|Número de publicación||US3385367 A|
|Tipo de publicación||Concesión|
|Fecha de publicación||28 May 1968|
|Fecha de presentación||7 Dic 1966|
|Fecha de prioridad||7 Dic 1966|
|Número de publicación||US 3385367 A, US 3385367A, US-A-3385367, US3385367 A, US3385367A|
|Cesionario original||Paul Kollsman|
|Exportar cita||BiBTeX, EndNote, RefMan|
|Citas de patentes (8), Citada por (275), Clasificaciones (12)|
|Enlaces externos: USPTO, Cesión de USPTO, Espacenet|
May 28, 1968U P. KOLLSMAN SEALING DEVICE FOR PERFORATED WELL CASING 4 Sheets-Sheet 1 Original Filed Aprli 21, 1964 Pfg. 5
INVENTOR. Paul KO//Sman P. KOLLSMAN May 28, 1968 SEALING DEVICE FOR PERFORATED WELL CASING 4 Sheets-Sheet Original Filed April 2l, 1964 Fly. /2
INVENTOR. Pau/ KO//Sman "M ATTORNEY May 28, 1968 P. KOLLSMAN SEALING DEVICE FOR PERFORATED WELL CASING 4 VSheets--Slfleet 5 Original Filed April 21, 1964 wf T INVENTOR. Paal/(a//sman QM A TTOR/vfy May 28, 1968 P. KOLLSMAN SEALING DEVICE FOR PERFORATED WELL CASING 4 Sheets-Sheet 4 iff/lll. I
Original Filed April 2l, 1964 INVENTOR Paa/ Ko//sman ATTORNEY United States Patent C l 3 Claims. (Cl. 16o-191) ABSTRACT F THE DISCLUSURE The present improvements provide a sealing element for wells in which a casing is installed. The sealing element comprises a central tubular core and an outer covering of elastomer material of a relaxed diameter larger than the internal diameter of the casing. The covering comprises spaced annular ribs and is inserted, together with its central sleeve, into the casing in compressed condition and after presoaking in a hydrocarbon liquid. The liquid forms a lubricating ilrn during insertion and during subsequent movement of the element relatively to perforations of the casing in order to open and seal Such perforations.
This application is a continuation of my copending application Ser. No. 361,327, filed Apr. 21, 1964, now abandoned.
The invention deals with the problem of controlling the flow of uids into a perforated well casing. The perforations may be present at a single level or formation or at several different levels or formations. They extend through the casing wall and through the surrounding cement layer or sheath into the adjacent formation, thus opening up the formation by explosion-produced passages leading from the formation into the well casing.
The control may involve the temporary or permanent sealing of all the perforations at a certain level, while initiating or maintaining flow at a different level, or it may involve the selective control of the fluid flow at a particular level for the purpose, for example, of reducing gas ilow through the higher perforation of the zone or level, or reducing water flow through the lower perforations of the zone or level by selective closing or restriction of such upper or lower perforations.
The invention accomplishes this in a manner in which the inner diameter of the casing is not excessively reduced, so that a production string, including a pump, may extend therethrough, and further in such a manner that the flow may subsequently be adjusted by opening or closing the perforations at one level and independently adjusting the flow through the perforations of a different level above or below the one level.
It is known to seal the perforations of a zone by a procedure called squeeze cementing. This involves the installation of packers below and above the zone to be cemented, the injection of cement through the perforations into the formation, followed by removal of the packers and of cement remm'ning in the casing. The result is the permanent closure of the perforations.
Another known practice involves the installation of a straddle tool comprising essentially a piece of tubing with a mechanically or hydraulically expansible packer at each end, thus straddling the perforations which lie between the packers. The conventional straddle tools have a relatively small central bore which severely restricts treatment of a zone, or production from a zone, below the tool through the bore of the tool.
Further, the expansible packers which form a part of the straddle tool exert high specific pressures of the order of 1,500 to 10,000 p.s.i. against the casing well which 3,385,367 Patented May 28, 1968 ice only a sound and noncorroded casing can withstand. By way of contrast the invention employs sealing pressures of a dilferent order of magnitude. Pressures of less than 300 p.s.i. were found to be sutlcient for a reliable seal.
The invention involves the installation of a valve sleeve within the casing. The valve sleeve comprises essentially a central tubular metal sleeve body providing a large central passage through which well fluids may flow, through which a production string including a pump may extend, or through which appropriate tools may reach in order to act on and reset a similar valve sleeve installed at a lower zone or level.
The metal sleeve body is tubular and rigid in contrast to the known casing patches which are inserted into a damaged well casing in a corrugated state in which their outer diameter is reduced, and which are subsequently mechanically expanded into tubular or near-tubular shape by attening out of the corrugations.
The metal sleeve body has an outer covering of elastomer material bonded thereto which, in installed condition, is suciently compressed to produce a seal between sleeve and casing. Even though the specific sealing pressure exerted against the casing is of a low order, a reliable seal against high pressures is readily produced by an elastomer body of appropriate length.
The elastomer covering may be composed of solid or of porous elastomer material. Elastomer materials, as such, may, for the purpose of the present invention, be divided into those which remain substantially unaffected by contact with hydrophobic liquids and those which, upon exposure to hydrophobic liquids, exhibit an appreciable degree of swelling.
In all applications according to the invention the purpose of the elastomer covering is to produce a seal resulting from compressive force exerted by the exterior element, such as the well casing or the well bore, upon the elastomer or, conversely, by the force with which the elastomer expands against the exterior element, the casing or well bore.
For this purpose the elastomer body may be compressed prior or incidental to the installation, such as its insertion into the well casing. In order to facilitate insertion or produce a tighter seal, the elastomer may be precompressed with or without the simultaneous application of heat to reduce its original relaxed diameter by a set.
In place of, or in addition to, such compression or precompression, sealing force may be generated by swelling of the elastomer seal which is then made of a material which upon contact with a hydrophobic liquid causes the sealing body to swell.
Experiments conducted in connection with the invention showed that particularly high degrees of swelling can be produced if the elastomer orignally contains a substantial amount of a plasticizer which is then extractable, for example by leaching in a solvent and subsequent evaporation of the solvent. The elastomer shrinks under such treatment and exhibits a remarkable degree of swelling in relation to its shrunken dimensions when exposed to a hydrophobic liquid. At the same time a remarkable degree of its original tensile strength is retained.
Instead of being of solid composition or construction the elastomer may be manufactured as a porous or spongelike body with or without an exterior skin which is denser than the interior, or may be mechanically reinforced.
Such porous or spongelike elastomer bodies may, again, be made of materials which exhibit little swelling when exposed to hydrophobic liquids or of those which swell appreciably under such conditions, depending on the particular requirements.
Elastomer seals may even be made water swellable.
For this purpose a water swellable gel may be introduced into the pores of a porous body which, in itself, may be oil swellable. Drying of the gel produces shrinkage of the gel filled pores. The gel subsequently expands when exposed to water. Such water swellability can therefore be imparted even to an elastomer which by itself is swellable in hydrocarbon liquids, thus superimposing the phenomena of water swelling upon oil swelling.
The valve sleeve is inserted into the casing and is pushed down, for example by an appropriate cable-suspended weight or tubing string to the desired location at which it either seals, partially seals, or clears the perforated zone.
Subsequently the valve sleeve is readily moved either by moving it down further or lifting it to the desired adjusted position in which it clears or seals the perforated zone, or to a zone above or below or in which it uncovers certain perforations lof the same Zone in which the valve sleeve was originally set.
In all instances the valve sleeve forms a sleeve valve with the casing which is preferably suitably prepared by removing any burrs from the perforated zone or zones, for example by a conventional reaming tool.
Tests have shown that the valve sleeve may be moved in compressed condition from the point of insertion at the top of the casing along very substantial lengths of casing without any appreciable wear of the elastomer covering by either the casing wall or the joints of the casing.
A swellable valve sleeve lowered to the desired level and maintained suspended for a suliicient time swells and seats itself tightly. This can be accomplished within 6 to l2 hours from the time of insertion of the valve sleeve into the casing or well bore.
Summary of the invention The invention employs in a well comprising a perforated casing a sealing element comprising a central annular core and an outer core covering of elastomer material shaped to form annular ribs leaving void spaces between such ribs, the sealing element being inserted into the casing in compressed condition and after presoaking in a hydrocarbon liquid which provides a lubricating film during the initial insertion and during subsequent movement of the sealing element with respect to the perforations to seal or open the same.
The various features and advantages of this invention will appear more fully from the detailed description which follows accompanied by drawings showing, for the purpose of illustration, preferred embodiments of the invention. The invention also resides in certain new and original features of construction and combination of elements, as well as steps and sequences of steps hereinafter set forth and claimed.
Although the characteristic features of the invention which are believed to be novel will be particularly pointed out in the claims appended hereto, the invention itself, and the manner in which it may be carried out may be better understood by referring to the following description taken in connection with the accompanying drawings forming a part of it in which:
FIG. 1 is an elevational section through a valve sleeve according to this invention;
FIGS. 2 to 12 illustrate, in elevational section, views of specific forms of elastomer coatingsz FIG. 13 is a diagrammatic and simplified vertical section of a well and casing being prepared for the installation of a valve sleeve;
FIGS. 14 and 15 are corresponding illustrations of the well and casing with valve sleeves installed therein in different positions; and
FIG. 16 is a diagrammatic illustration of a straddle sleeve whose elastomer seals seal against the well bore.
In the following description and in the claims various details will be identified by specilic names for convenience. The names, however, are intended to be generic in their application. Corresponding reference numerals refer to corresponding parts in the several figures of the drawings.
The drawings accompanying, and forming part of, this specification disclose certain specific details of the invention for the purpose of explanation of broader aspects of the invention, but it is understood that details may be nodilied in various respects without departure from the principles of the invention and that the invention may be applied to other structures than specifically shown.
The valve sleeve of PIG. l comprises three peripherally rigid tubular sections 11, 12 and 13 connected by threaded couplings 14 and 15. The exterior surface of sections 11 and 13 is roughened by Sandblasting or knurling to provide a secure grip for an elastomer covering generally indicated at 16 and bonded to the surface. The contour of the elastomer covering may vary in form, representative forms being shown in FIGS. 2 to 12.
There are different elastomer materials in existence and commercially available. These will be described collectively further below. At this point it is suflicient to state that the covering may either consist of solid or of open-pore spongelike elastomer material, 0r solid elastomer material which may be shaped to provide voids into which the material can be deformed when the elastomer material is in a state of compression inside the casing in order to produce the desired seal with respect to the casing.
The valve sleeve shown in FIG. 1 may be of considerable length of the order of l0 to 30 feet or more, depending on the length of the central section 12 which is chosen to meet the particular local requirement. A representative practical length of the end sections is 4 yfeet.
As shown in FIG. 2, the tubular elastomer covering may be shaped as a series of annular ribs 17 preferably of solid material spaced from one another by annular valleys 18. The outer diameter D of the ribs or rings 17 exceeds the internal diameter d of the casing 20. By the act of insertion the annular ribs are deformed in profile, as a result of which the space or volume of the annular valleys 18 is reduced. The elastomer rings 17 may be manufactured as one piece comprising a plurality of annuli 17.
This multi-ring piece may either be directly molded on the sleeve, or it may be premanufactured and then bonded to the sleeve. The rings 17 may also be premanufactured as individual rings and then bonded to the outer surface 19 of the rigid tubular sleeve member 11.
The elastomer structure shown in FIG. 3 represents the relaxed state of the rings 17 which are substantially of saw-tooth or gable shape appearance in cross section. This structure is then precompressed to a reduced diameter and maintained in the precompressed state under application of heat for a time to produce a set. The elastomer body then has the appearance as shown in the upper portion of FIG. 4, its relaxed but set diameter being D which is subsequently reduced to d by insertion into the casing 20.
The elastomer sleeve shown in FIG. 6 may be made from oil or water swellable elastic material capable of swelling within the casing upon contact with a swelling liquid, e.g., crude oil or water, respectively, to form a tight seal as shown in FIG. 7.
The elastomer sleeve shown in FIG. 5 is constructed from a material containing a substantial proportion of a plasticizer. The relaxed diameter D1 of the rings 17 is reduced to a lesser diameter D2 indicated in FIG. 6 as a result of shrinkage of the elastomer by extraction of the plasticizer. The reduced diameter D2 may be smaller than the diameter d of the casing 20 into which the sleeve 17, 11 is to be inserted.
After insertion into the casing the elastomer seal is exposed to a swelling liquid, for example crude oil to which gasoline may be added, causing the sleeve to expand to such a degree that the required sealing pressure is developed. The expanded sleeve 11, 17 is shown in its swelled, expanded condition in FIG. 7.
In the form of valve sleeve shown in FIG. 8 the elastomer component is essentially a thin walled piece of tubing 23 having integral internal annular ribs 24 which are bonded to the sleeve exterior 11 along their respective base surfaces at 25. This arrangement results in the formation of a series of annular chambers 26 vented to the periphery by vent passages 27.
As the valve sleeve is being inserted into the casing 20, the elastomer sleeve or tubing 23 is being compressed, thereby reducing the size of the chambers 26. This particular form of valve sleeve encounters somewhat less resistance at casing joints when it is being moved to its eventual location which may involve travel of the order of a mile.
The open-pore sponge body 2S of the elastomer material shown in FIG. 9 has a dense tough outer porous skin 28', the end of which is directly bonded to the `sleeve 11 at 30. Insertion of the valve sleeve into the casing 20 results in compression of the sponge body 28 which becomes correspondingly denser.
The elastomer sleeve 16 of the valve sleeve shown in FIG. l0 consists of open-pored elastomer sponge ma teria] containing in its pores a liquid swellable gel. Substantially radial passages 32 are yformed in the sponge body whose Volume is subsequently reduced by compression of the elastomer body incidental to its insertion into the casing 20 of smaller diameter. If the swellable substance in the pores is a water swellable gel, the swelling force thus produced is superimposed upon the elastic force of the elastomer.
Instead of bonding the elastomer layer to the sleeve 11 the sleeve may be provided with peripheral ridges or flanges 29 which interlock with correspondng grooves of the elastomer body as shown in FIG. l1. The tightness of interengagement increases when the valve sleeve is inserted into the casing, thereby compressing the sleeve.
In the form shown in FIG. l2 the elastomer body has a certain limited degree of freedom to move axially with respect to the metal sleeve 11. The interior spaces 26 into which the ridges 29 extend are vented by passages 27. The elastomer body is reinforced peripherally by a suitable cord or fabric layer 30. Such reinforcing layers are preferably so constructed as to limit iaxial expansion while permitting radial expansion.
FIG. 13 is a diagrammatic representation of a well comprising a casing 20 within the well bore 31 and a layer 32 of cement between bore and casing. The bottom of the casing is sealed by a cement plug 33.
Perforations 34 extend through the casing wall 20 and the cement 32 into the surrounding oil bearing formations 35 and 36. The perforating procedure produces burrs 37 which are removable in a known manner by a casing scraper or reamer diagrammatically indicated at 38.
In the arrangement illustrated in FIG. `l4 the upper formation 35 is temporarily, although not necessarily permanently, sealed by a st-raddle sleeve of the type shown in FIG. l. One elastomer body seals the valve sleeve relatively to the casing 20 above the formation 35 and another elastomer body seals the valve sleeve relatively to the casing 20 below the formation 35. This form of seal permits substantial tolerances in the placement of t-he valve sleeve with respect 'to the perforations.
A production string extends through the upper valve sleeve in formation 35 `and through a lower valve'sleeve in yformation 36, the pump 40 being at the end of the string.
In this diagrammati-c illustration wall thicknesses, elastomer thickness and valve sleeve thickness are exaggerated for the sake of clarity. Correspondingly the diameter of the central passage through the valve sleeves appears too small. It is considerably larger in actual construction. For example, a casing having an internal diameter of 4 accommodates a valve sleeve having an internal passage diameter of 3%".
The lower valve sleeve of FIG. 14 is set to close the lower zone of the perforations of the formation 36 to reduce the flow of liquid, for example water, therethrough.
Subsequently the lower valve sleeve may be raised to seal t-he lower form-ation 36 to a greater degree, or completely, while the upper valve sleeve may -be moved wto expose a portion, or all, of the perforations within formation 35.
In the arrangement shown in FIG. l5 three relatively short valve sleeves, 111, 211 and 311 are so set that the central perforations within the lower formation 36 are exposed, while the upper Iand lower zones of the same formation are sealed by valve sleeves 211 and 111, respectively. At a later period the lower formation may be sealed completely by moving the valve sleeves 111 and 211 into contact with each other.
The valve sleeve 311 is so set with respect to the perforations -of the upper formation 35 as to restrict production through the 'upper portion of the perforated zone only.
Each one of the these valve sleeves may readily be moved by gripping it by means of a conventional tubing anchor. This type of tool is in essence an expansible mandrel or core which is lowered into the well and expanded by rotation in one direction, generally counterclockwise or left-handed rotation, and is contracted by rotation in the opposite sense, usually clockwise or righthanded rotation.
The for-ce exerted by such gripping tools is sufficient to permit exertion of great force, either pulling or pushing, -on the valve sleeve in order to move it to the desired new location.
For the purpose -of adjusting valve sleeves conventional bumping tools may also be employed to move the valve sleeve -by impact rather than static force. The use of bumping tools is particularly advantageous where the desired displacement of -the valve sleeve is relatively small, but where accurate positioning is required.
Valve sleeves were constructed of steel tubing having an louter diameter of 3%" and an internal diameter of 3%" and a total length lof 48". Elastomer layers were bonded or vulcanized to the sandblasted outer surface of the tubing. The valve sleeves were then inserted for test- :ing in standard 41/2 casing having an internal diameter of 4".
T est 1.-The elastomer covering had the shape shown in FIG. 2 composed of individual rings of t Width and an external diameter of 4% of neoprene rubber cured with benzoyl peroxide land having a hardness of 40 -durome-ter un-its.
The valve sleeve was soaked in cru-de oil, pressed into the casing and subjected to a differential pressure of 3000 p.s.i. across the entire length of the sleeve. There was no leakage.
Thereafter a sub-assembly of only six rings was subjected to differential pressure. This latter test established that six rings provided a tight seal up to 520 p.s.i.
Test 2,-An elastomer covering was applied to the valve sleeve core in the form shown in FIG. 5 composed of individual rings of a width of 1/z and an outer diameter of 45716. The rings consisted of Nordel rubber cured with lbenzoyl peroxide and containing 25 percent plasticizer by volume, Nordel rubber, as hereinafter specified, is an ethylene propylene hydrocarbon -rubber cured with benzoyl peroxide.
The valve sleeve was then pressed into casing tubing and maintained at a temperature Iof 240 F. for 48 hours. After removal of the valve sleeve from the 4" tubing the elastomer coating had acquired a set, its external diameter -being 4%".
The valve sleeve was then soaked in crude `oil and inserted into the easing. Subjected t-o a differential pressure of 3000 p.s.i. it main-tained a tight seal.
A sub-assembly of six rings maintained a tight seal up to a differential pressure of 5S 0 p.s.i.
The force required to insert the valve sleeve into the casing and to move the valve sleeve axially within the casing was considerably less than in Test l. This appears to be due to limited absorption of crude oil by the rubber rings, which oil then acts as a lubricant,
Test 3.-A neoprene sleeve was bonded to the valve sleeve core. The neoprene sleeve had the shape shown in FIG. 8, the outer layer 23 being 1/16 thick and the annular ribs 24 being ls thick and spaced 1A center to center. Eight vent holes of /lG" diameter were provided for each chamber 26. The outer layer 23 was reinforced by thin peripherally stretchable and axially stretch resistant nylon fabric immediately below the outer surface. In its relaxed state the neoprene sleeve had an outer diameter of 4%".
The valve sleeve was wetted with crude oil and then pushed into the casing and produced a tight seal against a differential pressure of 3000 p.s.i. The force required for insertion of the valve sleeve into, and movement of the valve sleeve within, the casing was less than in Test l. This appears to be due to the near cylindrical shape of the elastomer body which promotes maintenance of a lm of lubricant over its surface.
Test 4.-For this test an elastomer sleeve of the shape shown in FIG. 9 was applied to the sleeve valve core. The elastomer sleeve consisted of open-pore polyurethane sponge material of a density of ll lb. per cubic foot and an extremely tine pore structure. In its relaxed condition the sleeve had an outer diameter of 41/2" which after aging in 4 tubing at a temperature of 212 was reduced to 45/16". The outer skin of the elastomer was tough and denser than the interior, but porous.
The valve sleeve was inserted into the casing and showed traces of leakage at a differential pressure of 1900 p.s.i.
Test 5.-An elastomer sleeve of t-he type shown in FIG. l was applied to the sleeve valve core. The elastomer sleeve was composed of polyurethane open-pore sponge material of a density of ll lb. per cubic foot and extremely tine pore size. The material had Mr perforatons, as shown at 32 in FIG. l0, the perforations being spaced One inch, center to center. The outer diameter of the sponge body was 4%". The sponge body was impregnated with ANI-9 gel forming aqueous solution containing l0 percent of NaCl and then heated to 160 F. for 5 minutes to insure complete gelling of the solution. The resulting elastomer was then dried to dehydrate the gel Within the pores.
The valve sleeve was inserted into the casing in dehydrated condition and the casing was then filled with water. After 6 hours the valve sleeve was subjected to a differential pressure test and was found to resist 4000 p.s.i. pressure without leaking.
Insertion of the dehydrated valve sleeve into the casing required the least force of all of the tests.
Apparently the superior sealing ability of the elastomer is due to the swelling of the gel component within the pores.
Test 6.-A valve sleeve was constructed according to FIGS. 6 and 7 with an elastomer body of Nordel rubber (ethylene propylene hydrocarbon rubber cured with benzoyl peroxide) composed of rings having a diameter of 41/6, a width of l of the shape shown in FIG. 5. The rubber contained a thin hydrocarbon oil (commercially available as Flexon 765) in an amount equal to 50 percent of the total elastomer volume. The sleeve was immersed in benzene for 48 hours for the purpose of extracting the plasticizer and then air dried for 48 hours to extract the benzene, at which time the rubber rings had shrunk to an outer diameter of 3%" as shown in FIG. 6. The sleeve was then inserted into the casing filled with crude oil which caused the elastomer body to swell. After 24 hours of swelling the valve sleeve withstood a differential pressure of 4000 p.s.i.
Test 7.-A packer comprising an elastomer layer of 3" length and 3%" outer diameter composed of Nordel rubber was placed in a 4 casing and then wetted by hydrocarbon plasticizer oil having a boiling point of 380 C. The elastomer swelled into contact with the casing and produced a seal capable of withstanding 280 p.s.i. differential pressure. The amount of oil used was about 20 percent greater than the amount absorbed by the elastomer during swelling.
After exposure to air for days the seal withstood the same test pressure without leakage.
The test indicates that by swelling the elastomer seal with a swelling liquid of high boiling point, such as plasticizers compatible with the elastomer material, the seal may even be exposed to air after swelling or exposed to a gaseous atmosphere in ywhich swelling liquids of low boiling points, such as gasoline or water, would evaporate too fast to be practical.
This property makes swelled elastomer seals as represented by this test highly useful not only for underground installations but also for above ground use, for example as a seal in water drain ducts.
In all instances the valve sleeves were removed from the casing by forceful extraction against the sealing force of the elastomer to demonstrate the axial displacement of the valve sleeves. The outer diameters after withdrawal were as follows: Test l 4"};g; Test 2-4/s; Test 3 4"}2; Test 4-4-/UW; Test 5 iii/10W; Test 6-4343.
The elastomers employed in the practice of this invention are preferably of the highly exible type such as rubber, polyesters7 polyurethanes with elongations in excess Of 200 percent and a low tendency to set after compression, i.e., materials having high elastic recovery after release from compression over long periods of time, such as 24 months, and temperatures of the order of 160 F.
The elastomers should be chemically resistant to crude oil and salt water at temperatures of the order of 160 F. in the sense that their physical strength should remain substantial even though the material may swell appreciably. Indeed swellability is a desirable characteristic in most instances.
The following were found to be satisfactory: polychloroprene, a substance commercially known as "neoprene rubber. It exhibts lov. crude oil swellability. Butadicne acrylonitriie copolymer is commercially known as Buna N rubber'. It has low crude oil swellability and exhibits low compression set. Polyurethane rubber known commercially as Adiprene and Cyanaprene Fluoroelastomer rubber commercially known as Viton and Hydelon. Ethylene propylene hydrocarbon rubber is commercially known as Nordel rubber. It represents an example of a highly swellable substance. The degree of swelling may be amplified. Oil swellable rubbers are preferably cured in a highly plasticized form. Extraction of the plasticizer by leaching in a volatile solvent, such as benzene, followed by evaporation of the solvent leads to appreciable shrinkage. If the shrunk condition is taken as the starting condition a great increase in volume by subsequent swelling can be produced.
The volume of the plasticizer may range between 25 and 75 percent of the total volume.
The commercially available elastomcrs of this type contain as plasticizers hydrocarbon oils of high boiling point. Such oils are commercially available under a wide range of trade designations, such as Flexon 765 or Flexon 865, Conoco H-35.
A particularly advantageous form of rubber is cured with a volatile plasticizer such as benzene under conditions preventing loss of the plasticizer during the curing process. In that case subsequent extraction of the plasticizer involves no more than simple evaporation.
Open-pore sponge type elastomers may be of the rubber or the polyurethane type.
Impregnating solutions for producing water swellable gels are mad-e from materials known in the well drilling art as grouting materials. One such grouting material, known by its trade designation AM-9, is composed of parts of acrilamide, parts of methylene bisacrilamide, 900 parts of water and a small amount of a catalyst, such as ammonium persulfate. After mixing with the water the resulting liquid sets to form a stiff gel.
Gels made with pure water in the gel forming solution shrink upon contact with saline underground water such as occur in oil wells. To eliminate such shrinkage I prefer to make gel bodies for underground use from a gel forming aqueous solution containing an inert salt or solute of a concentration at least of the order of that of the saline water to be encountered underground.
Additional swelling results if the solution concentration is made higher than that of the underground saline water. In that case the gel bodies actually swell beyond their normal gel setting volumes upon contact with the underground water of lower concentration.
Solution concentrations of .1 N up to saturation of the inert solute or salt, such as NaCl, is generally satisfactory.
In view of the commercial availability of a wide variety of oil swellable and nonswellable elastomers in solid or porous form, other materials than herein specifically mentioned may be employed. A practical test is conducted by cutting a test strip of about 10 x 20 x 100 mm. which is then subjected to test to determine its tensile strength before and after contact with hydrocarbons, its swellability and the degree to which it may be preshrunk by plasticizer extraction. Plasticized elastomers are commercially available and can be made with different plasticizer contents, such as 25, 50, and 75 percent of total volume.
In conducting tests materials were used which their manufacturer, who was not aware of the intended use, described as not suitable or not recommended for use in contact with hydrocarbons because of the high degree of swelling experienced in such use. These materials proved very well suited for the practice of the invention, as swellability is a feature, not a disadvantage.
Example 1.-In a well tted with a cemented casing three potentially productive zones were perforated. The
top zone had a vertical spread of the perforations of 14- feet, the intermediate zone 19 feet, and the lowest zone 46 feet. The casing was reamed to remove perforation burrs and otherwise provide a smooth surface.
The zones were then individually tested and treated with the aid of straddle test tools with hydraulically operated packers at each end. It was determined that the upper zone produced salt water only, that the intermediate zone produced oil from the upper 6 feet and water from the lower 13 feet. The lowest zone was found to produce oil and gas from its upper perforations and water from the bottom 17 feet of perforations.
Valve sleeves were then installed to seal the upper zone permanently and to control the ow from the lower two zones. For this purpose the casing was first filled with crude oil by circulation and swabbing through tubing extending to the bottom of the well.
IAfter withdrawal of the tubing a valve sleeve 30 feet in length with Nordel rubber sleeves at each end and extending for a length of 4 feet each was gripped by an adjustable internal friction gripper, adjusted to sustain 21/2 times the weight of the sleeve. The friction gripper was attached to the end of a wire line, lowered into the casing with the gripped sleeve and maintained at the proper level to shut olf the lower 17 feet of the bottom zone. After six hours the swellable elastomer sleeve had swelled suicientlyto seat the sleeve in the casing against the pull of the gripper which slipped out of the sleeve when a pull in excess of 21/2 times the sleeve weight was exerted.
The upper ll foot portion of the bottom zone was closed next by a 24 foot valve sleeve with a 4 foot elastomer covering at each end.
The entire intermediate zone was sealed by a 31 foot valve sleeve with 4 foot elastomer portions at each end, and finally the entire top zone was sealed by a valve sleeve of a total length of 25 feet having 4 foot elastomer portions at each end.
A production string with pump was then installed extending to a point below the bottom zone.
Production was obtained from the uncovered 18 foot portion of the bottom zone. When, after a period of production, the gas/oil ratio and the water/oil ratio increased to an undesired degree, the lower 3() foot valve sleeve was raised and the upper 24 foot valve sleeve was lowered by means of a string of weighted tubing with a gripper or anchor at its lower end.
The gripper grasped the respective sleeve in the manner of an internal chuck, and the sleeve was then moved by Iapplication of sufficient force to make it slide.
Eventually the two sleevs within the bottom zone were moved to abut, thereby sealing the lbottom zone, and the 31 foot sleeve valve within the intermediate zone was depressed to produce from the upper 6 foot portion thereof.
It is of course also feasa'ble to install several valve sleeves at their desired levels simultaneously by means of a wireline with several gripping .tools arranged in series, and sleeves engaged by the gripping tools, properly spaced from one another. When all sleeves are lowered into the casing which is filled with crude oil, they expand simultaneously at their respective positions, whereafter the wire line and the gripping tools are withdrawn.
Example 2.-Three valve sleeves with oil swellable elastomer seals were assembled with the required spacing from one another on a tubing string iitted with mechanically expansible line packers or anch-ors. The line packers or anchors were expanded by counterclockwise rotation until they gripped the respective valve sleeves securely.
The tubing string was then lowered into the Water lilled casing of the well. After placement of the sleeves at the desired location crude oil was circulated down the casing and up through lthe tubing string until all water was displaced from the casing. After 24 hours of immersion of the sleeves in crude oil the valve sleeves were set sufficiently firmly for removal of the string and of the packers or anchors thereon by clockwise rotation of the string, thereby contracting the packers and anchors to free them from the cylindrical center passage of the valve sleeves and permit withdrawal of the string.
The tubing string was then replaced 'by a pro-duction string.
Subsequent axial adjustment was accomplished by reinsertion and tightening of a packer or anchor. For this purpose the tubing was loaded with drill collars as closely to the valve sleeve to be depressed as possible. It was also found possible to move the valve sleeves in relatively small increments up or down by bumping involving impacts on the gripped valve sleeve.
It is possible also to adjust valve sleeves by bu-mping by means of a wire line or cable tool. Regular cable drilling equipment is well suitable for this purpose.
In all instances the static force for moving a valve sleeve with two f-our foot elastomer seals ranged between 1 Ito 4 tons.
Example 3.-Valve sleeves with elastomer seals according to FIG. 2 and composed of neoprene `rubber of low swellability compressed by insertion into the casing from an original relaxed diameter of 45/32 to a compresed diameter of 4" were moved a total distance of 4200 feet in a reamed casing containing crude oil and were subsequently tested for sealing ability. The sleeves before the 4200 foot travel sealed securely against a differential pressure of 3200 p.s.i. After withdrawal they were found to be effective against a differential pressure of 2800 p.s.i.
Example 4.--A well of 7%" diameter was drilled and it was determined that a formation of 7 foot thickness was oil bearing.
The well bore was checked by caliper @logging and was found to be a smooth-Walled bore of 7% diameter over a distance of 22 feet above the oil bearing formation and 19 feet below the formation.
In lieu of installation of a casing, a 2%" tubing string was installed carrying near its lower end a straddle tool capable of establishing a hydraulically tight connection between the tubing interior and the oil bearing zone as follows:
The straddle tool is diagrammatically shown in FIG. 16 and consisted of a steel sleeve 411 of 6" outer diameter and 21 feet length with elastomer seals of Nordel rubber at cach end extending over a distance yof 5 feet from the end of the sleeve. Each seal consisted of :a series of individual rings having an outer diameter of 71A", a width lof 4 and a thickness of 1/2. V-shaped valleys are formed between successive rings.
The rings are built up from strips of rubber 1/16 in thickness and reinforced with nylon fabric resisting `axial elongation but permitting radial expansion. About 8 turns of the strip material forms the 1/ thickness of the ring which after winding are cured to assume their final unexpanded shape.
The sleeve 411 was connected to the tubing 39 by spiders 41 and 42 permitting passage of liquid through spider apertures 43 from the space above the straddle tool -to the space below and vice versa.
Passages 44 temporarily sealed by aluminum plugs 45 were provided to establish communication between the interior of the tubing string 39 and the annular space 46 defined by the elastomer seals 16, the well bore 31 and the sleeve 11.
T he tubing string was lowered into the we'll to a position in which the sleeve straddled the formation, the bottom end of the string extending 50 feet below the straddle tool. The well bore was then filled with crude oil containing about 40 percent gasoline by volume by circulating the oil down the tubing and up the tubing by swabbing.
After 48 hours the elastomer seals had expanded to form a lluid and pressure tight seal.
In order to prevent or reduce leakage from the spaces above and below the straddle seal through fractures or porous portions of the formation, the oil in the annular space above and below the sleeve was replaced by a slurry of Bentonite and gel particles made by grinding AM-9 gel. The slurry effects a seal of porous portions which tend to form a passage for leakage liquid.
The tubing was then sealed below the straddle tool with a packer and the plugs 45 were dissolved by 1 N NaOH in water solution, whereafter the installation was ready for production.
Example 5.--A valve sleeve was constructed according to FIG. 6. The sleeve was 18 feet in length and cornprised water swellable elastomer seals of 4 feet length at each end. The sleeve was installed in a well casing of 4 inner diameter to straddle perforations in the casing and in the oil bearing Zone about it, the perforations being within a vertical spread of 6 feet. The elastomer layers were bonded to the valve tubing and consisted of cellulose sponge cloth of V2. thickness impregnated with a gel formed of AM-9 gel compound and 8 percent aqueous NaCl solution, subsequently dried and shrunk to an outer diameter of 3%.
The valve sleeve was then lowered into the waterfilled casing by wire line and gripper. After 6` hours the elastomers had swelled to seat tightly in the casing and seal the perforations. The packer was tested and did not leak at 3000 p.s.i. of external overpressure. The well was then tested below the sealed zone and after 18 days the packer was pulled upwards in the casing for a distance of 20 feet by wire line and gripper to uncover the perforations. The well was then produced from this Zone.
What is claimed is:
1. In the combination of (a) a well casing,
('b) a cement layer between said casing and its surrounding formation, there being (c) perforations extending through said casing and said cement layer into the formation;
and a valve sleeve within said casing, the sleeve comprising (I) a central tubular rigid metal core providing a central passageway for fluid axially through the sleeve,
(II) and an outer covering of elastomer material secured to said tubular core, said covering comprising, in alternating sequence, substantially annular elastomer portions and substantially annular void portions,
the improvement according to which said outer covering in its relaxed condition has an external diameter larger than the internal diameter of the casing, the outer covering being inserted into the casing (a) in radially compressed condition, thereby displacing a portion of the elastomer annuli into said void portions, and
(b) presoaked in a hydrocarbon liquid before insertion into the casing, thereby providing a lubricating film between said covering and said casing.
2. The combination as claimed in claim 1 in which the covering of elastomer material comprises an inner sleeve portion from which annular rib portions extend outwardly forming annular void spaces of substantially V-shaped cross section between successive ribs.
3. The combination as claimcd in claim 1 in which the covering of elastomer material comprises a common outer sleeve portion for bearing against said casing, and annular rib portions integral with said sleeve portion, said rib portion extending inwardly towards said metal core.
References Cited UNITED STATES PATENTS 500,558 10/1895 Fraser et al. 166-23 672,255 4/1901 Boberg 277-123 2,094,691 10/1937 Williams 277--1 2,452,466 10/1948 Jaswell 166-179 2,849,070 8/1958 Maly 277--11 2,945,541 7/1960 Maly et al 166-187 3,067,819 12/1962 Gore 166-179 3,134,442l 4/ 1964 Jennings 166-207 JAMES A. LEPPINK, Primary Examiner.
UNITED STATES PATENT OFFICE CERTIFICATE OF CORRECTION Patent No. 3 ,38S ,367 May Z8 1968 Paul Kollsman It is certified that error appears in the above identified patent and that said Letters Patent are hereby corrected as shown below:
Column 10, line 15, ,Isleevs" should read sleeves Column l2, line 51, "500,558" should read 50,558
Signed and sealed this 16th day of December 1969.
WILLIAM E. SCHUYLER, JR
Edward M. Fletcher, Jr.
Commissioner of Patents Attesting Officer
|Patente citada||Fecha de presentación||Fecha de publicación||Solicitante||Título|
|US500558 *||27 Mar 1893||4 Jul 1893||Printing aniline-black|
|US672255 *||14 May 1900||16 Abr 1901||Christian Johannes Lorenz Boberg||Stuffing-box packing.|
|US2094691 *||31 May 1933||5 Oct 1937||United Gas Improvement Co||Packed joint and method of leakproofing the same|
|US2452466 *||19 Jul 1944||26 Oct 1948||Roy Jaswell||Sealing tip for well casings|
|US2849070 *||2 Abr 1956||26 Ago 1958||Union Oil Co||Well packer|
|US2945541 *||17 Oct 1955||19 Jul 1960||Union Oil Co||Well packer|
|US3067819 *||2 Jun 1958||11 Dic 1962||Gore George L||Casing interliner|
|US3134442 *||5 May 1961||26 May 1964||Pan American Petroleum Corp||Apparatus for lining wells|
|Patente citante||Fecha de presentación||Fecha de publicación||Solicitante||Título|
|US4137970 *||20 Abr 1977||6 Feb 1979||The Dow Chemical Company||Packer with chemically activated sealing member and method of use thereof|
|US4193105 *||17 May 1977||11 Mar 1980||Wavin B.V.||Pipe with an external sealing body|
|US4936386 *||9 Nov 1989||26 Jun 1990||American Colloid Company||Method for sealing well casings in the earth|
|US5078211 *||19 Dic 1989||7 Ene 1992||Swineford Richard A||Plastic packer|
|US5219028 *||25 Feb 1992||15 Jun 1993||Conoco Inc.||Well casing and well casing method|
|US6834725||12 Dic 2002||28 Dic 2004||Weatherford/Lamb, Inc.||Reinforced swelling elastomer seal element on expandable tubular|
|US6840325||26 Sep 2002||11 Ene 2005||Weatherford/Lamb, Inc.||Expandable connection for use with a swelling elastomer|
|US6848505||29 Ene 2003||1 Feb 2005||Baker Hughes Incorporated||Alternative method to cementing casing and liners|
|US6896063 *||7 Abr 2003||24 May 2005||Shell Oil Company||Methods of using downhole polymer plug|
|US6907937||23 Dic 2002||21 Jun 2005||Weatherford/Lamb, Inc.||Expandable sealing apparatus|
|US6935432||20 Sep 2002||30 Ago 2005||Halliburton Energy Services, Inc.||Method and apparatus for forming an annular barrier in a wellbore|
|US6988557||22 May 2003||24 Ene 2006||Weatherford/Lamb, Inc.||Self sealing expandable inflatable packers|
|US7013979 *||8 Abr 2005||21 Mar 2006||Baker Hughes Incorporated||Self-conforming screen|
|US7066259||24 Dic 2002||27 Jun 2006||Weatherford/Lamb, Inc.||Bore isolation|
|US7070001||21 Jun 2005||4 Jul 2006||Weatherford/Lamb, Inc.||Expandable sealing apparatus|
|US7143832||29 Jun 2001||5 Dic 2006||Halliburton Energy Services, Inc.||Well packing|
|US7228915||28 Ene 2002||12 Jun 2007||E2Tech Limited||Device and method to seal boreholes|
|US7290606 *||2 Sep 2005||6 Nov 2007||Baker Hughes Incorporated||Inflow control device with passive shut-off feature|
|US7299882 *||19 Ene 2007||27 Nov 2007||Halliburton Energy Services, Inc.||Annular isolators for expandable tubulars in wellbores|
|US7320367 *||19 Ene 2007||22 Ene 2008||Halliburton Energy Services, Inc.||Annular isolators for expandable tubulars in wellbores|
|US7337841||24 Mar 2004||4 Mar 2008||Halliburton Energy Services, Inc.||Casing comprising stress-absorbing materials and associated methods of use|
|US7357189||12 Feb 2004||15 Abr 2008||Weatherford/Lamb, Inc.||Seal|
|US7363986||19 Ene 2007||29 Abr 2008||Halliburton Energy Services, Inc.||Annular isolators for expandable tubulars in wellbores|
|US7373991||27 Mar 2006||20 May 2008||Schlumberger Technology Corporation||Swellable elastomer-based apparatus, oilfield elements comprising same, and methods of using same in oilfield applications|
|US7404437||3 Ago 2007||29 Jul 2008||Halliburton Energy Services, Inc.||Annular isolators for expandable tubulars in wellbores|
|US7407007||26 Ago 2005||5 Ago 2008||Schlumberger Technology Corporation||System and method for isolating flow in a shunt tube|
|US7407165 *||4 Abr 2000||5 Ago 2008||Hutchinson Fts, Inc.||Composite sleeve for sealing a tubular coupling|
|US7409999||29 Jul 2005||12 Ago 2008||Baker Hughes Incorporated||Downhole inflow control device with shut-off feature|
|US7422071 *||5 Ene 2006||9 Sep 2008||Hills, Inc.||Swelling packer with overlapping petals|
|US7472757||19 Oct 2006||6 Ene 2009||Halliburton Energy Services, Inc.||Well packing|
|US7493947||21 Dic 2005||24 Feb 2009||Schlumberger Technology Corporation||Water shut off method and apparatus|
|US7510011||6 Jul 2006||31 Mar 2009||Schlumberger Technology Corporation||Well servicing methods and systems employing a triggerable filter medium sealing composition|
|US7527099||22 Jul 2004||5 May 2009||Shell Oil Company||System for sealing a space in a wellbore|
|US7543640||1 Sep 2005||9 Jun 2009||Schlumberger Technology Corporation||System and method for controlling undesirable fluid incursion during hydrocarbon production|
|US7578354 *||11 Jun 2007||25 Ago 2009||E2Tech Limited||Device and method to seal boreholes|
|US7597150||1 Feb 2008||6 Oct 2009||Baker Hughes Incorporated||Water sensitive adaptive inflow control using cavitations to actuate a valve|
|US7597152||13 Dic 2007||6 Oct 2009||Baker Hughes Incorporated||Swelling layer inflatable|
|US7624793||8 Sep 2007||1 Dic 2009||Halliburton Energy Services, Inc.||Method and apparatus for perforating and isolating perforations in a wellbore|
|US7665537||10 Mar 2005||23 Feb 2010||Schlumbeger Technology Corporation||System and method to seal using a swellable material|
|US7699115||9 Mar 2005||20 Abr 2010||Shell Oil Company||Method for applying an annular seal to a tubular element|
|US7703539||21 Mar 2007||27 Abr 2010||Warren Michael Levy||Expandable downhole tools and methods of using and manufacturing same|
|US7762341||13 May 2008||27 Jul 2010||Baker Hughes Incorporated||Flow control device utilizing a reactive media|
|US7762344||19 Oct 2007||27 Jul 2010||Halliburton Energy Services, Inc.||Swellable packer construction for continuous or segmented tubing|
|US7775271||11 Jul 2008||17 Ago 2010||Baker Hughes Incorporated||Device and system for well completion and control and method for completing and controlling a well|
|US7775277||24 Jun 2008||17 Ago 2010||Baker Hughes Incorporated||Device and system for well completion and control and method for completing and controlling a well|
|US7784543||11 Jul 2008||31 Ago 2010||Baker Hughes Incorporated||Device and system for well completion and control and method for completing and controlling a well|
|US7789139||23 Jun 2008||7 Sep 2010||Baker Hughes Incorporated||Device and system for well completion and control and method for completing and controlling a well|
|US7789151||18 Jun 2008||7 Sep 2010||Baker Hughes Incorporated||Plug protection system and method|
|US7789152||15 Ago 2008||7 Sep 2010||Baker Hughes Incorporated||Plug protection system and method|
|US7793714||23 Jun 2008||14 Sep 2010||Baker Hughes Incorporated||Device and system for well completion and control and method for completing and controlling a well|
|US7798223||27 Jun 2006||21 Sep 2010||Weatherford/Lamb, Inc.||Bore isolation|
|US7814974||17 Jun 2008||19 Oct 2010||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US7819190||17 Jun 2008||26 Oct 2010||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US7819200||17 Feb 2010||26 Oct 2010||Shell Oil Company||Method of creating an annular seal around a tubular element|
|US7823645||21 Ago 2007||2 Nov 2010||Baker Hughes Incorporated||Downhole inflow control device with shut-off feature|
|US7823649||2 Abr 2008||2 Nov 2010||Halliburton Energy Services, Inc.||System and method for plugging a side pocket mandrel using a swelling plug|
|US7832491||25 Nov 2008||16 Nov 2010||Halliburton Energy Services, Inc.||Well packing|
|US7849930||8 Sep 2007||14 Dic 2010||Halliburton Energy Services, Inc.||Swellable packer construction|
|US7866408||14 Nov 2007||11 Ene 2011||Halliburton Energy Services, Inc.||Well tool including swellable material and integrated fluid for initiating swelling|
|US7891430||19 Oct 2007||22 Feb 2011||Baker Hughes Incorporated||Water control device using electromagnetics|
|US7913755||11 Jul 2008||29 Mar 2011||Baker Hughes Incorporated||Device and system for well completion and control and method for completing and controlling a well|
|US7913765||19 Oct 2007||29 Mar 2011||Baker Hughes Incorporated||Water absorbing or dissolving materials used as an in-flow control device and method of use|
|US7918272||19 Oct 2007||5 Abr 2011||Baker Hughes Incorporated||Permeable medium flow control devices for use in hydrocarbon production|
|US7918275||19 Nov 2008||5 Abr 2011||Baker Hughes Incorporated||Water sensitive adaptive inflow control using couette flow to actuate a valve|
|US7931081||17 Jun 2008||26 Abr 2011||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US7942206||14 Ago 2008||17 May 2011||Baker Hughes Incorporated||In-flow control device utilizing a water sensitive media|
|US7946351 *||12 Dic 2005||24 May 2011||Halliburton Energy Services, Inc.||Method and device for sealing a void incompletely filled with a cast material|
|US7971640 *||13 Mar 2006||5 Jul 2011||Halliburton Energy Services, Inc.||Method and device for setting a bottom packer|
|US7992637||2 Abr 2008||9 Ago 2011||Baker Hughes Incorporated||Reverse flow in-flow control device|
|US8006773||10 Nov 2009||30 Ago 2011||Halliburton Energy Services, Inc.||Swellable packer construction for continuous or segmented tubing|
|US8042618 *||11 Ago 2009||25 Oct 2011||Halliburton Energy Services, Inc.||Methods for swelling swellable elements in a portion of a well using an oil-in-water emulsion|
|US8047298||24 Mar 2009||1 Nov 2011||Halliburton Energy Services, Inc.||Well tools utilizing swellable materials activated on demand|
|US8051914||30 Jul 2010||8 Nov 2011||Halliburton Energy Services, Inc.||Well packing|
|US8056627||2 Jun 2009||15 Nov 2011||Baker Hughes Incorporated||Permeability flow balancing within integral screen joints and method|
|US8069919||11 Nov 2010||6 Dic 2011||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US8069921||2 Abr 2009||6 Dic 2011||Baker Hughes Incorporated||Adjustable flow control devices for use in hydrocarbon production|
|US8096351||19 Oct 2007||17 Ene 2012||Baker Hughes Incorporated||Water sensing adaptable in-flow control device and method of use|
|US8100190 *||11 Ago 2009||24 Ene 2012||Halliburton Energy Services, Inc.||Methods for swelling swellable elements in a portion of a well using a water-in-oil emulsion|
|US8110099||9 May 2007||7 Feb 2012||Contech Stormwater Solutions Inc.||Stormwater filter assembly|
|US8113292||15 Dic 2008||14 Feb 2012||Baker Hughes Incorporated||Strokable liner hanger and method|
|US8132624||2 Jun 2009||13 Mar 2012||Baker Hughes Incorporated||Permeability flow balancing within integral screen joints and method|
|US8151875||15 Nov 2010||10 Abr 2012||Baker Hughes Incorporated||Device and system for well completion and control and method for completing and controlling a well|
|US8151881||2 Jun 2009||10 Abr 2012||Baker Hughes Incorporated||Permeability flow balancing within integral screen joints|
|US8157019||27 Mar 2009||17 Abr 2012||Baker Hughes Incorporated||Downhole swellable sealing system and method|
|US8159226||17 Jun 2008||17 Abr 2012||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US8171999||10 Jun 2008||8 May 2012||Baker Huges Incorporated||Downhole flow control device and method|
|US8215394 *||9 Jun 2009||10 Jul 2012||Baker Hughes Incorporated||Control line patch|
|US8312931||12 Oct 2007||20 Nov 2012||Baker Hughes Incorporated||Flow restriction device|
|US8443907 *||11 Jun 2010||21 May 2013||Baker Hughes Incorporated||Apparatus and method for sealing portions of a wellbore|
|US8453746||20 Abr 2006||4 Jun 2013||Halliburton Energy Services, Inc.||Well tools with actuators utilizing swellable materials|
|US8453750||4 Ago 2011||4 Jun 2013||Halliburton Energy Services, Inc.||Well tools utilizing swellable materials activated on demand|
|US8459366 *||8 Mar 2011||11 Jun 2013||Halliburton Energy Services, Inc.||Temperature dependent swelling of a swellable material|
|US8490707||11 Ene 2011||23 Jul 2013||Schlumberger Technology Corporation||Oilfield apparatus and method comprising swellable elastomers|
|US8499843||22 Feb 2010||6 Ago 2013||Schlumberger Technology Corporation||System and method to seal using a swellable material|
|US8499844 *||14 Jun 2012||6 Ago 2013||Weatherford/Lamb, Inc.||Expandable packer|
|US8544548||19 Oct 2007||1 Oct 2013||Baker Hughes Incorporated||Water dissolvable materials for activating inflow control devices that control flow of subsurface fluids|
|US8550166||21 Jul 2009||8 Oct 2013||Baker Hughes Incorporated||Self-adjusting in-flow control device|
|US8555958||19 Jun 2008||15 Oct 2013||Baker Hughes Incorporated||Pipeless steam assisted gravity drainage system and method|
|US8555961||5 Ene 2009||15 Oct 2013||Halliburton Energy Services, Inc.||Swellable packer with composite material end rings|
|US8627894 *||12 Dic 2011||14 Ene 2014||Swelltec Limited||Ring member for a swellable downhole packer|
|US8646535||7 Ago 2012||11 Feb 2014||Baker Hughes Incorporated||Flow restriction devices|
|US8689894||21 Mar 2008||8 Abr 2014||Schlumberger Technology Corporation||Method and composition for zonal isolation of a well|
|US8726992||4 Abr 2011||20 May 2014||Halliburton Energy Services, Inc.||Method and device for filling a void incompletely filled by a cast material|
|US8776881||17 Jun 2008||15 Jul 2014||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US8807209 *||22 Mar 2010||19 Ago 2014||Baker Hughes Incorporated||Swellable material and method|
|US8833473||22 Ago 2008||16 Sep 2014||Swellfix B.V.||Sealing assembly|
|US8839849||18 Mar 2008||23 Sep 2014||Baker Hughes Incorporated||Water sensitive variable counterweight device driven by osmosis|
|US8857526 *||26 Abr 2010||14 Oct 2014||Schlumberger Technology Corporation||Mechanically deployable well isolation mechanism|
|US8893809||2 Jul 2009||25 Nov 2014||Baker Hughes Incorporated||Flow control device with one or more retrievable elements and related methods|
|US8931570||8 May 2008||13 Ene 2015||Baker Hughes Incorporated||Reactive in-flow control device for subterranean wellbores|
|US8967281||15 Jul 2013||3 Mar 2015||Weatherford/Lamb, Inc.||Expandable packer|
|US9016371||4 Sep 2009||28 Abr 2015||Baker Hughes Incorporated||Flow rate dependent flow control device and methods for using same in a wellbore|
|US9038740||7 Nov 2011||26 May 2015||Halliburton Energy Services, Inc.||Apparatus and method of forming a plug in a wellbore|
|US9085953||10 Abr 2012||21 Jul 2015||Baker Hughes Incorporated||Downhole flow control device and method|
|US9140095||11 Oct 2013||22 Sep 2015||Weatherford Technology Holdings, Llc||Packer cup for sealing in multiple wellbore sizes eccentrically|
|US9273533||18 Dic 2010||1 Mar 2016||Halliburton Energy Services, Inc.||Well tool including swellable material and integrated fluid for initiating swelling|
|US9303483 *||18 Ene 2008||5 Abr 2016||Halliburton Energy Services, Inc.||Swellable packer with enhanced sealing capability|
|US9388921 *||28 Ago 2013||12 Jul 2016||Carl Freudenberg Kg||Plug-in piece|
|US9464500||27 Ago 2010||11 Oct 2016||Halliburton Energy Services, Inc.||Rapid swelling and un-swelling materials in well tools|
|US9488029||23 Nov 2011||8 Nov 2016||Halliburton Energy Services, Inc.||Swellable packer with enhanced sealing capability|
|US9506320||24 Oct 2012||29 Nov 2016||Halliburton Energy Services, Inc.||Variable flow resistance for use with a subterranean well|
|US9512691 *||19 Dic 2013||6 Dic 2016||Swelltec Limited||Elongated sealing member for downhole tool|
|US9540893||19 Jun 2014||10 Ene 2017||Halliburton Energy Services, Inc.||Cable duct device in a swelling packer|
|US9546528||23 Nov 2009||17 Ene 2017||Halliburton Energy Services, Inc.||Cable duct device in a swelling packer|
|US9551201||15 Ene 2014||24 Ene 2017||Weatherford Technology Holdings, Llc||Apparatus and method of zonal isolation|
|US20030146003 *||24 Dic 2002||7 Ago 2003||Duggan Andrew Michael||Bore isolation|
|US20040020662 *||29 Jun 2001||5 Feb 2004||Jan Freyer||Well packing|
|US20040055760 *||20 Sep 2002||25 Mar 2004||Nguyen Philip D.||Method and apparatus for forming an annular barrier in a wellbore|
|US20040112609 *||12 Dic 2002||17 Jun 2004||Whanger James K.||Reinforced swelling elastomer seal element on expandable tubular|
|US20040118572 *||23 Dic 2002||24 Jun 2004||Ken Whanger||Expandable sealing apparatus|
|US20040144538 *||29 Ene 2003||29 Jul 2004||Richard Bennett M.||Alternative method to cementing casing and liners|
|US20040194959 *||7 Abr 2003||7 Oct 2004||Chang Benjamin Tai-An||Downhole polymer plug and liner and methods employing same|
|US20040194971 *||28 Ene 2002||7 Oct 2004||Neil Thomson||Device and method to seal boreholes|
|US20050016740 *||12 Feb 2004||27 Ene 2005||Walter Aldaz||Seal|
|US20050110217 *||22 Nov 2004||26 May 2005||Baker Hughes Incorporated||Swelling layer inflatable|
|US20050173130 *||8 Abr 2005||11 Ago 2005||Baker Hughes Incorporated||Self-conforming screen|
|US20050199401 *||10 Mar 2005||15 Sep 2005||Schlumberger Technology Corporation||System and Method to Seal Using a Swellable Material|
|US20050211445 *||24 Mar 2004||29 Sep 2005||Ravi Krishna M||Casing comprising stress-absorbing materials and associated methods of use|
|US20050252651 *||5 Sep 2003||17 Nov 2005||Shell Oil Company||Wellbore device for selective transfer of fluid|
|US20050269108 *||21 Jun 2005||8 Dic 2005||Weatherford/Lamb, Inc.||Expandable sealing apparatus|
|US20060076150 *||2 Sep 2005||13 Abr 2006||Baker Hughes Incorporated||Inflow control device with passive shut-off feature|
|US20060113089 *||29 Jul 2005||1 Jun 2006||Baker Hughes Incorporated||Downhole inflow control device with shut-off feature|
|US20060175065 *||21 Dic 2005||10 Ago 2006||Schlumberger Technology Corporation||Water shut off method and apparatus|
|US20060272806 *||5 Ene 2006||7 Dic 2006||Wilkie Arnold E||Swelling packer with overlapping petals|
|US20060283607 *||27 Jun 2006||21 Dic 2006||Duggan Andrew M||Bore isolation|
|US20070012436 *||9 Dic 2003||18 Ene 2007||Rune Freyer||Cable duct device in a swelling packer|
|US20070027245 *||27 Mar 2006||1 Feb 2007||Schlumberger Technology Corporation||Swellable Elastomer-Based Apparatus, Oilfield Elements Comprising Same, and Methods of Using Same in Oilfield Applications|
|US20070044962 *||26 Ago 2005||1 Mar 2007||Schlumberger Technology Corporation||System and Method for Isolating Flow In A Shunt Tube|
|US20070044963 *||1 Sep 2005||1 Mar 2007||Schlumberger Technology Corporation||System and Method for Controlling Undesirable Fluid Incursion During Hydrocarbon Production|
|US20070056735 *||22 Jul 2004||15 Mar 2007||Bosma Martin Gerard R||System for sealing a space in a wellbore|
|US20070108575 *||3 Nov 2006||17 May 2007||Robert Montgomery||Semiconductor package that includes stacked semiconductor die|
|US20070114016 *||19 Ene 2007||24 May 2007||Halliburton Energy Services, Inc.||Annular Isolators for Expandable Tubulars in Wellbores|
|US20070114017 *||19 Ene 2007||24 May 2007||Halliburton Energy Services, Inc.||Annular Isolators for Expandable Tubulars in Wellbores|
|US20070114018 *||19 Ene 2007||24 May 2007||Halliburton Energy Services, Inc.||Annular Isolators for Expandable Tubulars in Wellbores|
|US20070114044 *||19 Ene 2007||24 May 2007||Halliburton Energy Services, Inc.||Annular Isolators for Expandable Tubulars in Wellbores|
|US20070151723 *||19 Oct 2006||5 Jul 2007||Jan Freyer||Well Packing|
|US20070205002 *||9 Mar 2005||6 Sep 2007||Baaijens Matheus N||System for Sealing an Annular Space in a Wellbore|
|US20070221387 *||21 Mar 2007||27 Sep 2007||Warren Michael Levy||Expandable downhole tools and methods of using and manufacturing same|
|US20070227734 *||12 Dic 2005||4 Oct 2007||Rune Freyer||Method and Device for Sealing a Void Incompletely Filled with a Cast Material|
|US20070246225 *||20 Abr 2006||25 Oct 2007||Hailey Travis T Jr||Well tools with actuators utilizing swellable materials|
|US20070257441 *||25 Oct 2005||8 Nov 2007||Baaijens Matheus N||Sealing of a Wellbore Device in a Tubular Element|
|US20070267201 *||3 Ago 2007||22 Nov 2007||Halliburton Energy Services, Inc.||Annular Isolators for Expandable Tubulars in Wellbores|
|US20080000646 *||11 Jun 2007||3 Ene 2008||Neil Thomson||Device and method to seal boreholes|
|US20080006413 *||6 Jul 2006||10 Ene 2008||Schlumberger Technology Corporation||Well Servicing Methods and Systems Employing a Triggerable Filter Medium Sealing Composition|
|US20080035350 *||21 Ago 2007||14 Feb 2008||Baker Hughes Incorporated||Downhole Inflow Control Device with Shut-Off Feature|
|US20080066912 *||8 Sep 2007||20 Mar 2008||Rune Freyer||Method and Apparatus for Perforating and Isolating Perforations in a Wellbore|
|US20080078561 *||8 Sep 2007||3 Abr 2008||Chalker Christopher J||Swellable Packer Construction|
|US20080093086 *||19 Oct 2007||24 Abr 2008||Courville Perry W||Swellable packer construction for continuous or segmented tubing|
|US20080156502 *||13 Mar 2006||3 Jul 2008||Rune Freyer||Method and Device for Setting a Bottom Packer|
|US20080185158 *||18 Ene 2008||7 Ago 2008||Halliburton Energy Services, Inc.||Swellable packer with enhanced sealing capability|
|US20080220991 *||6 Mar 2007||11 Sep 2008||Halliburton Energy Services, Inc. - Dallas||Contacting surfaces using swellable elements|
|US20080251250 *||25 Jun 2008||16 Oct 2008||Halliburton Energy Services, Inc.||Annular Isolators for Expandable Tubulars in Wellbores|
|US20080290603 *||23 May 2008||27 Nov 2008||Baker Hughes Incorporated||Swellable material and method|
|US20090084559 *||25 Nov 2008||2 Abr 2009||Halliburton Energy Services, Inc.||Well packing|
|US20090095484 *||14 Ago 2008||16 Abr 2009||Baker Hughes Incorporated||In-Flow Control Device Utilizing A Water Sensitive Media|
|US20090095487 *||12 Oct 2007||16 Abr 2009||Baker Hughes Incorporated||Flow restriction device|
|US20090101329 *||19 Oct 2007||23 Abr 2009||Baker Hughes Incorporated||Water Sensing Adaptable Inflow Control Device Using a Powered System|
|US20090101341 *||19 Oct 2007||23 Abr 2009||Baker Hughes Incorporated||Water Control Device Using Electromagnetics|
|US20090101342 *||19 Oct 2007||23 Abr 2009||Baker Hughes Incorporated||Permeable Medium Flow Control Devices for Use in Hydrocarbon Production|
|US20090101352 *||19 Oct 2007||23 Abr 2009||Baker Hughes Incorporated||Water Dissolvable Materials for Activating Inflow Control Devices That Control Flow of Subsurface Fluids|
|US20090101353 *||19 Oct 2007||23 Abr 2009||Baker Hughes Incorporated||Water Absorbing Materials Used as an In-flow Control Device|
|US20090101355 *||19 Oct 2007||23 Abr 2009||Baker Hughes Incorporated||Water Sensing Adaptable In-Flow Control Device and Method of Use|
|US20090101357 *||11 Jul 2008||23 Abr 2009||Baker Hughes Incorporated||Device and system for well completion and control and method for completing and controlling a well|
|US20090101360 *||24 Jun 2008||23 Abr 2009||Baker Hughes Incorporated||Device and system for well completion and control and method for completing and controlling a well|
|US20090130938 *||23 May 2008||21 May 2009||Baker Hughes Incorporated||Swellable material and method|
|US20090179383 *||5 Ene 2009||16 Jul 2009||Halliburton Energy Services, Inc.||Swellable packer with composite material end rings|
|US20090194289 *||1 Feb 2008||6 Ago 2009||Baker Hughes Incorporated||Water sensitive adaptive inflow control using cavitations to actuate a valve|
|US20090236102 *||18 Mar 2008||24 Sep 2009||Baker Hughes Incorporated||Water sensitive variable counterweight device driven by osmosis|
|US20090250222 *||2 Abr 2008||8 Oct 2009||Baker Hughes Incorporated||Reverse flow in-flow control device|
|US20090250227 *||2 Abr 2008||8 Oct 2009||Halliburton Energy Services, Inc.||A System And Method For Plugging A Side Pocket Mandrel Using A Swelling Plug|
|US20090255687 *||10 Abr 2008||15 Oct 2009||Halliburton Energy Services, Inc.||Sealing Between Alignable Windows for Lateral Wellbore Drilling|
|US20090277650 *||8 May 2008||12 Nov 2009||Baker Hughes Incorporated||Reactive in-flow control device for subterranean wellbores|
|US20090283255 *||18 Jul 2008||19 Nov 2009||Baker Hughes Incorporated||Strokable liner hanger|
|US20090283262 *||10 Jun 2008||19 Nov 2009||Baker Hughes Incorporated||Downhole flow control device and method|
|US20090283263 *||17 Jun 2008||19 Nov 2009||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US20090283264 *||17 Jun 2008||19 Nov 2009||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US20090283267 *||17 Jun 2008||19 Nov 2009||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US20090283268 *||17 Jun 2008||19 Nov 2009||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US20090283272 *||19 Jun 2008||19 Nov 2009||Baker Hughes Incorporated||Pipeless sagd system and method|
|US20090283275 *||13 May 2008||19 Nov 2009||Baker Hughes Incorporated||Flow Control Device Utilizing a Reactive Media|
|US20090283278 *||15 Dic 2008||19 Nov 2009||Baker Hughes Incorporated||Strokable liner hanger|
|US20090284260 *||17 Jun 2008||19 Nov 2009||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US20090301726 *||31 Jul 2009||10 Dic 2009||Baker Hughes Incorporated||Apparatus and Method for Controlling Water In-Flow Into Wellbores|
|US20090308619 *||4 Jun 2009||17 Dic 2009||Schlumberger Technology Corporation||Method and apparatus for modifying flow|
|US20100051295 *||10 Nov 2009||4 Mar 2010||Halliburton Energy Services, Inc.||Swellable packer construction for continuous or segmented tubing|
|US20100065284 *||23 Nov 2009||18 Mar 2010||Halliburton Energy Services, Inc.||Cable duct device in a swelling packer|
|US20100139930 *||22 Feb 2010||10 Jun 2010||Schlumberger Technology Corporation||System and method to seal using a swellable material|
|US20100163252 *||21 Mar 2008||1 Jul 2010||Loic Regnault De La Mothe||Method and composition for zonal isolation of a well|
|US20100181080 *||14 Mar 2010||22 Jul 2010||Warren Michael Levy||Expandable downhole tools and methods of using and manufacturing same|
|US20100206589 *||17 Feb 2010||19 Ago 2010||Erik Kerst Cornelissen||Method of creating an annular seal around a tubular element|
|US20100243269 *||24 Mar 2009||30 Sep 2010||Halliburton Energy Services, Inc.||Well Tools Utilizing Swellable Materials Activated on Demand|
|US20100243276 *||27 Mar 2009||30 Sep 2010||Baker Hughes Incorporated||Downhole swellable sealing system and method|
|US20100263858 *||16 Abr 2010||21 Oct 2010||Swellfix B.V.||Swelling seal|
|US20100263880 *||19 Abr 2010||21 Oct 2010||Swellfix B.V.||Downhole seal|
|US20100288514 *||30 Jul 2010||18 Nov 2010||Halliburton Energy Services, Inc.||Well packing|
|US20100300194 *||2 Jun 2009||2 Dic 2010||Baker Hughes Incorporated||Permeability flow balancing within integral screen joints and method|
|US20100300674 *||2 Jun 2009||2 Dic 2010||Baker Hughes Incorporated||Permeability flow balancing within integral screen joints|
|US20100300675 *||2 Jun 2009||2 Dic 2010||Baker Hughes Incorporated||Permeability flow balancing within integral screen joints|
|US20100300676 *||2 Jun 2009||2 Dic 2010||Baker Hughes Incorporated||Permeability flow balancing within integral screen joints|
|US20100300689 *||26 Ago 2008||2 Dic 2010||Swellfix B.V.||Sealing assembly|
|US20100300691 *||2 Jun 2009||2 Dic 2010||Baker Hughes Incorporated||Permeability flow balancing within integral screen joints and method|
|US20100307748 *||9 Jun 2009||9 Dic 2010||Dario Casciaro||Control Line Patch|
|US20100307771 *||22 Ago 2008||9 Dic 2010||Swellfix B.V.||Sealing assembly|
|US20110000684 *||2 Jul 2009||6 Ene 2011||Baker Hughes Incorporated||Flow control device with one or more retrievable elements|
|US20110017470 *||21 Jul 2009||27 Ene 2011||Baker Hughes Incorporated||Self-adjusting in-flow control device|
|US20110036572 *||11 Ago 2009||17 Feb 2011||Weaver Jimmie D||Methods for Swelling Swellable Elements in a Portion of a Well Using an Oil-in-Water Emulsion|
|US20110036573 *||11 Ago 2009||17 Feb 2011||Weaver Jimmie D||Methods for Swelling Swellable Elements in a Portion of a Well Using a Water-in-Oil Emulsion|
|US20110056680 *||11 Nov 2010||10 Mar 2011||Baker Hughes Incorporated||Systems, methods and apparatuses for monitoring and recovery of petroleum from earth formations|
|US20110056686 *||4 Sep 2009||10 Mar 2011||Baker Hughes Incorporated||Flow Rate Dependent Flow Control Device|
|US20110056688 *||15 Nov 2010||10 Mar 2011||Baker Hughes Incorporated||Device and system for well completion and control and method for completing and controlling a well|
|US20110083861 *||18 Dic 2010||14 Abr 2011||Halliburton Energy Services, Inc.||Well tool including swellable material and integrated fluid for initiating swelling|
|US20110094746 *||27 Oct 2009||28 Abr 2011||Allison David B||Swellable Spacer Fluids and Associated Methods|
|US20110101613 *||2 Ene 2009||5 May 2011||Mcrobb Graeme||Improved seal|
|US20110101628 *||22 Mar 2010||5 May 2011||Baker Hughes Incorporated||Swellable material and method|
|US20110121568 *||20 Nov 2009||26 May 2011||Halliburton Energy Services, Inc.||Swellable connection system and method of using the same|
|US20110180264 *||4 Abr 2011||28 Jul 2011||Halliburton Energy Services, Inc.||Method and device for filling a void incompletely filled by a cast material|
|US20110220359 *||10 Mar 2010||15 Sep 2011||Soliman Mohamed Y||Methods Relating to Modifying Flow Patterns Using In-Situ Barriers|
|US20110259611 *||26 Abr 2010||27 Oct 2011||Zafer Erkol||Mechanically deployable well isolation mechanism|
|US20110303421 *||11 Jun 2010||15 Dic 2011||Baker Hughes Incorporated||Apparatus and method for sealing portions of a wellbore|
|US20120103634 *||12 Dic 2011||3 May 2012||Swelltec Limited||Ring Member for a Swellable Downhole Packer|
|US20120227986 *||8 Mar 2011||13 Sep 2012||Halliburton Energy Services, Inc.||Temperature dependent swelling of a swellable material|
|US20140091533 *||28 Ago 2013||3 Abr 2014||Carl Freudenberg Kg||Plug-In Piece|
|US20140224497 *||19 Dic 2013||14 Ago 2014||Swelltec Limited||Elongated sealing member for downhole tool|
|US20140306406 *||19 Nov 2012||16 Oct 2014||Ruma Products Holding B.V.||Seal sleeve and assembly including such a seal sleeve|
|US20150167419 *||6 Feb 2013||18 Jun 2015||Halliburton Energy Services, Inc.||High flow area swellable cementing packer|
|USRE41118||30 Oct 2007||16 Feb 2010||Halliburton Energy Services, Inc.||Annular isolators for expandable tubulars in wellbores|
|CN100449111C||22 Jul 2004||7 Ene 2009||国际壳牌研究有限公司||System for sealing a space in a wellbore|
|CN101080548B||12 Dic 2005||27 Jun 2012||哈利伯顿能源服务公司||A method and a device for sealing a void incompletely filled with a cast material|
|EP1672166A1 *||29 Jun 2001||21 Jun 2006||Halliburton Energy Services, Inc.||Well packing|
|EP1825099A1 *||12 Dic 2005||29 Ago 2007||Easy Well Solutions AS||A method and a device for sealing a void incompletely filled with a cast material|
|EP1825099A4 *||12 Dic 2005||22 Sep 2010||Easy Well Solutions As||A method and a device for sealing a void incompletely filled with a cast material|
|EP2719857A3 *||8 Oct 2013||10 Sep 2014||Weatherford/Lamb, Inc.||Packer cup for sealing in multiple wellbore sizes eccentrically|
|EP2859176A4 *||8 Jun 2012||6 Abr 2016||Halliburton Energy Services Inc||Swellable packer with enhanced anchoring and/or sealing capability|
|WO1996037682A1 *||16 May 1996||28 Nov 1996||Baker Hughes Incorporated||Method and apparatus for sealing and transferring force in a wellbore|
|WO2002059452A1 *||28 Ene 2002||1 Ago 2002||E2 Tech Limited||Device and method to seal boreholes|
|WO2004027209A1 *||18 Sep 2003||1 Abr 2004||Halliburton Energy Services, Inc.||Method and apparatus for forming an annular barrier in a wellbore|
|WO2004067906A1 *||28 Ene 2004||12 Ago 2004||Baker Hughes Incorporated||Alternative method to cementing casing and liners|
|WO2005012686A1 *||22 Jul 2004||10 Feb 2005||Shell Internationale Research Maatschappij B.V.||System for sealing a space in a wellbore|
|WO2005052308A1 *||18 Nov 2004||9 Jun 2005||Baker Hughes Incorporated||Swelling layer inflatable|
|WO2005090741A1 *||9 Mar 2005||29 Sep 2005||Shell Internationale Research Maatschappij B.V.||System for sealing an annular space in a wellbore|
|WO2006045794A1 *||25 Oct 2005||4 May 2006||Shell Internationale Research Maatschappij B.V.||Sealing of a wellbore device in a tubular element|
|WO2008033120A3 *||12 Sep 2006||30 Abr 2009||Christopher J Chalker||Method and apparatus for perforating and isolating perforations in a wellbore|
|WO2008154384A2 *||6 Jun 2008||18 Dic 2008||Baker Hughes Incorporated||Wrap on reactive element barrier packer and method of creating same|
|WO2008154384A3 *||6 Jun 2008||5 Feb 2009||Baker Hughes Inc||Wrap on reactive element barrier packer and method of creating same|
|WO2009073531A1 *||26 Nov 2008||11 Jun 2009||Baker Hughes Incorporated||An improved swellable material and method|
|WO2010020826A1 *||27 Mar 2007||25 Feb 2010||Warren Michael Levy||Expandable downhole tools and methods of using and manufacturing same|
|WO2011061502A2||18 Nov 2010||26 May 2011||Halliburton Energy Services, Inc||Swellable connection system and method of using the same|
|WO2011061502A3 *||18 Nov 2010||22 Sep 2011||Halliburton Energy Services, Inc||Swellable connection system and method of using the same|
|WO2011110802A1||4 Mar 2011||15 Sep 2011||Halliburton Energy Services, Inc||Methods relating to modifying flow patterns using in-situ barriers|
|WO2012028848A2||31 Ago 2011||8 Mar 2012||Halliburton Energy Services, Inc.||Systems and methods for monitoring a parameter of a subterranean formation using swellable materials|
|WO2013095093A1 *||16 Nov 2012||27 Jun 2013||Ruma Products Holding B.V.||Seal sleeve and assembly including such a seal sleeve|
|WO2013096127A2||14 Dic 2012||27 Jun 2013||Halliburton Energy Services, Inc.||Plug and abandonment system|
|WO2013184147A1||8 Jun 2012||12 Dic 2013||Halliburton Energy Services, Inc.||Swellable packer with enhanced anchoring and/or sealing capability|
|WO2014046676A1||21 Sep 2012||27 Mar 2014||Halliburton Energy Services, Inc.||Swellable packer having reinforcement plate|
|WO2015171530A2||5 May 2015||12 Nov 2015||Ferg Thomas Eugene||Swellable elastomer plug and abandonment sealing plugs|
|Clasificación de EE.UU.||166/191, 166/387, 277/615, 277/336, 277/322|
|Clasificación internacional||E21B33/12, E21B33/134, E21B33/13|
|Clasificación cooperativa||E21B33/1208, E21B33/134|
|Clasificación europea||E21B33/134, E21B33/12F|