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
  • E21B27/00—Containers for collecting or depositing substances in boreholes or wells, e.g. bailers, baskets or buckets for collecting mud or sand; Drill bits with means for collecting substances, e.g. valve drill bits
  • E21B27/02—Dump bailers, i.e. containers for depositing substances, e.g. cement or acids

Definitions

• the present disclosure relates to well bore operations, and, more particularly, to methods and apparatuses for releasing a chemical into a well bore upon command
• 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, for example, through the casing into an annulus between the walls of a well bore and the casing disposed therein
• the cement may be pumped into the annulus until it reaches a predetermined height in the well bore to provide zonal isolation
• the cement may cure 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 extenor surface of the pipe st ⁇ ng to the walls of the well bore
• a deployment means to release one or more chemicals into the annulus between the well bore and the casing so that the chemical need not be pumped from the surface at the top of the well bore Moreover, in the case of cementing operations, it may be desirable to not activate a cement composition in the annulus until a specific time chosen by an operator Providing such a deployment means may entail a number of complications such as complex and expensive equipment and procedures Therefore, it may be desirable to have methods and apparatuses for chemical deployment that are inexpensive, not complex, and require minimal modification to existing proceduies such as cementing procedures
• the present disclosure relates to well bore operations, and, more particularly, to methods and apparatuses for ieleasing a chemical into a well bore upon command
• theie is piovided a method foi i eleasing a chemical in a well boie
• a casing st ⁇ ng is piovided, and at least one housing membei is coupled to the casing stung, wheie the housing membei is coupled to a chemical leservon
• a fluid is introduced into a space between an inner surface of the well bore and an outer surface of the casing string.
• a chemical is released from the chemical reservoir into the fluid.
• an apparatus for releasing a chemical in a well bore includes a curved member configured for coupling to a casing, and at least one hollow member is connected to the curved member.
• a chemical container is disposed, at least in part, within the hollow space, and the hollow member extends at least partially around a hollow space.
• an apparatus for setting cement in a well bore includes a casing string and at least one housing member coupled to the casing string and disposed adjacent to an external surface of the casing string.
• the apparatus also includes a chemical container disposed between the housing member and the external surface of the casing string.
• a method for releasing a chemical in a well bore in this aspect, a casing string is provided, and the casing string includes a casing collar that includes a chemical reservoir. A fluid is introduced into a space between an inner surface of the well bore and an outer surface of the casing string. A chemical is released from the chemical reservoir into the fluid.
• an apparatus for releasing a chemical in a well bore includes casing collar configured to connect to a section of a casing string.
• a chemical container is disposed within the casing collar, and the casing collar is configured to release a chemical from the chemical reservoir.
• an activator collar is connected between sections of a casing string.
• the activator collar and the sections are positioned in a well bore.
• a non-activated cementitious material is introduced into the well bore.
• a chemical is released from the chemical reservoir into the well bore.
• Figure 1 illustrates a cross-sectional view of a casing st ⁇ ng in accordance with certain embodiments of the present disclosure
• Figures 2a and 2b illustrate cross-sectional views of casing and a casing collar in accordance with certain embodiments of the present disclosure
• Figure 3 illustrates a method for bonding a well bore to a casing in accordance with certain embodiments of the present disclosure
• Figures 4a and 4b illustrate cross-sectional views of casing and a casing collar in accordance with certain embodiments of the present disclosure
• Figure 5 illustrates a cross-sectional view of a casing st ⁇ ng in accordance with certain embodiments of the present disclosure
• Figures 6a and 6b illustrate cross-sectional views of casing and a casing collar in accordance with certain embodiments of the present disclosure
• Figure 7 illustrates a method for bonding a well bore to a casing in accordance with certain embodiments of the present disclosure
• Figure 8 illustrates a cross-sectional view of casing and a casing collar in accordance with certain embodiments of the present disclosure
• Figures 9a and 9b illustrate cross-sectional views of casing and a casing collar in accordance with certain embodiments of the present disclosure
• FIGS 10a and 10b illustrate side and axial views of a centralizer in accordance with certain embodiments of the piesent disclosure
• Figure 1 1 illustrates a cross-sectional view of casing and a centralizer in accoi dance with certain embodiments of the piesent disclosure
• Figure 12 illustrates a cross-sectional view of casing and a centralizer in accoi dance with certain embodiments of the piesent disclosuie
• Figure 13 illustrates a cioss-sectional view of casing and a centralizer in accoi dance with certain embodiments of the present disclosuie
• the present disclosure relates to well bore operations, and, more particularly, to methods and apparatuses for releasing a chemical into a well bore upon command Stated otherwise, the present disclosure may allow an operator to choose a specific time at which one or more chemicals may be released into an annulus
• the subterranean well fluids useful in the present disclosure may be permitted to remain in a slurry state for a desired time before being activated through the addition of an activator released from an improved casing st ⁇ ng
• a cementing operation involves introducing a casing st ⁇ ng into a well bore A cement composition may then be pumped down the interior of the casing st ⁇ ng, with a bottom plug and a top plug installed so that a cement column may be placed in between the plugs A displacement fluid may push the cement column and plugs down the well bore The bottom plug may then be landed and pump pressure may cause a frangible element withm the bottom plug to rupture, allowing the cement m the casing to be pumped through the bottom plug and a float shoe, and then up into the annular space between the casing and the well bore When all the cement has been pumped through the bottom plug the top plug may land on the bottom plug
• cement may be placed into the annulus by what is known in the art as a reverse cementing operation In either case, as the placed cement sets, it bonds the casing st ⁇ ng to a portion of the subterranean
• a cementitious mate ⁇ al placed in the annulus may be non-activated Thereafter, an operator may initiate the setting of the cementitious mate ⁇ al "on-command" by choosing a specific time at which to release an activation agent into the non-activated cementitious mate ⁇ al The moment of initiation maybe chosen any time after cementitious mate ⁇ al is in place within the well bore
• the subterranean well fluids used in the piesent disclosuie include a hydiaulic cement
• a va ⁇ ety of hydraulic cements may be suitable for use including those compiising calcium, aluminum, silicon, oxygen, and/or sulfur, which may set and haiden by ieaction with water
• Such hydiaulic cements include, but aie not limited to, Portland cements, pozzolanic cements, gypsum cements, high alumina content cements, silica cements, and high alkalinity cements.
• Cementitious material comprising shale or blast furnace slag, fly ashes, and fumed silica also may be suitable for use in the present disclosure.
• the shale may include vitrified shale; in certain other embodiments, the shale may include raw, unfired shale, or a mixture of raw shale and vitrified shale.
• cement hydration may be activated with conventional cement accelerators.
• the activator may include but is not limited to sodium hydroxide, sodium carbonate, amine compounds, salts comprising calcium, sodium, magnesium, aluminum, and/or mixtures thereof.
• the activator may comprise a calcium salt such as calcium chloride.
• the activator may comprise a sodium salt such as sodium chloride, sodium aluminate, and/or sodium silicate.
• the activator may comprise a magnesium salt such as magnesium chloride.
• the activator may comprise amine compounds such as triethanol amine, tripropanol amine, tri-isopropanol amine, and/or diethanol amine.
• the activator will be released in a sufficient amount to set the cement within about 1 minute to about 24 hours.
• the concentration may be in the range of from about 3% to about 15% by weight of the cement in the cement slurry.
• the concentration may be in the range of from about 0.5% to about 5% by weight of the cement in the cement slurry.
• the activator may "flash-set" the cement slurry.
• flash-set will be understood to mean the initiation of setting of the cement slurry within about 1 minute to about 15 minutes after contacting the released activator.
• the previously identified activators may flash set the cement slurry. Flash-set activators may include sodium hydroxide, sodium carbonate, potassium carbonate, bicarbonate salts of sodium or potassium, sodium silicate salts, sodium aluminate salts, ferrous and ferric salts ⁇ e.g., ferric chloride and ferric sulfate), polyacrylic acid salts, and/or others.
• the following activators can flash-set the cement slurry based on these activators exceeding a specified concentration: calcium nitrate, calcium acetate, calcium chloride, and/or calcium nitrite.
• a strongly-retarded cement may be activated by degrading the retarder with an oxidizing agent.
• Suitable oxidizing agents may be either inorganic (e.g., sodium persulfate, sodium bromate, sodium chlorate) or organic (e.g., di-t-butyl peroxide, dicumyl peroxide, t-butyl hydroperoxide), depending on the temperature and type of retarder used. Any suitable activation system which may be deployed in the manner described herein may be used.
• Figure 1 shows cross-sectional view of an exemplary embodiment of casing string 100 inserted into well bore 1 10 after well bore 1 10 has been drilled to a desired depth below the surface into subterranean formation 120.
• Annulus 130 may be formed between casing string 100 and subterranean formation 120.
• Casing string 100 may include a series of interconnected sections of casing 140. These sections of casing 140 may be connected by activation collars 150.
• Activation collars 150 may be placed in casing string 100 and cemented in a manner similar to that used with standard casing collars.
• a casing collar may be configured to be an activation collar 150.
• Casing string 100 may be positioned in the well bore with activation collars 150 installed between sections of casing 140 at all connections of sections of casing 140.
• activation collars 150 may be used at one or more selected locations in casing string 100 which may correspond to specific well bore locations in the well once the entire casing string 100 to be cemented has been installed.
• a non-activated condition may be maintained for a long period of time with no setting of the material. If complications are encountered in completing cementing operations, there may be no danger of the cement setting during this non-activated condition, thereby possibly eliminating major remediation or causing loss of the well due to having hardened cement where it is not desired.
• additional pressure may be applied to displacement fluid within casing string 100. The additional pressure may be communicated to an activation collar 150.
• Activation collar 150 may be configured to release one or more chemicals in response to a pressure increase in the casing string 100.
• FIG. 2a illustrates a cross-sectional view showing details of an exemplary activation collar 200, corresponding to activation collars 150 in Figure 1, before operation.
• Activation collar 200 may include a hollow, generally cylindrically shaped housing 210.
• the activation collars disclosed herein may be manufactured, depending upon the particular use, from a variety of materials used for conventional casing collars, including, but not limited to, ferrous materials, aluminum, titanium, and/or fiberglass.
• Activation collar 200 may further include collar threading on one or more surfaces of housing 210 as means of connecting to casing threading of sections of casing 220. It should be understood by those skilled in the art that, in certain embodiments of the present disclosure, alternative means of connecting to sections of casing 220 may be employed. Generally, conventional sections of casing disclosed herein, depending upon the particular use, may be manufactured from a variety of materials, including, but not limited to, ferrous materials, aluminum, titanium, and/or fiberglass.
• Housing 210 may include one or more rupture elements 230.
• Rupture element 230 may be, for example, a rupture disk or other frangible element configured to mechanically break down or otherwise allow fluid communication in response to a given pressure on an interior surface of housing 210.
• Rupture element 230 may be configured to rupture at a predetermined pressure.
• Housing 210 may further include one or more pistons 240, one or more chemical reservoirs 250, and one or more outlets 260.
• One or more pistons 240 may be moveable and configured to compress the volume of the chemical reservoir 250 in response to pressure communicated from the interior of housing 210.
• Chemical reservoir 250 may be any suitable containment of an activation agent.
• An outlet 260 may be an open port between the chemical reservoir 250 and the exterior of housing 210. Outlet 260 may be appropriately sized such that the pressure balance associated with the exterior of housing 210 prevents the activation agent from exiting the chemical reservoir 250 until piston 240 decreases the volume of chemical reservoir 250 or until its volume is otherwise reduced.
• outlet 260 may include another sealing element, a wax-like substance, for example, to prevent the activation agent from exiting the chemical reservoir 250 until piston 240 has sufficiently compressed chemical reservoir 250.
• a sealing element a wax-like substance, for example.
• FIG. 2b illustrates a cross-sectional view showmg details of exemplary activation collar 200 after rupture element 230 has allowed fluid communication between the inte ⁇ or of housing 210 and piston 240 Piston 240 is shown as having compressed chemical reservoir 250, after activation agent 270 has been expressed through outlet 260 into the annulus Subsequent or simultaneous rotation and/or reciprocation of the casing st ⁇ ng may be used to distnbute the activation agent 270 within the fluid in the annulus Activation collar 200 may also be configured to meter out activation agent 270 slowly, or at any predetermined rate To facilitate distribution, the casing string may be rotated and/or reciprocated while and/or after the activation agent is released The casing st ⁇ ng may then be positioned in its final desired location before the activator causes the cement to set
• FIG 3 is a process flow diagram for an exemplary activation collar running procedure 300
• activation collars may be installed on standard casing, or collars may be installed between standard casing joints, p ⁇ or to introduction of a cementitious material into the well bore
• the casing st ⁇ ng may be placed into the well bore
• the cement may be pumped according to standard procedures
• the top plug may be slowly seated while pumping the cement
• sufficient rupture pressure on top plug may be provided so that the collars may be activated before plug rupture occurs
• pressure on the casing may be increased to a level sufficient to activate collars and deploy the activation chemicals
• the casing string may be reciprocated and/or rotated to mix the activator within the cement slurry
• the casing st ⁇ ng may be positioned and maintained at a desired depth until cement hardening
• FIG. 4a and 4b show details of another embodiment of the present disclosure
• Figure 4a illustrates a cioss-sectional view showing an exemplary activation collar 400 before activation agent 450 has been expressed through outlet 460 into the annulus
• activation collai 400 may include a tension sleeve 430 that holds two expelling pistons 440 togethei
• the tensile sitength of tension sleeve 430 may be exceeded so that it will bieak, theieby allowing pistons 440 to force activation agent 450 thiough port 460 and to the exterior of housing 410
• Figuie 4b illustrates activation collar 400 after tension sleeve 430 has given way and allowed activation agent to be expressed through outlet 460 into the annulus.
• point-distributed activation collars and methods are provided where "doses" of one or more chemicals and/or an activation agent may be introduced at one or more points along a casing string. If necessary, the casing string may be reciprocated and/or rotated to facilitate mixing an activation agent with a fluid in the annulus. Certain embodiments of this invention may eliminate the need for external or internal attachments to a casing string for deployment of an activation agent. Certain embodiments allow for activator distribution within an entire cross-section of an annulus. The equipment and procedures for certain embodiments are not complex, require minimal modification to existing cementing procedures, and have low operating risks.
• FIG. 5 illustrates a cross-sectional view showing another embodiment of the invention.
• Casing string 500 may be inserted into well bore 510 after well bore 510 has been drilled.
• Annulus 530 may be formed between casing string 500 and subterranean formation 520.
• Casing string 500 may include a series of interconnected sections of casing 540. These sections of casing 540 may be connected by activation collars 550.
• Activation collars 550 may be placed in casing string 500 to be cemented in a manner similar to how standard casing collars would be used.
• Casing string 500 may be positioned in well bore 510 with activation collars 550 installed between sections of casing 140 at all connections of sections of casing 540.
• activation collars 550 may be used at one or more selected locations in casing string 500 which correspond to specific well bore locations in well bore 510 once the entire casing string 500 to be cemented is installed.
• FIG. 6a illustrates a cross-sectional view showing details of an exemplary activation collar 600, corresponding to the activation collars 550 in Figure 5, before operation.
• Activation collar 600 may include an inner housing member 610 coupled to sections of casing 620.
• Inner housing member 610 may further include collar threading on one or more surfaces of housing 610 as means of connecting to casing threading of sections of casing 620. It should be understood by those skilled in the art that, in certain embodiments of the present disclosure, alternative means of connecting to sections of casing 620 may be employed.
• Activation collar 600 may further include an outer housing member 630 coupled to inner housing member 610.
• Outer housing member 630 may be coupled to inner housing member 610 by a threaded engagement that allows rotational movement and causes the outer housing member 630 to move axially with respect to inner housing member 610.
• a threaded engagement that allows rotational movement and causes the outer housing member 630 to move axially with respect to inner housing member 610.
• a chemical reservoir 640 may be defined by inner housing member 610 and outer housing member 630.
• Chemical reservoir 640 may be any suitable means of containing one or more chemicals and/or activation agent.
• Activation collar 600 may be configured so that a relative rotation between inner housing member 610 and outer housing member 630 changes the volume of chemical reservoir 640.
• Activation collar 600 may further include one or more outlets 650.
• An outlet 650 may be an open port between the chemical reservoir 640 and the exterior of outer housing member 630. Outlet 650 may be appropriately sized such that the pressure balance of associated with the exterior of outer housing member 630 prevents the activation agent from exiting the chemical reservoir 640 until the volume of chemical reservoir 640 is decreased.
• outlet 650 may include another sealing element, such as a wax-like substance, to prevent the activation agent from exiting the chemical reservoir 650 until chemical reservoir 650 has been sufficiently compressed.
• Activation collar 600 may further include one or more bowed spring members— centralizer members 660.
• Centralize! members 660 may be coupled to outer housing member 630 to allow centralizer members 660 to contact surfaces of the well bore when attached to a casing string downhole. Centralizer members 660 may accordingly provide resistance to rotation so that outer housing member 630 may tend to remain stationary.
• a centralizer member 660 may be of another type of projecting member designed to make contact with a surface of a well bore and may not necessarily be designed to provide a centralizing function
• Activation collar 600 may be configured so that a predetermined number of rotations of casing string 500 will actuate activation collar 600 and release an activation agent
• Casing st ⁇ ng 500 may also be reciprocated axially along well bore 500 to fa ⁇ htate chemical dispersion
• centrahzer members 660 may make contact with surfaces of the well bore and hold outer housing member 630 stationary, thereby allowing relative rotation between casing st ⁇ ng 500 and outer housing member 630
• a threaded engagement between outer housing member 630 and inner housing member 610 allows outer housing member 630 to move axially with respect to inner housing member 610
• Chemical reservoir 640 accordingly may be reduced in volume due to the axial relative movement
• Figure 6b illustrates a cross-sectional view showing details of exemplary activation collar 600 after outer housing member 630 has moved axially with respect to inner housing member 610
• Outer housing member 630 and inner housing member 610 are shown as having compressed chemical reservoir 640, and activation agent 670 that has been expelled through outlet 650 into the annulus Concurrent or subsequent rotation and/or reciprocation of casing st ⁇ ng 500 may distnbute the activation agent 670 within the fluid m the annulus Activation collar 600 may also be configured to meter out activation agent 670 slowly while the casing st ⁇ ng is being rotated and/or reciprocated to facilitate dist ⁇ bution Casing st ⁇ ng 500 may then be positioned in its final desired location before the activator causes the cementitious mate ⁇ al to set
• FIG. 7 shows a piocess flow diagiam for an exemplaiy activation collar i mining pioceduie 700
• activation collais may be installed on standaid casing, oi collais may be installed between standard casing joints, p ⁇ oi to intioducmg a cementitious mate ⁇ al into the well bore
• the casing stung may be iun into the well boie
• the cement may be introduced into the well boie accoidmg to standaid pioceduies hi step 740, the casing st ⁇ ng may be iotated and/oi iecipiocated to i el ease the activator and to mix the activator with the cement slurry.
• the casing st ⁇ ng may be placed and maintained in its final position until cement hardening.
• FIG. 8 illustrates a cross-sectional view showing details of an exemplary activation collar 800.
• Activation collar 800 corresponds to activation collar 600, but alternatively may include one or more centralizer members 810 at an angle with respect to a longitudinal axis of the casing string. Angling of centralizer members 810 may be used to minimize premature actuation of activation collar 800 when centralizer members 810 are in contact with surfaces of the well bore.
• the orientation and angle of centralizer members 810 may be configured to, in conjunction with surfaces of the well bore, bias outer housing member 820 in the rotational direction that is opposite to the direction which actuates activation collar 800.
• Figure 9a and 9b show details of another embodiment of the present disclosure.
• Figure 9a illustrates a cross-sectional view showing an exemplary activation collar 900 before activation agent 940 has been expressed through outlet 950 into the annulus.
• activation collar 900 may include a j-slot or ratchet type release mechanism that may allow reciprocating motion to compress chemical reservoir 940, thereby expressing one or more chemicals into the annulus.
• Activation collar 900 may include an inner housing member 910 and an outer housing member 930 coupled together at least in part by one or more lugs 970 and a j-slot path 980.
• one or more lugs 670 may be attached to outer housing member 930, and inner housing member 910 may include one or more j-slot paths 980. Lug 970 may follow j-slot path 980 as the casing is moved up and down. J-slot path 980 may be configured so that, after a certain number of reciprocation cycles, lug 970 may follow a longer j-slot path section 990 which may allow relative motion between inner housing member 910 and outer housing member 930 to sufficiently compress a volume of chemical reservoir 940.
• Figure 9b illustrates activation collar 900 after chemical reservoir 940 has been compressed and one or more chemicals have been expressed through outlet 950 into the annulus.
• rotationally operated activation collars and methods where "doses" of one or more chemicals and/or an activation agent may be introduced at one or more points along a casing st ⁇ ng, without providing a potential leak path from the annulus to an intenor diameter of the casing st ⁇ ng
• the casing st ⁇ ng may be reciprocated and/or rotated to facilitate mixing an activation agent with a fluid m the annulus
• Certain embodiments of this invention do not require external or internal attachments to casing st ⁇ ng for deployment of an activation agent
• Certain embodiments allow for activator dist ⁇ bution within an entire cross- section of an annulus containing a cementitious mate ⁇ al
• the equipment and procedures for certain embodiments are not complex, require minimal modification to existing cementing procedures, and have low operating ⁇ sks
• Figure 10a and 10b shows another exemplary embodiment of the invention
• Figure 10a illustrates straight blade centrahzer 1000
• Figure 10b illustrates an axial view of straight blade centrahzer 1000
• Straight blade centrahzer 1000 may be attached to the outside of a casing stnng in the same manner that a conventional centrahzer may be attached to a casing st ⁇ ng according to standard practice in the oil and gas industry
• Straight blade centrahzer 1000 may include one or more collars 1010 that may be generally cyhnd ⁇ cal or curved and designed to wrap at least partially around a casing section
• Straight blade centrahzer 1000 may further include a plurality of hollow blades 1020 connected to the one or more collars 1010 Each hollow blade 1020 may form a substantially complete enclosure of around a hollow space Alternatively, each hollow blade 1020 may form only a partially covered hollow space For example, a hollow space may be exposed on the intenor side of a hollow blade 1020 (z e , the side closest the longitudinal axis of straight blade centrahzer 1000)
• Figure 1 1 illustrates a cross-sectional view showing straight blade centrahzer 1100, which corresponds to straight blade centrahzer 1000 of Figures 10a and 10b, coupled to casing 11 10
• Straight blade centiahzer 1 ] 00 may include one or more collars 1120 and one or more hollow blades 1 130
• Figure 1 1 depicts two hollow blades 1130, although a different numbei of hollow blades 1130 may be used
• Each hollow blade 1130 may house oi covei, at least in part, a chemical containei 1 140 such as a canister filled with one oi moie chemicals to be dispensed into the annulus
• Chemical contameis 1140 may be held inside of hollow blades 1 130, or otherwise disposed neat an inteiioi suiface of hollow blades 1 130, as the casing stnng is loweied into the well boie This allows chemical contameis 1 140 to be piotected when in the well bore
• the chemical containers or reservoirs may
• each chemical container 1 140 may be equipped with a pump 1 150 that may be remotely activated to release one or more chemicals at any arbitrary moment
• pump 1150 may be or include a pump, a valve, or any device configured to express, eject, pump, transfer, or otherwise release the chemicals
• Pump 1 150 may be activated by pressure or pressure pulse from the surface down the annulus
• pump 1150 may be activated by lowe ⁇ ng a device on slick line or wireline into the inte ⁇ or of the casing that would signal each valve to release chemicals from the chemical container into the annulus as the device passes nearby This signal could be in the form of acoustic, radioactive, neutron, magnetic, thermal or any other type of signal that would penetrate the steel casing for a short distance
• vanous configurations could be employed to activate pump 1 150
• chemicals in chemical containers 1140 may be dispensed at any point in
• FIG. 12 illustrates a cross-sectional view showing additional embodiments, where centrahzer 1200 may include elements of straight blade centrahzer 1 100 as well as elements of a bow spring centrahzer Centiahzer 1200 may include one or more collais 1210 may be generally cylindrical or curved and designed to wrap at least partially around a casing section 1220 Bowed spring members 1230 may be attached to collars 1210 to allow bowed spring members 1230 to contact suifaces of the well boie when attached to a casing sti ing downhole
• two bowed spring membeis aie depicted m the example of Figuie 12 it should be understood that certain embodiments may employ one oi a different number of bowed spring membeis Bowed spring members 1230 may accoidingly piovide resistance to iotation so that all or part of centrahzer 1200 may tend to iemain stationary Collais 1210 may be slidably coupled to casing section 1220 in oider
• each hollow blade 1240 of centrahzer 1200 may form a substantially complete enclosure of around a hollow space Alternatively, each hollow blade 1240 may form only a partially covered hollow space where, for example, the hollow space may be exposed on the interior side ( ⁇ e , the "casing side") of a hollow blade 1240 Figure 12 depicts two hollow blades 1240, although a different number of hollow blades 1240 may be used
• each hollow blade 1240 of centrahzer 1200 may house or cover, at least m part, a chemical container 1250 such as a canister filled with one or more chemicals to be dispensed into the annulus
• Chemical containers 1250 may be held inside of hollow blades 1240, or otherwise disposed near an inte ⁇ or surface of hollow blades 1240, as the casing st ⁇ ng is lowered into the well bore
• each chemical container 1250 may be equipped with a pump 1260 Pump 1260 may be linked to the casing 1220 in a manner known in the art so that, when casing 1220 is rotated, pump 1260 may be forced open to thereby release one or moie chemicals from chemical container 1250, and/or forced to actively express the chemicals from chemical container 1250
• pump 1260 may be alternatively configured for activation with the appioaches discussed above with respect to Figure 1 1
• wheie chemical contamei 1250 may include a plastic or a flexible bag
• a cutting instrument 1270 such as a knife edge
• casing 1220 When casing 1220 is lotated, each plastic container or bag may be cut open, thereby ieleasing the chemical
• cutting instrument 1270 may include any means that would cut, tear, lacerate, puncture, penetrate, snag, tear, unseal, or otherwise release one or more chemicals from chemical container 1250.
• FIG 13 shows a cross-sectional view illustrating an additional embodiment, where activation collar 1300 may correspond to activation collar 1200, for example, but be configured to include distribution tubes 1310.
• Distribution tubes 1310 may be coupled to an outlet 1320 of the chemical containers so an activator chemical may be distributed further from an initial point of release.
• Distribution tubes 1310 may be attached to the casing by straps, clamps, welding or other means as would be understood by one of ordinary skill in the art.
• Distribution tubes 1310 may include one or more outlets to express the chemical.
• distribution tube 1310 may be perforated and may be designed to release the chemical in a manner similar to the function of a soaker hose sometimes used in gardening.
• Distribution tubes 1310 tubes may be of any length desired and may be spiraled around the outside of the casing.
• Activation collar 1300 may accordingly facilitate activating longer sections of the cement in the annulus.
• one or more chemicals and/or activating agents may be released into the well bore "on command.”
• the chemicals may be left stagnant and allowed to disperse into the surrounding fluid in the annulus by means of diffusion, or the chemicals may be mixed into the annular fluid by reciprocating or rotating the casing for a period of time as discussed above.
• the blades of the centralizer would provide a means to stir the fluid and mix the chemical in with it.
• Certain embodiments allow for activator distribution within an entire cross-section of an annulus containing a cementitious material.
• the equipment and procedures for certain embodiments are not complex, require minimal modification to existing cementing procedures, and have low operating risks.

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• Geochemistry & Mineralogy (AREA)
• Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
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• Moulds For Moulding Plastics Or The Like (AREA)

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• 2010
  • 2010-08-23 AU AU2010288355A patent/AU2010288355B2/en not_active Ceased
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  • 2010-08-23 WO PCT/GB2010/001592 patent/WO2011023943A2/en active Application Filing
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