BACKGROUND
In the drilling and completion industry, the formation of boreholes for the purpose of production or injection of fluid is common. The boreholes are used for exploration or extraction of natural resources such as hydrocarbons, oil, gas, water, and alternatively for CO2 sequestration. A tubular inserted within the borehole is used for allowing the natural resources to flow within the tubular to a surface or other location, or alternatively to inject fluids from the surface to the borehole. Opening perforations through the wall of the tubular to allow fluid flow there through after deployment of the tubular within the borehole is not uncommon. One method of opening such perforations is through ignition of ballistic devices, referred to as perforation guns. Due to the explosive nature of the guns, the art would be receptive to alternate methods of opening perforations in tubulars that do not require guns.
SUMMARY
A downhole system includes a tubular having a wall with at least one port there through; and at least one member arranged to cover the at least one port in a compressed condition thereof, and configured to at least partially displace cement pumped on an exterior of the tubular in a radially expanded condition of the at least one member.
A method of non-ballistically opening ports in a tubular of a downhole system, the method includes covering at least one port in the tubular with an initially compressed radially extendable member; inserting the tubular within a borehole; cementing an annular space between the tubular and the borehole; allowing the radially extendable member to expand from heat of curing cement; and, at least partially displacing the cement with the radially extendable member.
BRIEF DESCRIPTION OF THE DRAWINGS
Referring now to the drawings wherein like elements are numbered alike in the several Figures:
FIG. 1 is a partial quarter cross-sectional view of an exemplary embodiment of a downhole system with a radially extendable member in a non-extended condition;
FIG. 2 is a partial quarter cross-sectional view of the downhole system of FIG. 1 depicting a cementing operation;
FIG. 3 is a partial quarter cross-sectional view of the downhole system of FIG. 1 with the radially extendable member in a partially extended condition;
FIG. 4 is a partial quarter cross-sectional view of the downhole system of FIG. 1 with the radially extendable member in a fully extended condition;
FIG. 5 is a partial quarter cross-sectional view of the downhole system of FIG. 1 with a sleeve shifted and a foam attacking agent introduced;
FIG. 6 is a partial quarter cross-sectional view of the downhole system of FIG. 1 with the radially extendable member removed and a fracture procedure initiated; and,
FIG. 7 is a partial quarter cross-sectional view of another exemplary embodiment of a downhole system with a radially extendable member in a non-extended condition.
DETAILED DESCRIPTION
A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.
Referring to FIGS. 1-6, an exemplary embodiment of a downhole system 10 is illustrated. The system 10 is a non-ballistic tubular perforating system employable as a completion system within a borehole 12 extending through a formation 14. The borehole 12 has a wall 16 that may be fractured to enhance the extraction of natural resources from the formation 14. The system 10 includes a tubular 18 having a wall 20 with flow ports 22 there through. While only one section 24 of the tubular 18 is illustrated, it should be understood that several zones within the borehole 12 may be operated thereon using the system 10 by connecting the section 24 of the tubular 18 to other sections 24, such as by using the threaded connections 26, 28 shown at the uphole and downhole ends 30, 32, respectively, of the section 24, or by connecting the section 24 to other sections 24 with other pieces of tubular (not shown) positioned there between. Cement 34 (shown in FIGS. 2-6 only) is positionable radially of the tubular 18 in an annular space 36 between the wall 20 of the tubular 18 and the wall 16 of the borehole 12, as will be further described below. At least one radially extendable member 38 is positioned radially outwardly of the tubular 18 in locations covering the ports 22. As illustrated, the ports 22 are elongated apertures in the wall 20 that that are radially distributed about the tubular 18, although other shapes and arrangements of the ports 22 may also be included in the system 10. For operating within different longitudinally spaced zones of the borehole 12, longitudinally spaced ports 22 can be provided, such as by the interconnection of two or more of the sections 24 of the tubular 18. The member 38 can be provided at discrete locations to block each individual port 22, or a single member can wrap around the outer periphery of the tubular 18 to cover several ports 22, such as all the ports 22 within a particular section 24 of the tubular 18. The members 38 may be provided entirely or partially within each port 22, or radially exteriorly of the ports 22. The members 38 are configured to cover the peripheries of their associated ports 22.
The radially extendable member 38 is a foamed shape memory polymer (“SMP”) that can increase radially while surrounding the ports 22 of the tubular 18. The system 10 employs foamed shape memory polymer, such as, but not limited to, Morphic™ technology, a shape memory polymeric open-cell foam available from Baker Hughes, Inc., as a volumetric masking agent to limit the amount and quality of cement 34 delivered to certain areas within the borehole 12.
With reference to FIG. 1, the members 38 are initially provided in a compressed state on the outer diameter of the tubular 18. The members 38 are mounted on the outer diameter, or within the ports 22, in such a way that they surround, enclose, or fill at least the perimeter and area of the flow ports 22. The members 38 are engineered such that they will remain compacted during deployment of the system 10. FIG. 1 shows the system 10 with the members 38 in the compressed state while being run in the borehole 12. The members 38 will deploy to the uncompacted shape substantially surrounding/enclosing the flow ports 22 of the system 10 upon exposure to heat (such as that generated by curing cement 34, or by a chemical reaction between a material in or around the members 38 with a fluid circulated in front of the cement 34).
The introduction of cement 34 is shown in FIG. 2. The cement 34 is pumped in a downhole direction 40 through the tubular 18. At an end of the tubular 18 (not shown), after the cement 34 escapes the tubular 18, the cement 34 moves in an uphole direction 42 through the annular space 36 between the tubular 18 and the borehole wall 16. Radially extending the radially extendable member 38 after the cement 34 is pumped allows the cement 34 to be pumped through the annular clearance 44 between the wall 16 of the borehole 12 and the radially extendable member 38. After-which radially extending of the radially extendable member 38 displaces some more of the cement 34 as the radially extendable member 38 radially extends into contact with the wall 16. The members 38 will deploy to the un-compacted shape substantially surrounding/enclosing the flow ports 22 of the system 10 upon exposure to heat (such as that generated by curing cement 34). This is shown in FIG. 3, with the members 38 being deployed and displacing the green cement 34 (cement 34 that has not yet cured). The expanding foam of the members 38 will extend from the outer diameter of the tubular 18 out to the inner diameter of the borehole wall 16, and contact and conform to this wall 16, as shown in FIG. 4. The porosity and stiffness of the foam of the members 18 is engineered so that as the foam expands it displaces uncured cement 34 from the area into which it deploys. The displacement of the uncured cement 34 may be complete, or may include only enough liquid and particulate to severely degrade the quality of any cement 34 remaining in the area once cured. If necessary the cement may be retarded somewhat to align cure rate with foam deployment. The radially extendable member 38 establishes essentially a cement free pathway from the interior 46 of the tubular 18 through the ports 22 and through the radially extendable member 38 to the earth formation 14.
Once the cement 34 has at least substantially cured in the unmasked areas (the areas not containing the deployed members 38), the system 10 is activated to move sleeves 48 and expose the ports 22 through a series of ball drops. As shown in FIG. 5, after cement 34 has cured, fracturing operations can begin from the pressure activated toe-sleeve by pressuring up the system 10 to open the sleeve 48, and pumping an agent 50 that attacks the shape memory polymer foam in the area surrounding the outer diameter of the now-open pressure activated sleeve 48. FIG. 5 demonstrates one exemplary embodiment for opening the sleeve 48, which includes the landing of a plug, such as a ball 52, on a ball seat 54. Seating the ball 52 allows pressure built against the ball 52 to move the ball 52, ball seat 54 and attached sliding sleeve 48 in a downhole direction 40. Movement of the sliding sleeve 48 in the downhole direction 40 reveals the ports 22 and the deployed member 38, which are otherwise sealed from the interior 46 of the tubular 18 via seals 58, 60 that seal the sleeve 48 relative to the wall 20 of the tubular 18. That is, once the sliding sleeve 48 is moved, the interior 46 of the tubular 18 is fluidically connected to the ports 22 and deployed member 38. The sliding sleeve 48 may include ports (not shown) that are misaligned with ports 22 in the tubular 18 in a non-activated condition of the sleeve 48, and aligned with the ports 22 in the tubular 18 when the sliding sleeve 48 is moved into an open condition of the ports 22. Alternatively, the sliding sleeve 48 may be imperforate and moved completely away from the ports 22 in the tubular 18 to provide direct access between the interior 46 of the tubular 18 and the members 38. Foam removal agent 50 or solvent, such as but not limited to dimethylformamide and ethylene glycol monobutyl ether, may be pumped at the lead of each stage intended to undermine the strength of the member 38. Treating the members 38 with the agent 50 has the effect of maximizing the area available to flow for fracturing treatment and limiting tortuosity, while maintaining the integrity advantages of a cemented liner.
Once the cement 34 has cured and the member 38 removed, the result is a substantially cemented completion system 10 with a cement sheath that is absent or severely compromised in the areas adjacent to any of the flow ports 22 as a result of the foam deployment. Removal of the members 38 result in large sections of exposed formation 14 ideal for stimulation. As shown in FIG. 6, once the solvent 50 has degraded the member 38 in the area exposed by the displaced sleeve 48, pump rate can increase and the first fracture stage can be completed. The ports 22 can be divided up into one or more zones, with just a single one of the zones being illustrated herein and the sliding sleeves 48 prevent simultaneous pressuring up of all zones located along the system 10. Subsequent stages can be completed by dropping the appropriate ball size and landing the ball 52 while pumping more of the shape memory polymer foam attacking solvent 50, substantially increasing the area available to flow through the ports 22. The fracture treatment will follow, and the pattern will continue until all sleeves 48 are opened. In this manner all of the stages in the system 10 benefit from the large flow area unfettered by tortuous perforation tunnels or cement, yet most of the completion is cemented in place, maximizing wellbore integrity.
Removal of the member 38 allows fluidic communication between an interior 46 of the tubular 18 and the earth formation 14. This fluid communication allows treating of the formation 14. Such treatments include fracturing, pumping proppant and acid treating, for example. Additionally, the system 10 would allow for production of fluids, such as hydrocarbons, for example, from the formation 14. The system 10 enables the use of pre-formed ports 22 within the tubular 18, as opposed to perforating the tubular 18 with perforations while within the borehole 12.
While FIGS. 1-6 depict the downhole system 10 in conjunction with a ball-activated sleeve 48, it should be understood that the system is also usable with other types of frac sleeves 56, such as, but not limited to, pressure actuated sleeves, hydraulically actuated sleeves, electrically actuated sleeves, and sleeves operable by downhole tools such as wireline devices, shifting tools, and bottom hole assemblies. An exemplary sleeve 56 not actuated by a ball 52 is shown in FIG. 7 with the member 38 in a compressed condition. With the exception of the sleeve 56 being movable by a means other than the ball 52, the system 100 shown in FIG. 7 may be operated in a manner similar to the system 10 shown in FIGS. 1-6. Other arrangements for blocking the fluid communication between the interior 46 of the tubular 18 and the annular space 36, as well as alternate arrangements for zonal isolation are also within the scope of the arrangements and the sleeves 48, 56, and ball and ball seats 52, 54 are described for exemplary purposes.
While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited. Moreover, the use of the terms first, second, etc. do not denote any order or importance, but rather the terms first, second, etc. are used to distinguish one element from another. Furthermore, the use of the terms a, an, etc. do not denote a limitation of quantity, but rather denote the presence of at least one of the referenced item.
Patent Application
20150090448
