Patent Grant
8186435
The present invention relates to apparatus and methods to stimulate subterranean wells, including injection or production wells, utilizing rocket propellants. Wells such as oil and gas production wells can be stimulated to enhance oil or gas production.
Early attempts to increase fluid flow area around the wellbore of a subterranean production well, such as an oil and/or gas production well, used devices and materials such as nitroglycerin, dynamite, or other such high energy materials to produce an explosive event that would create flow area at desired locations. These early methods had only limited success. A presentation of Cuderman's work at the Society of Petroleum Engineers (SPE) conference in Pittsburgh, Pa. on May 16-18, 1982, confirmed the existence of a preferred multiple fracture regime under certain firing conditions. Cuderman demonstrated that pressure rise time was an important factor for increasing near wellbore permeability.
More specifically, Cuderman demonstrated the existence of a hydraulic fracture regime, an explosive fracture regime, and an intermediate multiple fracture regime (see SPE/DOE 10845, “Multiple Fracturing Experiment—Propellant in Borehole Considerations” by Jerry F. Cuderman). The hydraulic fracture regime is characterized by a slow pressure rise that occurs when fluid flows to the point of least resistance. To create formation characteristics in the multiple fracture regime, a more rapid pressure rise is required. Pressure developed in the hydraulic fracture regime flows to the point of least resistance, usually generating a bidirectional, two-dimensional fracture. In contrast, the explosive fracture regime is created when a very rapid pressure rise of short duration is produced. Frequently, the explosive fracture regime causes formation damage and rubblization, damaging and sealing off some of the pore space. This results in an undesirable loss of porosity.
A number of inventors have attempted to use propellants in wells to achieve various goals; some of these are listed below in Table 1.
Each of these techniques has issues with wellbore conditions, explosive propellants, and/or minimal effective stimulation due to lack of or loss of energy.
Snider '426 describes a method of surrounding at least one perforating shaped charge with a sleeve of propellant, and uses the perforating charge blow a hole through the propellant and ignite it. The propellant gas is then used to create fractures in the near wellbore. A system is used that utilizes a shaped charge, or many shaped charges, to ignite the propellant sleeve. This type of ignition makes it difficult to predictably reproduce the event. Shaped charges are configured to blow through pipe and cement, thereby creating a tunnel for fluid flow. The entry hole size varies widely, e.g., from 0.19″ to 1.10″ and from 1 shot per foot up to 18 shots per foot (or more). This does not allow for a predictable, consistent amount of propellant surface area to be ignited. The propellant of Snider is broken into a random number of pieces, resulting in unpredictable pressure rise and propellant flow results.
Passamaneck '545 describes a method of externally igniting an external portion of a propellant charge to burn inwardly, thus yielding a more predictable ignition of the external propellant surface. Although the ignition system is predictable, the fluid in the wellbore keeps the propellant from reaching the critical pressure rise time needed to achieve a multiple fracture regime because of fluid leaching into the propellant. Much of the energy required for formation treatment is lost to the well fluid that inhibits the burn.
Hill '943 and '951 uses a compressible fracturing fluid to carry the propant into the fractures, causing hydraulic fracturing due to the energy stored in the “compressible” fluid.
Ford '337 describes positioning propellant having an abrasive material directly adjacent a shaped charge that is subsequently ignited. The shaped charge ignites the propellant gas and propels the abrasive material, thereby enlarging the perforation holes and extending fractures. The extended fractures are propped open by the abrasive material.
Hane '925 describes a method of utilizing multiple explosive charges in an effort to rubblize and fracture the formation.
Godfrey '030 describes a method of igniting a propellant tens of feet above a high explosive disposed adjacent to the pay zone, with the high explosive and the propellant being suspended in fracturing fluid. Godfrey's technique attempts to extend the duration of the shock wave caused by the high explosive.
Mohaupt '234 describes a method of igniting a propellant-type explosive that is dispersed into the wellbore liquid. This allows it to be ignited and reignited to cause pressure oscillations.
Subterranean wells often have a restricted flow area near the wellbore. Examples of such wells can include oil and/or gas producing wells, injection wells, storage wells, brine or water production wells, and disposal wells. The restricted flow area can be caused by the overburden exerting excessive compression on the formation near the wellbore, or by man-made damage near the wellbore, e.g., during drilling operations. For example, fluids or materials introduced into the wellbore can restrict permeability, reducing fluid communication and decreasing flow capacity to the pay zone. Certain wells have pay zones that cannot be effectively produced without some type of stimulation. Such wells are usually “tight” and require that additional flow area be opened to enable the wells to become commercially viable.
The technologies described in the documents above each attempt to create multiple fractures near the wellbore or open fractures near the wellbore prior to a hydraulic fracture, thereby increasing formation permeability and enhanced flow characteristics near the wellbore. Unfortunately, they each possess certain limitations. For example, none of them utilize a predictable internal ignition system to enable them to reach a critical pressure rise time necessary to enter into the multiple fracture regime and to provide sufficient gas volume to be able to extend the multiple fractures sufficiently far into the formation while protecting the propellant from the fluid in the wellbore.
What is needed is a method and apparatus utilizing an internal ignition in combination with a propellant charge that creates fractures into the wellbore in the multiple fracture regime, and extends these fractures further into the subterranean formation, thereby providing for an extended radial flow area that enhances well capacity and production capabilities.
The present invention achieves these objectives by using an internal propellant ignition system that is predictable and repeatable, in combination with a propellant that has the characteristics needed to enable the multiple fracture regime to be reached and extended. The propellant uses a long burn time in combination with a predetermined pressure rise time to provide the energy needed to create and/or extend the fractures.
The present invention also creates multiple fractures in the multiple fracture zone and extends them further into the formation. This is achieved using an enhanced (rapid) critical pressure rise time and sufficient peak pressure, in combination with the extended propellant burn time. After the fractures are initiated, they can be extended into the formation by gas that is still being generated by the propellant.
One aspect of the invention includes a propellant unit for underground submersion and combustion in a production or injection well. The propellant unit includes a propellant charge defining a bore and a pre-stressed tube within the bore. A detonating member, such as a detonating cord, is within the pre-stressed tube. In some embodiments, the detonating member includes a detonating cord with a bidirectional booster at an end of the detonating cord.
At least one of a first and second end of the pre-stressed tube can be sealed to prevent liquid penetration. This sealing can be by O-rings, a tubing fitting connection, threading (e.g., NPT connections), or combinations of these or other techniques. The pre-stressed tube can be stressed by scoring along a length of an exterior surface of the tube. The scoring can be accomplished by creating a groove along the outside surface of the tube, although other techniques can be used if they weaken the pressure containing capability of the tube appropriately. Since the pre-stressing determines the high-pressure failure point(s) of the tube, multiple scores result in multiple tube ruptures, which in turn results in a corresponding number of splits in the propellant charge that surrounds the tube.
Another aspect of the invention features an explosive transfer cap for transferring an ignition from an upper propellant firing train to a lower propellant firing train within a producing or injection well. The explosive transfer cap includes a housing that has a first seal, a second seal, and a longitudinal axis extending therethrough. An explosive charge is between the first and second seals, to facilitate ignition along the longitudinal axis. Although the propellant units are referred to as “upper” and “lower”, other configurations can also be used. For example, horizontal and sloped arrangements work effectively with all aspects of the invention.
The explosive charge of the explosive transfer cap can be a shaped charge. A shaped charge is especially effective at penetrating a solid seal, such as a bulkhead. Moreover, the explosive charge can be configured to be ignited by a detonator. Ignition from the detonator can reach the explosive charge, e.g., by a detonating member that includes a detonating cord and one or more bidirectional boosters. Ignition of the detonator can be performed electrically or mechanically.
In some embodiments, the first and second seal of the explosive transfer cap can be aligned along a longitudinal axis of the explosive transfer cap, and the explosive charge can facilitate ignition along this longitudinal axis. The first and/or the second seal can be a double seal, e.g., including two sealing mechanisms such as threading (e.g., NPT), tubing connections, O-rings, pressure connections, clamped connections, flanges, and others known to those of skill in the art. In some embodiments the second seal is a plug. The explosive charge of the explosive transfer cap can be configured to penetrate this plug, thereby propagating the ignition to a downstream firing train.
Another aspect of the invention is a propellant igniter for positioning within a propellant charge. This propellant igniter is configured to ignite a propellant charge and includes a pre-stressed tube and a detonating member within the tube. The detonating member extends substantially from a first end to a second end of the tube. Preferably, a length of the detonating member approximately corresponds to a length of the pre-stressed tube. The scoring of the pre-stressed tube can include establishing one or more shallow grooves along the length of the steel tubing. This can occur a number of times, with the one or more scorings distributed about a perimeter of the tube. Preferably, when more than one scoring is used, they are distributed equidistant about the perimeter of the tube. The igniter can be sealed at one or both ends to protect the detonating member from contaminants.
Yet another aspect of the invention features a carrier connector for a stimulation gun. The carrier connector includes a carrier housing, which includes a first end and a second end defining a longitudinal axis therethrough. The first end is adapted for connection with a first propellant carrier and the second end adapted for connection with a second propellant carrier. The carrier connector includes a first seal adjacent the first end and a second seal adjacent the second end. The connector is adapted to accommodate an explosive charge between the first seal and the second seal, which is configured to transfer an ignition along the longitudinal axis. The explosive charge, such as a shaped charge, can be configured to perforate the second seal, especially in embodiments where the second seal is a bulkhead plug. Moreover, the carrier connector can include a detonating member disposed within a longitudinal bore defined by the first end and the second end.
Another aspect of the invention features a propellant carrier unit for use in stimulating a producing or injection well. The carrier unit includes a first propellant unit and a second propellant unit. Each propellant unit can include a propellant charge defining a bore, a pre-stressed tube within the bore, and a detonating member within the pre-stressed tube. An explosive transfer cap is disposed between the first propellant unit and the second propellant unit for passing an ignition from the first propellant unit to the second propellant unit. Embodiments include the first propellant unit being configured to be ignited by a detonator.
Another aspect of the invention includes a method for stimulating a producing or injection well that comprises the steps of providing a propellant unit comprising a propellant charge, pre-stressing a tube within the propellant unit to facilitate establishment of a desired initial pressure release, igniting the propellant unit, splitting the propellant charge to form a predetermined, predictable amount of propellant surface area, and generating a gas pressure within an interior of a well bore of the production or injection well. The propellant unit can include a bore defined by the propellant charge, such that at least a portion of the pre-stressed tube disposed within the bore, and a detonating member within the pre-stressed tube. The detonating member can extend substantially from a first end to a second end of the pre-stressed tube. The propellant unit can be configured to be ignited by a detonator.
Yet another aspect of the invention features a method of transferring an ignition from a first propellant unit to a second propellant unit within a producing or injection well. This method includes the steps of connecting a first propellant unit to a first end of an explosive transfer cap, connecting a second propellant unit to a second end of the explosive transfer cap, igniting a first detonating member of the first propellant unit, transferring the ignition from the first detonating member to an explosive charge within the explosive transfer cap, and transferring the ignition from the explosive charge within the explosive transfer cap to the second detonating member. The detonating member can be a detonating cord, or it can include a detonating cord and at least one bidirectional booster. Ignition of the first detonating member can be by a detonator.
Another aspect of the invention features a method of transferring an ignition from a first carrier unit to a second carrier unit within a producing or injection well. This method includes the steps of connecting a first carrier unit to a first end of a carrier connector, connecting a second carrier unit to a second end of the carrier connector, igniting a propellant igniter of the first carrier unit, transferring the ignition from the first carrier unit to an explosive charge disposed within the carrier connector, and transferring the ignition from the explosive charge within the carrier connector through a bulkhead to a propellant igniter of the second carrier unit. The explosive charge can be a shaped charge that propagates the ignition along a longitudinal axis of the carrier connector.
Yet another aspect of the invention features a method of controlling stimulation gas flow to a producing or injection well. This includes the steps of sizing a propellant charge of a propellant unit to correspond to a total desired stimulating gas volume or amount to be generated, igniting the propellant charge within the well using a detonating member disposed within the propellant unit, and splitting the propellant a number of times corresponding to the amount of initial gas pressure to be established. Preferably, the splitting of the propellant charge is along a longitudinal axis of the propellant charge. This can result in a plurality of substantially symmetrical propellant charge fragments, to effectively achieve a predetermined combustion gas generation rate.
An aspect of the invention features a fluid-repellant propellant material produced by the process of treating a propellant surface with a primer coating that can include rubber, fluoroelastomer, and titanium dioxide, and coating the treated propellant with a protective fluoroelastomer coating that can include fluoroelastomer, mica, and graphite, and allowing the treated propellant to dry. Yet another aspect of the invention includes a fluid-repellant propellant material comprising a propellant treated with a primer that includes rubber and fluoroelastomer, and a fluoroelastomer coating adhered to the primer coating on the propellant, the fluoroelastomer coating including fluoroelastomer and mica powder.
The foregoing discussion will be understood more readily from the following detailed description of the invention, when taken in conjunction with the accompanying drawings, in which:
The invention relates to apparatus and methods to stimulate subterranean wells, including injection or production wells, utilizing rocket propellants. Wells such as oil and gas production wells can be stimulated to enhance oil or gas production. Although the following discussion focuses on oil production wells, the technology is also applicable to gas production wells, injection wells, storage wells, brine or water production wells, disposal wells, and the like. Known stimulation techniques can include multiple fracturing and/or cleaning near the wellbore to reduce flow interference that can be caused by debris. As described above, hydraulic fracturing processes create fluid (e.g., gas and/or liquid) communication by fracturing the rock with hydraulic pressure. A propping material can also be used, such as sand, bauxite, or other materials which are designed to keep the fracture open to an extensive area of the pay zone. But hydraulic fracturing is not efficient or practicable in some instances, e.g., when the point of least resistance in a producing oil well is in the direction of a salt water zone.
In situations such as these, treatment in the multiple fracture regime is preferred for increasing near wellbore permeability and flow. Creation of a multiple fracture regime requires a pressure rise time that is rapid enough to exceed the ability of the preferred fracture plane to accept the gas being generated. The fractures P cannot open rapidly enough to receive the generated gas. Since the preferred fracture plane P is not able to accommodate all of the generated combustion product, additional fractures open in a direction T perpendicular to the preferred fracture plane (e.g., away from the salt water zone), thus causing an increased flow area near the wellbore. As illustrated in
As can be seen from the figures, the propellant treatment techniques described herein can be used to increase well production with minimal risk of propagating the flow area out of the pay zone (e.g., into an undesired adjacent salt water zone). Although the propellant treatment time can be as long as 2,000 milliseconds, this amount of time is insufficient for the fracture to propagate out of the pay zone. The present invention can be used to initiate fractures prior to a hydraulic fracture. The risk of near wellbore damage (e.g., rubblization) can be minimized since the propellant treatment reduces the initial breakdown pressure encountered during any subsequent hydraulic fracturing process. In some embodiments, when the invention is used to create a sufficient number of fractures near the wellbore, a hydraulic fracture treatment may not be required.
Although propellant fracturing for well development has been used in the past, known techniques have employed only short event times (on the order of 20 to 40 milliseconds). Others have been known to have a long burn time (on the order of 500-1,000 milliseconds or longer) but have trouble reaching the critical pressure rise time required to initiate the multiple fractures that are formed during the multiple fracture regime. The present invention uses a critical pressure rise time of about 0.5 to 20 milliseconds, or preferably about 10 milliseconds, thereby generating sufficient peak pressure to create the multiple fractures in the multiple fracture regime. The invention also extends these treatments, e.g., to about 500 to 2000 milliseconds, or preferably to about 500 milliseconds, thereby extending, the multiple fractures further into the formation. As described below, embodiments of the invention achieve this by controlling both the initial pressure rise and the entire burn duration of the propellant.
Embodiments of the present invention utilize the propellant gas for clean up of the near wellbore (e.g., to increase local wellbore porosity) and for fracturing. Predictable stimulation and protection from wellbore fluids results, and sufficient energy for effective stimulation is provided. As described below, embodiments include utilizing an internal linear ignition system to split the propellant into two or more pieces of predicable size (see
A propellant unit of the invention includes a detonating member 1, such as a detonating cord, explosive cord, deflagrating cord, detonating fuse, explosive fuse, and the like, disposed, e.g., in a pre-stressed steel tube. For convenience, these are each referred to as a detonating cord, herein. A detonating cord is defined as an elongated charge with sufficient energy to split a scored tube 2 when ignited inside the tube. The term detonating member includes one or more detonating cords as defined herein. In a preferred embodiment, the detonating member 1 includes a detonating cord having a bidirectional booster at one or both ends. Generally, a bidirectional booster is similar to a detonating cord except that it has a higher energy content (e.g., due to compression of the explosive material). As used herein, the term bidirectional booster also includes many types of boosters, such as omnidirectional boosters, unidirectional boosters, lead azide technology, and others.
The tube 2 can be ⅜″ diameter stainless steel tubing and is located in the propellant charge 3. Although the pre-stressed member is referred to herein as a tube 2, embodiments can include other configurations, such as an oval shape, a flared shape, an irregular shape, a square channel member, and others. The term “tube” is also intended to include combinations of different shapes, such as non-circular cross-sections disposed between circular (cylindrical) end portions. The tube 2 can also be other sizes and can be made of other materials possessing suitable physical characteristics.
This figure illustrates a propellant igniter of the invention. A pre-stressed tube 2 comprising a detonating member 1 extending substantially from one end to the other end of the tube can be used to ignite a propellant charge. Preferably, the tube is scored one or more times corresponding to an initial amount of gas release and pressure rise that is desired to initially stimulate a well. The scoring can include external cutting or grooving of the tube, although other techniques to weaken the tube at specified positions can be used. If multiple scoring techniques are used, preferably the scores are distributed about a circumference of the tube. For example, two scores should be oriented at 180 degrees, 3 scores at 120 degrees, etc. When the igniter is positioned in the well it is not important that the scores be positioned along a desired fracture direction. The orientation of the scores has little, if any effect since the propellant igniter, as discussed below, is generally mounted within a carrier. As discussed below, the ends of the propellant igniter can be, e.g., sealed or double sealed, to increase repeatability and firing reliability.
Another embodiment of the invention includes an explosive transfer cap disposed between propellant units, for transferring ignition from one propellant unit to another.
A combination sealed end cap (bulkhead) and a custom perforating charge 21 can also be used in the explosive transfer cap 6. The explosive transfer cap 6 can be manufactured to include or house an explosive charge 21, such as a shaped charge. Preferably, about 1 to 1½ grams of explosives are used, to enable penetration of, e.g., 1″ steel with a minimum 0.20″ entry hole. A sealed bulkhead 19 can be placed at the end of the explosive charge 21 to protect it from the well environment. The other end of the propellant unit firing train can be sealed and protected by a top end cap (also known as a receptor 5). Thus, a propellant unit firing train can be configured as a sealed unit extending from a top end cap 5 at one end, along the steel tube 2, and extending to an explosive transfer cap 6 at the other end. An explosive charge 21 in the explosive transfer cap can be sealed by the bulkhead 19.
During fabrication, when the receptor 5 and the explosive transfer cap 6 are installed on a tube 2, the assembly is pressure tested to ensure there are no leaks. The propellant is then placed over the top end cap 5 and can butt against the explosive transfer cap 6. It will be understood that using this technique each propellant unit can be sealed at the top and bottom to prevent fluid penetration into the firing train, and to maintain a clean firing system during transport to a well site.
Thus it will be understood that the first propellant unit 13 in the firing train 14 is ignited by a shaped charge that fires through a bulk head 19, and then through the top end cap 5 of the first propellant unit (see
Near one end of the connector 11 is a sealed top end cap 5A of the carrier connector. The carrier connector can also include a detonating member 1 (e.g., including bi-directional boosters 4 and a detonating cord), a tube 2 (e.g., without scoring), and an explosive charge 21 (e.g., a shaped charge). This connector allows longer carrier assemblies (e.g., up to 500 feet in overall combined length) to be run down a well in a single run without compromising the firing train. The explosive charge 21 can be configured as it was for an explosive transfer cap 6 (described above). An explosive charge 21 (not shown) from an upstream propellant unit fires through a bulkhead 19 and/or top end cap 5A in the carrier connector. The detonating member (e.g., bi-directional booster 4 and detonating cord) is ignited, the detonating member 1 ignites the explosive charge 21, which continues the ignition through bulkhead 19 and to the first propellant unit 13 of the next carrier 7.
The invention includes a method of stimulating a well that includes providing a propellant unit, such as described above. The propellant unit can include a pre-stressed tube that is stressed a number of times to establish an initial gas pressure release from the propellant, e.g., to establish an initial pressure at a time of about 10 milliseconds after ignition of the propellant. The total amount of propellant utilized can be selected based upon the total amount of stimulation gas flow desired, e.g., to last for a duration of 500 milliseconds, or 1 second, and the like. This method provides for the independent control of at least two different variables—the amount of initial gas release (which can be controlled by the number and type of scoring used on the tube), plus the total amount of gas subsequently released (for immediate, subsequent propagation and stimulation in the multiple fracture regime). Control of these two variables results in a predetermined, controlled combustion of the propellant, maximizing the effectiveness of the stimulation for a given wellbore application. The one or more propellant units located within the one or more carriers are simultaneously ignited, e.g., using the type of firing train described above, thereby splitting the propellant in each propellant unit a predetermined number of times and establishing the amount of initial combustion gas flow that was previously determined. A gas pressure rise having a controlled, predetermined initial pressure rise, and a predetermined burn duration/amount can be generated by this technique.
Embodiments also include transferring an ignition from a first propellant unit to a second propellant unit using an explosive transfer cap 6. The propellant units are connected to the explosive transfer cap, the first propellant unit is ignited, e.g., using a detonator, the ignition is transferred from the first propellant unit to the explosive transfer cap, and an explosive charge (e.g., a shaped charge) within the explosive transfer cap then ignites a detonating member in the second propellant unit. An ignition can also be transferred from a first carrier unit to a second carrier unit including a propellant unit. Two carrier units are connected to a carrier connector 11 and an ignition from the first carrier is transferred through a top end cap seal 5A of the carrier to an explosive charge within the carrier. The resulting ignition within the carrier then passes through a seal, e.g., a bulkhead and to a firing train of a propellant unit 13 in a second carrier. Preferable, the ignition through the carrier propagates along a longitudinal axis of the carrier.
Yet another method includes a method of controlling a stimulating gas flow to a subterranean well that includes sizing the propellant charge to correspond to a total amount of stimulating gas desired, igniting the propellant cord using a detonating member within the propellant charge to split the charge a predetermined number of times. The number of splits in the propellant charge can be selected to correspond to the initial pressure rise desired in the well in which the propellant charge is ignited.
Embodiments of the invention also include various other methods. In general, the propellant unit is run (lowered) in a carrier tube that protects the propellant unit and has enough open flow area to allow the propellant gas to escape through the carrier without creating excessive pressure drop (gas flow resistance). The carrier can be made of steel and can be used multiple times because sufficient flow area is present to prevent creation of an excessive, damaging pressure differential when the propellant is consumed. The carrier assembly can be deployed into the wellbore in many different ways. For example, it can be conveyed by wireline, tubing, slickline, or coil tubing. As discussed above,
The invention also includes a method for fracturing wells. Propellant units can be run into the well either alone or with a perforating gun (e.g., beneath a perforating gun). Fluid in the wellbore can be used to isolate the propellant gas (i.e., the combustion product). By the propellant gas compressing the well fluid above and below the propellant, the propellant-produced gas can be directed to the pay zone. The well fluid above the propellant carrier acts as a tamp. The propellant is ignited by a detonating member (e.g., a detonator), which can be ignited by a bidirectional booster. The booster can be ignited by a shaped charge, which can be ignited by a detonator or a primer cord. The gas generated from combustion of the propellant pressurizes the tamp fluid, creating a gas bubble which forces the gas into the pay zone. When the propellant is ignited by the detonating member (e.g., a directional linear charge) there is a rapid pressure rise due to ignition of the surface area of the propellant, which initiates multiple fractures and/or cleans up the well.
In some embodiments, the propellant is shielded from the wellbore fluids by dipping it into a solution that becomes a flexible covering when dry. The coating helps to preserve the useable energy content of the propellant, and to maintain predictability of the combustion and stimulation results. The flexibility of the coating allows for shrinking of the covering when it is subjected to hydrostatic pressure from the wellbore fluids. The protective covering is destroyed or blown off when the propellant is combusted, as any wellbore fluid is being blown away from the propellant. Destruction of the coating can occur as the propellant burns, as the critical pressure rise time that is needed to treat the well and/or to create multiple fractures is being achieved. Protection of the propellant from the wellbore fluids reduces or eliminates contamination of the propellant and results in a more consistent, predictable propellant burn, thereby yielding improved stimulation results.
The protective covering can be made of the same material as the propellant, but without the energetic portion (e.g., ammonium perchlorate) of the propellant mixture. The covering can also be made of a mixture in which the propellant can be dipped. In some embodiments, it can be brushed on to the propellant so that a dry thin coat of VITON® (registered trademark of DuPont Dow Elastomers, LLC) or rubbery coating material remains on the outside of the propellant sealing the propellant from the fluids and other elements in the well. In all of these embodiments, the propellant covering is consumed during the propellant burn so no covering remnants remain in the well. This prevents the coating from causing problems when the carrier is later recovered from the well.
In some embodiments a coating, e.g., a fluoroelastomer coating, does not readily adhere to the propellant unless a primer coating is used. Use of a primer coating can result in the satisfactory adhesion to the propellant of fluoroelastomer coatings such as KALREZ® (registered trademark of E.I. DuPont de Nemours and Company) and VITON. A suitable primer coating for this purpose can be manufactured as follows and should include: 5% Hytemp 4451 CG polyacrylate rubber (available from Zeon Chemicals of Louisville, Ky.), 5% DYNEON® FC-2178 fluoroelastomer (available from 3M, St. Paul, Minn.) and 1% titanium dioxide pigment in t-butyl acetate solvent. (DYNEON is a registered trademark of Dyneon LLC.) The following procedure can be used to formulate a suitable primer coating.
To administer the primer coating, either dip the propellant into the primer, or brush the primer onto the exterior of the propellant.
The barrier coating should be applied to the exterior of the primer coat after the primer has dried. The following procedure can be used to prepare the barrier coating.
Apply this coating to the primed propellant and allow the coating to dry. This barrier coating can be applied, e.g., by dipping or brushing. Moreover, in addition to Dyneon FC-2178, other fluoroelastomer materials, such as those available from Pelseal Technologies, LLC of Newtown, Pa., can be used.
While the invention has been particularly shown and described with reference to specific preferred embodiments, it should be understood by those skilled in the art that various changes in form and detail may be made therein without departing from the spirit and scope of the invention as defined by the following claims.
This application is a divisional application of U.S. Ser. No. 12/488,160, filed Jun. 19, 2009, which is a divisional of U.S. Ser. No. 11/359,972, filed on Feb. 22, 2006, the entire contents of both of which are incorporated herein by reference. This application claim priority to and benefit of U.S. Ser. No. 60/655,456, filed Feb. 23, 2005, the contents of which are incorporated herein by reference.
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| Number | Date | Country | |
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| 20110240183 A1 | Oct 2011 | US |
| Number | Date | Country | |
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| Number | Date | Country | |
|---|---|---|---|
| Parent | 12488160 | Jun 2009 | US |
| Child | 13103766 | US | |
| Parent | 11359072 | Feb 2006 | US |
| Child | 12488160 | US |
