprise the steps of introducing the casing into the well bore, directing pulses of fluid from within the casing into the well bore, and filling an annulus between an inner surface of the well bore and an outer surface of the casing with the fluid.
  • the step of directing pulses of fluid may performed while moving the casing further into the well bore.
  • the method may further comprise the step of selecting a frequency and pressure level for the pulses of fluid so as to reduce filter cake formed on the inner surface of the well bore.
  • the method may further comprise the step of vibrating well fluid at a resonance frequency for the well fluid.
  • the method may further comprise the step of vibrating the casing at a resonance frequency for the casing. Vibrating the casing at a resonance frequency may comprise the step of directing pulses of fluid into the well bore at a frequency and pressure selected to induce resonance vibrations in the casing.
  • the fluid may be a cement. If the fluid is a cement, the method may further comprise the step of selecting a frequency and pressure level for the pulses of fluid so as to reduce the amount non-cement material on the casing, and the method may further comprise the step of selecting a frequency and pressure level for the pulses of fluid so as to reduce filter cake formed on the inner surface of the well bore, such that the pulses have a dual-step profile.
  • a method for reducing fluid or gas migration into a fluid in an annulus formed between a surface of a well bore in a formation and a casing may comprising the step of inducing pressure pulses in the fluid before the fluid has cured.
  • the fluid may be a cement.
  • the method may further comprise the step of selecting a frequency and amplitude for the pressure pulses such that the pressure pulses prevent shear damage of the fluid during curing.
  • the step of inducing pressure pulses in fluid before the fluid has cured may comprise the step of inducing a low-amplitude pressure pulse. Additionally, or alternatively, the step of inducing pressure pulses in fluid before the fluid has cured may comprise the step of inducing a low-frequency pressure pulse.
  • the step of inducing pressure pulses in fluid before the cement has cured may comprise the step of inducing a pressure pulse having a dual-step profile.
  • Figure 1 illustrates conventional cement bonding.
  • Figure 2 illustrates a method for bonding a well bore to a casing in accordance with one embodiment of the present invention.
  • Figure 3 illustrates an alternate embodiment of a method for bonding a well bore to a casing.
  • Figure 4 illustrates yet another embodiment of a method for bonding a well bore to a casing.
  • Figure 5 illustrates various pressure pulses in accordance with one embodiment of the present invention.
  • Figure 6 illustrates a shear damage profile in accordance with one embodiment of the present invention.
  • Figure 7 illustrates a fluidic oscillator in accordance with one embodiment of the present invention.
  • Figure 8 illustrates an alternate embodiment of a method for bonding a well bore to a casing.
  • Figure 9 illustrates yet another embodiment of a method for bonding a well bore to a casing.
  • the present invention relates to cementing operations, and, more particularly, methods and apparatuses for providing more competent cement bonds during and after cementing operations in well bores.
  • a cementing operation involves attaching float shoe 110 to an end of casing 102 and introducing casing 102 into well bore 101. Cement 103 may then flow down the interior of casing 102 and out through float shoe 110 into annulus 104.
  • a reverse cementing operation may be used to place cement 103 in annulus 104. In either instance, as cement 103 enters annulus 104, it displaces material such as drilling fluid, filter cake, gas, or debris occupying annulus 104.
  • the material may be more completely replaced by cement 103 when pulsing or oscillation is used during the introduction of cement 103 into annulus 104.
  • a number of devices rely on fluid oscillation effects to create pulsating fluid flow. Generally, these devices connect to a source of fluid flow, provide a mechanism for oscillating the fluid flow between two different locations within the device and emit fluid pulses downstream of the source of fluid flow.
  • These "fluidic oscillator” 112 devices require no moving parts to generate the oscillations and have been used in various applications for which pulsating fluid flow is desired, such as massaging showerheads, flow meters, and windshield-wiper-fluid-supply units.
  • Specialized fluidic oscillator devices have been developed for the oilfield industry, such as, for example, the Pulsonix TF tool offered by Halliburton Energy Services, Inc. of Duncan, Oklahoma.
  • fluidic oscillator 112 may help mitigate fluid and/or gas migration during cement cure time.
  • fluidic oscillator 112 may be present in float shoe 110.
  • a feedback loop may be scaled and adapted to allow desired flow rates and cement passages to allow application into a Super Seal II float shoe by matching flow areas of the 2-3/4'" or 4-1/4" Super Seal II Valves. This may allow for filter cake 109 removal while running in hole using a top drive unit. Filter cake 109 may be removed more effectively by direct fluid impingement of the well bore 101.
  • TD total depth
  • Pulsing may break down gel strength, fragmenting or breaking down filter cake 109.
  • an additional benefit of fluidic oscillator 112 in float shoe 110 may be available in either standard or top drive applications.
  • cement 103 is displaced more effectively at the walls of well bore 101 and casing 102.
  • the oscillation effect tends to place cement 103 further into formation 100, compacting cement 103, which results in fewer voids due to filter cake contamination entrapment or consistency issues.
  • casing 102 may be set into resonance by the oscillation at float shoe 110. This resonance tends to prevent voids at the wall of casing 102.
  • the resonance and compaction effect continuously occurs from the beginning of the displacement until the top plug lands or pumping is discontinued.
  • frequency may be set such that the well bore fluids are set into resonance.
  • fluidic oscillator 112 Since each well will have different frequency variables, such as fluid, rate, and geometry, it may be particularly useful for fluidic oscillator 112 to have variable components.
  • a fluctuating or variable fluidic oscillator 112 may be used to allow for alternating resonance of casing 102 and well bore fluids.
  • a high frequency component, a low frequency component, or a combination of the two may enhance the effectiveness of the system.
  • These components may be further combined with either high or low amplitude components, or both.
  • variable rate or "dual-step profile" pumping may be used.
  • two or more fluidic oscillators 112 could be used to alternate between two or more resonances.
  • a specific design may be used for a specific well bore fluid system. As more cement 103 is pumped, resonant frequency will change. Thus it may be desirable for fluidic oscillator 112 to change based on changes in the system. This may be a result of monitoring of instrumentation measuring the level of excitation. This may be done with a sensor such as a hydrophone, a pressure transducer, a flow device, an accelerometer, or any number of other devices known in the art. This monitoring may allow for fluidic oscillator 112 to maintain resonance.
  • a sensor such as a hydrophone, a pressure transducer, a flow device, an accelerometer, or any number of other devices known in the art. This monitoring may allow for fluidic oscillator 112 to maintain resonance.
  • a pressure pulsation tool 114 may be optimized from its normal high amplitude/low frequency configuration to a low amplitude/low frequency tool by way of configurable inserts and pump rate control. Pressure pulsation tool 114 may be encapsulated in a canister and used in conjunction with a reservoir system to create a surface cement pulsation system to apply low pressure/low frequency pressure pulses to annulus 104 to delay the curing time and prevent fluid migration as a result of cement volume reduction.
  • Idealized pressure wave forms can be controlled to provide optimal pulsation and help prevent shear of cement 103 during dehydration. Examples of what the inventors envision as optimal pressure pulses are illustrated in Figure 5. These profiles may prevent shear damage to cement 103, as indicated in Figure 6.
  • FIG. 7 Yet another embodiment involves a low cost "tubing" size fluidic oscillator 112, as shown in Figure 7.
  • This fluidic oscillator 112 may be composed of phenolic inserts cemented into a low cost case.
  • Cement 103 may be fairly resistant to acid, thus allowing application to hydraulic work order ("HWO") or Well Intervention applications in addition to cementing applications.
  • HWO hydraulic work order
  • Well Intervention applications in addition to cementing applications.
  • FIG. 8 The concept of "pulsing" the top plug after catching cement is illustrated in Figure 8.
  • a pulse generator capable of pumping cement may allow for pulsing on the fly or, as illustrated, pulsing of the displacement fluid could be accomplished.
  • Pulsation or oscillation may be used to set more competent balanced plugs. Shown in Figure 9 is an oscillation guide shoe 113 used with either the tubing release tool ("TRT”) or bottom hole kickoff assembly (“BHKA”) tool. Retrieving drillpipe adapter and collet retainer 115 may be removed as releasing plug 116 is latched and collet is disengaged, releasing tubing. Alternatively, pressure pulsation may be used during hesitant squeeze cementing (not shown).
  • TRT tubing release tool
  • BHKA bottom hole kickoff assembly
  • This disclosure covers two basic fluid energy principles: fluidic oscillation and pressure pulsing technology. These two principles can be used during or after the cementing job. This technology is adaptable for both primary cementing and setting of balanced plugs.
  • This technology potentially could reduce sustained casing pressure which is a major concern particularly offshore.
  • Earlier methods do not consider the advantage of inducing fluid energies by fluidic oscillation or pressure pulsation methods. This methodology greatly enhances the chances for competent cement bonding.
  • every range of values (of the form, "from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b") disclosed herein is to be understood as referring to the power set (the set of all subsets) of the respective range of values, and set forth every range encompassed within the broader range of values.
  • the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and cleariy defined by the patentee.

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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)
  • Pipe Accessories (AREA)
  • Adhesives Or Adhesive Processes (AREA)

Abstract

L'invention concerne un procédé de scellement d'un tubage dans un puits de forage, pouvant comprendre plusieurs étapes. Le tubage peut être introduit dans le puits de forage et des pulsations de fluide peuvent être dirigées de l'intérieur du tubage vers le puits de forage. Un espace annulaire entre une surface intérieure du puits de forage et une surface extérieure du tubage peut être rempli de fluide. Un procédé destiné à réduire la migration de fluides ou de gaz en direction d'un fluide présent dans l'espace annulaire peut comprendre la création de pulsations de pression dans le fluide avant que celui-ci n'ait durci.
PCT/GB2008/003566 2007-12-20 2008-10-20 Procédés d'introduction de pulsations dans les opérations de cimentation WO2009081088A2 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US11/961,458 2007-12-20
US11/961,458 US20090159282A1 (en) 2007-12-20 2007-12-20 Methods for Introducing Pulsing to Cementing Operations

Publications (2)

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WO2009081088A2 true WO2009081088A2 (fr) 2009-07-02
WO2009081088A3 WO2009081088A3 (fr) 2010-01-21

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Cited By (26)

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US8235128B2 (en) 2009-08-18 2012-08-07 Halliburton Energy Services, Inc. Flow path control based on fluid characteristics to thereby variably resist flow in a subterranean well
US8261839B2 (en) 2010-06-02 2012-09-11 Halliburton Energy Services, Inc. Variable flow resistance system for use in a subterranean well
US8276669B2 (en) 2010-06-02 2012-10-02 Halliburton Energy Services, Inc. Variable flow resistance system with circulation inducing structure therein to variably resist flow in a subterranean well
US8356668B2 (en) 2010-08-27 2013-01-22 Halliburton Energy Services, Inc. Variable flow restrictor for use in a subterranean well
US8418725B2 (en) 2010-12-31 2013-04-16 Halliburton Energy Services, Inc. Fluidic oscillators for use with a subterranean well
US8430130B2 (en) 2010-09-10 2013-04-30 Halliburton Energy Services, Inc. Series configured variable flow restrictors for use in a subterranean well
US8616290B2 (en) 2010-04-29 2013-12-31 Halliburton Energy Services, Inc. Method and apparatus for controlling fluid flow using movable flow diverter assembly
US8646483B2 (en) 2010-12-31 2014-02-11 Halliburton Energy Services, Inc. Cross-flow fluidic oscillators for use with a subterranean well
US8657017B2 (en) 2009-08-18 2014-02-25 Halliburton Energy Services, Inc. Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system
US8678035B2 (en) 2011-04-11 2014-03-25 Halliburton Energy Services, Inc. Selectively variable flow restrictor for use in a subterranean well
US8684094B2 (en) 2011-11-14 2014-04-01 Halliburton Energy Services, Inc. Preventing flow of undesired fluid through a variable flow resistance system in a well
US8733401B2 (en) 2010-12-31 2014-05-27 Halliburton Energy Services, Inc. Cone and plate fluidic oscillator inserts for use with a subterranean well
US8739880B2 (en) 2011-11-07 2014-06-03 Halliburton Energy Services, P.C. Fluid discrimination for use with a subterranean well
US8844651B2 (en) 2011-07-21 2014-09-30 Halliburton Energy Services, Inc. Three dimensional fluidic jet control
US8851180B2 (en) 2010-09-14 2014-10-07 Halliburton Energy Services, Inc. Self-releasing plug for use in a subterranean well
US8863835B2 (en) 2011-08-23 2014-10-21 Halliburton Energy Services, Inc. Variable frequency fluid oscillators for use with a subterranean well
US8893804B2 (en) 2009-08-18 2014-11-25 Halliburton Energy Services, Inc. Alternating flow resistance increases and decreases for propagating pressure pulses in a subterranean well
US8950502B2 (en) 2010-09-10 2015-02-10 Halliburton Energy Services, Inc. Series configured variable flow restrictors for use in a subterranean well
US8955585B2 (en) 2011-09-27 2015-02-17 Halliburton Energy Services, Inc. Forming inclusions in selected azimuthal orientations from a casing section
US8991506B2 (en) 2011-10-31 2015-03-31 Halliburton Energy Services, Inc. Autonomous fluid control device having a movable valve plate for downhole fluid selection
US9127526B2 (en) 2012-12-03 2015-09-08 Halliburton Energy Services, Inc. Fast pressure protection system and method
US9260952B2 (en) 2009-08-18 2016-02-16 Halliburton Energy Services, Inc. Method and apparatus for controlling fluid flow in an autonomous valve using a sticky switch
US9291032B2 (en) 2011-10-31 2016-03-22 Halliburton Energy Services, Inc. Autonomous fluid control device having a reciprocating valve for downhole fluid selection
US9404349B2 (en) 2012-10-22 2016-08-02 Halliburton Energy Services, Inc. Autonomous fluid control system having a fluid diode
US9506320B2 (en) 2011-11-07 2016-11-29 Halliburton Energy Services, Inc. Variable flow resistance for use with a subterranean well
US9695654B2 (en) 2012-12-03 2017-07-04 Halliburton Energy Services, Inc. Wellhead flowback control system and method

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US9567819B2 (en) 2009-07-14 2017-02-14 Halliburton Energy Services, Inc. Acoustic generator and associated methods and well systems
AU2010288346B2 (en) * 2009-08-25 2015-04-09 Halliburton Energy Services, Inc. Sonically activating settable compositions and methods of activating them
US8047282B2 (en) * 2009-08-25 2011-11-01 Halliburton Energy Services Inc. Methods of sonically activating cement compositions
US8726993B2 (en) 2010-05-27 2014-05-20 Claude E Cooke, Jr. Method and apparatus for maintaining pressure in well cementing during curing
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US8453745B2 (en) 2011-05-18 2013-06-04 Thru Tubing Solutions, Inc. Vortex controlled variable flow resistance device and related tools and methods
US9212522B2 (en) 2011-05-18 2015-12-15 Thru Tubing Solutions, Inc. Vortex controlled variable flow resistance device and related tools and methods
US8424605B1 (en) * 2011-05-18 2013-04-23 Thru Tubing Solutions, Inc. Methods and devices for casing and cementing well bores
US8573066B2 (en) 2011-08-19 2013-11-05 Halliburton Energy Services, Inc. Fluidic oscillator flowmeter for use with a subterranean well
AR089305A1 (es) 2011-12-19 2014-08-13 Impact Technology Systems As Metodo y sistema para generacion de presion por impacto
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US9394759B2 (en) 2009-08-18 2016-07-19 Halliburton Energy Services, Inc. Alternating flow resistance increases and decreases for propagating pressure pulses in a subterranean well
US9260952B2 (en) 2009-08-18 2016-02-16 Halliburton Energy Services, Inc. Method and apparatus for controlling fluid flow in an autonomous valve using a sticky switch
US8327885B2 (en) 2009-08-18 2012-12-11 Halliburton Energy Services, Inc. Flow path control based on fluid characteristics to thereby variably resist flow in a subterranean well
US9109423B2 (en) 2009-08-18 2015-08-18 Halliburton Energy Services, Inc. Apparatus for autonomous downhole fluid selection with pathway dependent resistance system
US8657017B2 (en) 2009-08-18 2014-02-25 Halliburton Energy Services, Inc. Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system
US8931566B2 (en) 2009-08-18 2015-01-13 Halliburton Energy Services, Inc. Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system
US8905144B2 (en) 2009-08-18 2014-12-09 Halliburton Energy Services, Inc. Variable flow resistance system with circulation inducing structure therein to variably resist flow in a subterranean well
US8479831B2 (en) 2009-08-18 2013-07-09 Halliburton Energy Services, Inc. Flow path control based on fluid characteristics to thereby variably resist flow in a subterranean well
US8893804B2 (en) 2009-08-18 2014-11-25 Halliburton Energy Services, Inc. Alternating flow resistance increases and decreases for propagating pressure pulses in a subterranean well
US8235128B2 (en) 2009-08-18 2012-08-07 Halliburton Energy Services, Inc. Flow path control based on fluid characteristics to thereby variably resist flow in a subterranean well
US8714266B2 (en) 2009-08-18 2014-05-06 Halliburton Energy Services, Inc. Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system
US9133685B2 (en) 2010-02-04 2015-09-15 Halliburton Energy Services, Inc. Method and apparatus for autonomous downhole fluid selection with pathway dependent resistance system
US8622136B2 (en) 2010-04-29 2014-01-07 Halliburton Energy Services, Inc. Method and apparatus for controlling fluid flow using movable flow diverter assembly
US8708050B2 (en) 2010-04-29 2014-04-29 Halliburton Energy Services, Inc. Method and apparatus for controlling fluid flow using movable flow diverter assembly
US8757266B2 (en) 2010-04-29 2014-06-24 Halliburton Energy Services, Inc. Method and apparatus for controlling fluid flow using movable flow diverter assembly
US8985222B2 (en) 2010-04-29 2015-03-24 Halliburton Energy Services, Inc. Method and apparatus for controlling fluid flow using movable flow diverter assembly
US8616290B2 (en) 2010-04-29 2013-12-31 Halliburton Energy Services, Inc. Method and apparatus for controlling fluid flow using movable flow diverter assembly
US8261839B2 (en) 2010-06-02 2012-09-11 Halliburton Energy Services, Inc. Variable flow resistance system for use in a subterranean well
US8276669B2 (en) 2010-06-02 2012-10-02 Halliburton Energy Services, Inc. Variable flow resistance system with circulation inducing structure therein to variably resist flow in a subterranean well
US8376047B2 (en) 2010-08-27 2013-02-19 Halliburton Energy Services, Inc. Variable flow restrictor for use in a subterranean well
US8356668B2 (en) 2010-08-27 2013-01-22 Halliburton Energy Services, Inc. Variable flow restrictor for use in a subterranean well
US8464759B2 (en) 2010-09-10 2013-06-18 Halliburton Energy Services, Inc. Series configured variable flow restrictors for use in a subterranean well
US8950502B2 (en) 2010-09-10 2015-02-10 Halliburton Energy Services, Inc. Series configured variable flow restrictors for use in a subterranean well
US8430130B2 (en) 2010-09-10 2013-04-30 Halliburton Energy Services, Inc. Series configured variable flow restrictors for use in a subterranean well
US8851180B2 (en) 2010-09-14 2014-10-07 Halliburton Energy Services, Inc. Self-releasing plug for use in a subterranean well
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US20090159282A1 (en) 2009-06-25

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