CA2486513C - Fracturing head with replaceable inserts for improved wear resistance and method of refurbishing same - Google Patents
Fracturing head with replaceable inserts for improved wear resistance and method of refurbishing same Download PDFInfo
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- CA2486513C CA2486513C CA002486513A CA2486513A CA2486513C CA 2486513 C CA2486513 C CA 2486513C CA 002486513 A CA002486513 A CA 002486513A CA 2486513 A CA2486513 A CA 2486513A CA 2486513 C CA2486513 C CA 2486513C
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- 238000000034 method Methods 0.000 title claims description 9
- 239000012530 fluid Substances 0.000 claims abstract description 58
- 238000007789 sealing Methods 0.000 claims abstract description 47
- 230000002401 inhibitory effect Effects 0.000 claims abstract description 13
- 229910000831 Steel Inorganic materials 0.000 claims description 13
- 230000000149 penetrating effect Effects 0.000 claims description 13
- 239000010959 steel Substances 0.000 claims description 13
- 238000004891 communication Methods 0.000 claims description 8
- 239000004215 Carbon black (E152) Substances 0.000 claims description 7
- 230000003628 erosive effect Effects 0.000 claims description 7
- 229930195733 hydrocarbon Natural products 0.000 claims description 7
- 150000002430 hydrocarbons Chemical class 0.000 claims description 7
- 229920001971 elastomer Polymers 0.000 claims description 3
- 229920002635 polyurethane Polymers 0.000 claims description 3
- 239000004814 polyurethane Substances 0.000 claims description 3
- 230000002035 prolonged effect Effects 0.000 abstract description 3
- 239000002002 slurry Substances 0.000 description 12
- 230000015572 biosynthetic process Effects 0.000 description 5
- 238000005755 formation reaction Methods 0.000 description 5
- 239000002184 metal Substances 0.000 description 4
- 239000000203 mixture Substances 0.000 description 3
- 239000004576 sand Substances 0.000 description 2
- 229920002449 FKM Polymers 0.000 description 1
- 229910001315 Tool steel Inorganic materials 0.000 description 1
- 238000005299 abrasion Methods 0.000 description 1
- 229910001570 bauxite Inorganic materials 0.000 description 1
- 238000005336 cracking Methods 0.000 description 1
- 230000003292 diminished effect Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 230000002093 peripheral effect Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 230000001681 protective effect Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 239000011347 resin Substances 0.000 description 1
- 229920005989 resin Polymers 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 230000004936 stimulating effect Effects 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000011144 upstream manufacturing Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/2607—Surface equipment specially adapted for fracturing operations
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Multiple-Way Valves (AREA)
- Earth Drilling (AREA)
Abstract
Fracturing heads with one or more replaceable wear-resistant inserts have annular sealing elements for inhibiting fracturing fluids from circulating between the inserts and a main body of the fracturing head. Worn inserts and degraded sealing elements are easily replaced to refurbish the fracturing head without replacing or rebuilding the main body. Service life of the main body is therefore significantly prolonged. In one embodiment, an entire flow path through the main body is lined with wear-resistant replaceable inserts to further prolong the service life of the main body.
Description
FRACTURING HEAD WITH REPLACEABLE INSERTS FOR
IMPROVED WEAR RESISTANCE AND METHOD OF
REFURBISHING SAME
TECHNICAL FIELD
The present invention relates in general to the fracturing of subterranean hydrocarbon formations and, in particular, to a wear-resistant fracturing head used to pump high pressure fluids and abrasive proppants into a well requiring stimulatian.
BACKGROUND OF THE INVENTION
Subterranean hydrocarbon formations are routinely stimulated to enhance their geological permeability. A well known technique for stimulating a hydrocarbon formation is to fracture the formation by pumping into the well highly pressurized fluids containing suspended proppants, such as sand, resin-coated sand, sintered bauxite or other such abrasive particles. A fracturing fluid containing proppants is also known as a "slurry."
As is well known in the art, a fracturing head (or "fray head") has ports to which high pressure conduits known as "fray lines" are connected. The fray lines conduct the highly pressurized slurry from high pressure pumps to the fracturing head. The fracturing head is typically secured to a wellhead valve. The fracturing head includes a main body with a central bore for conveying the slurry downwardly into the well. Due to the high fluid pressures, high transfer rates and the abrasive properties of the proppants in the slurry, components of the fracturing head that are exposed to the pressurized slurry DOCSOTT: 356994\1 erode or "wash", as such erosion is referred to by those familiar with well fracturing processes.
As is well known in the art, fracturing heads are expensive to manufacture because they are made from hardened tool steel (AISI 4140, for example). Attempts have therefore been made to provide hardened, wear-resistant inserts that can be replaced in order to extend the service life of a fracturing head. For example, published Canadian Patent Application No. 2,430,784 to McLeod et al., describes a fracturing head with a replaceable abrasion-resistant wear sleeve secured in the main bore in the body of the fracturing head. The fracturing head defines a generally Y-shaped flow path. At least two streams of fracturing slurry are pumped through respective side ports angled at approximately 45 degrees to the main bore. The two streams of slurry mix turbulently at a confluence of the side ports. The slurry then flows downstream through the main bore and into the well. The wear sleeve is positioned so that the respective streams of slurry are directed at the wear sleeve rather than at the body of the fracturing head which, being of a softer steel that that of the wear sleeve, is more prone to erosion. However, due to the location of the wear sleeve, the turbulent slurry impinges a top edge of the wear sleeve, which tapers to a feathered edge. The feathered edge of the wear sleeve thus has a tendency to erode. As the feathered top edge erodes, pressurized slurry flows between thE: wear sleeve and the body of the fracturing head, eroding the body of the fracturing head, causing damage.
Consequently, there exists a need for a fracturing head with improved wear resistance.
IMPROVED WEAR RESISTANCE AND METHOD OF
REFURBISHING SAME
TECHNICAL FIELD
The present invention relates in general to the fracturing of subterranean hydrocarbon formations and, in particular, to a wear-resistant fracturing head used to pump high pressure fluids and abrasive proppants into a well requiring stimulatian.
BACKGROUND OF THE INVENTION
Subterranean hydrocarbon formations are routinely stimulated to enhance their geological permeability. A well known technique for stimulating a hydrocarbon formation is to fracture the formation by pumping into the well highly pressurized fluids containing suspended proppants, such as sand, resin-coated sand, sintered bauxite or other such abrasive particles. A fracturing fluid containing proppants is also known as a "slurry."
As is well known in the art, a fracturing head (or "fray head") has ports to which high pressure conduits known as "fray lines" are connected. The fray lines conduct the highly pressurized slurry from high pressure pumps to the fracturing head. The fracturing head is typically secured to a wellhead valve. The fracturing head includes a main body with a central bore for conveying the slurry downwardly into the well. Due to the high fluid pressures, high transfer rates and the abrasive properties of the proppants in the slurry, components of the fracturing head that are exposed to the pressurized slurry DOCSOTT: 356994\1 erode or "wash", as such erosion is referred to by those familiar with well fracturing processes.
As is well known in the art, fracturing heads are expensive to manufacture because they are made from hardened tool steel (AISI 4140, for example). Attempts have therefore been made to provide hardened, wear-resistant inserts that can be replaced in order to extend the service life of a fracturing head. For example, published Canadian Patent Application No. 2,430,784 to McLeod et al., describes a fracturing head with a replaceable abrasion-resistant wear sleeve secured in the main bore in the body of the fracturing head. The fracturing head defines a generally Y-shaped flow path. At least two streams of fracturing slurry are pumped through respective side ports angled at approximately 45 degrees to the main bore. The two streams of slurry mix turbulently at a confluence of the side ports. The slurry then flows downstream through the main bore and into the well. The wear sleeve is positioned so that the respective streams of slurry are directed at the wear sleeve rather than at the body of the fracturing head which, being of a softer steel that that of the wear sleeve, is more prone to erosion. However, due to the location of the wear sleeve, the turbulent slurry impinges a top edge of the wear sleeve, which tapers to a feathered edge. The feathered edge of the wear sleeve thus has a tendency to erode. As the feathered top edge erodes, pressurized slurry flows between thE: wear sleeve and the body of the fracturing head, eroding the body of the fracturing head, causing damage.
Consequently, there exists a need for a fracturing head with improved wear resistance.
- 2 -DOCSOTT: 3569)4\i SUNINIARY OF THE INVENTION' It is therefore an object of the invention to provide a fracturing head with improved wear resistance.
In accordance with a first aspect of the invention, a fracturing head includes a main body having a side port for connection to a high pressure line that conducts high pressure fracturing fluids from a high pressure pump, the main body including a main bore in fluid communication with the side port for conveying the fracturing fluids through the fracturing head. The fracturing head further includes a replaceable wear-resistant insert secured within the main bore and an annular sealing element disposed around a top end of the insert for inhibiting the fracturing fluids from penetrating an annular gap between the insert and the main body.
In one embodiment, the fracturing head includes a plurality of annular sealing elements disposed between the insert and the main body for inhibiting the fracturing fluids from penetrating the annular gap between the insert and the main body.
In accordance with a second aspect of the invention, a fracturing head includes a T-shaped main body having a main bore that extends from a port in a top end of the main body through a bottom end of the main body; a pair of side ports having side port bores that communicate with the main bore; at least one replaceable wear resistant insert that is received the main bare; and at least one replaceable wear-resistant insert received in each of the side ports.
In one embodiment, the at least one replaceable wear-resistant insert that is received in the main bore
In accordance with a first aspect of the invention, a fracturing head includes a main body having a side port for connection to a high pressure line that conducts high pressure fracturing fluids from a high pressure pump, the main body including a main bore in fluid communication with the side port for conveying the fracturing fluids through the fracturing head. The fracturing head further includes a replaceable wear-resistant insert secured within the main bore and an annular sealing element disposed around a top end of the insert for inhibiting the fracturing fluids from penetrating an annular gap between the insert and the main body.
In one embodiment, the fracturing head includes a plurality of annular sealing elements disposed between the insert and the main body for inhibiting the fracturing fluids from penetrating the annular gap between the insert and the main body.
In accordance with a second aspect of the invention, a fracturing head includes a T-shaped main body having a main bore that extends from a port in a top end of the main body through a bottom end of the main body; a pair of side ports having side port bores that communicate with the main bore; at least one replaceable wear resistant insert that is received the main bare; and at least one replaceable wear-resistant insert received in each of the side ports.
In one embodiment, the at least one replaceable wear-resistant insert that is received in the main bore
- 3 -DOCSOTT: 356994\1 includes: a first replaceable wear-resistant insert received in the port in the top end of the main body; a second replaceable wear-resistant insert received in the main body beneath the first insert, the second insert including opposed circular seats for respectively receiving inner ends of the inserts received in the respective side ports; and a third replaceable wear-resistant insert that is received in a retainer flange connected to a bottom end of the main body.
In accordance with a third aspect of the invention, a fracturing head includes a main body having at least two angled side ports for connection to respective high pressure lines that conduct high pressure fracturing fluids from high pressure pumps, the main body including a main bore in fluid communication with the angled side ports for conveying the fracturing fluids through the fracturing head. The fracturing head also includes a replaceable wear-resistant insert secured in the main bore downstream of the side ports, the insert having an impingement surface against which substantially all of a jet of pressurized fracturing fluids directly impinges when pressurized fracturing fluids are pumped through one or more of the angled side ports, the impingement surface being between top and bottom ends of the wear resistant insert. The fracturing head further includes at least one annular sealing element disposed between a top end of the wear resistant insert and the main body for inhibiting the fracturing fluids from penetrating between the wear resistant insert and the main body.
In accordance with a fourth aspect of the invention, a method of refurbishing a fracturing head includes the steps of disassembling the fracturing head;
In accordance with a third aspect of the invention, a fracturing head includes a main body having at least two angled side ports for connection to respective high pressure lines that conduct high pressure fracturing fluids from high pressure pumps, the main body including a main bore in fluid communication with the angled side ports for conveying the fracturing fluids through the fracturing head. The fracturing head also includes a replaceable wear-resistant insert secured in the main bore downstream of the side ports, the insert having an impingement surface against which substantially all of a jet of pressurized fracturing fluids directly impinges when pressurized fracturing fluids are pumped through one or more of the angled side ports, the impingement surface being between top and bottom ends of the wear resistant insert. The fracturing head further includes at least one annular sealing element disposed between a top end of the wear resistant insert and the main body for inhibiting the fracturing fluids from penetrating between the wear resistant insert and the main body.
In accordance with a fourth aspect of the invention, a method of refurbishing a fracturing head includes the steps of disassembling the fracturing head;
- 4 -DOCSOTT: 356994\1 removing a worn replaceable insert from a bore of a main body of the fracturing head; removing, inspecting and replacing any worn annular sealing elements associated with the replaceable insert; inserting a new replaceable insert in the bore of the main body; and reassembling the fracturing head.
BRIEF DESCRIPTION OF THE DRAWINGS
Further features and advantages of the present invention will become apparent from the following detailed description, taken in combination with the appended drawings, in which:
FIG. 1 is a front elevation view of a T-shaped fracturing head in accordance with an embodiment of the invention;
FIG. 2 is an exploded view of the fracturing head shown in FIG. l;
FIG. 3 is a cross-sectional view of another T-shaped fracturing head in accordance with another embodiment of the invention; and FIG. 4 is a cross-sectTOnal view of a Y-shaped fracturing head in accordance with yet a further embodiment of the invention.
It will be noted that throughout the appended drawings, like features are identified by like reference numerals.
DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT
In general, and as will be explained in detail below, a fracturing head in accordance with the invention
BRIEF DESCRIPTION OF THE DRAWINGS
Further features and advantages of the present invention will become apparent from the following detailed description, taken in combination with the appended drawings, in which:
FIG. 1 is a front elevation view of a T-shaped fracturing head in accordance with an embodiment of the invention;
FIG. 2 is an exploded view of the fracturing head shown in FIG. l;
FIG. 3 is a cross-sectional view of another T-shaped fracturing head in accordance with another embodiment of the invention; and FIG. 4 is a cross-sectTOnal view of a Y-shaped fracturing head in accordance with yet a further embodiment of the invention.
It will be noted that throughout the appended drawings, like features are identified by like reference numerals.
DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT
In general, and as will be explained in detail below, a fracturing head in accordance with the invention
- 5 -vOCSOTT: 356994\1 includes one or more replaceable wear-resistant inserts and annular sealing elements for inhibiting fracturing fluids from circulating between the inserts and a main body of the fracturing head. Worn inserts and degraded sealing elements are easily replaced to refurbish the fracturing head without replacing or rebuilding the main body. Service life of the main body is therefore significantly prolonged.
As will be described below, in one embodiment, an entire flow path through the main body is lined with wear-resistant replaceable inserts to further prolong the service life of the main body.
As shown in FIGS. 1 and 2, a fracturing head 10 in accordance with an embodiment of the invention includes a T-shaped main body 12. The main body 12 Includes a top port 14 as well as a pair of opposed side ports 16 to which high-pressure lines (not shown) can be connected and through which pressurized fracturing fluids can then be pumped. As is known in the art, the fracturing fluids include a slurry of treatment fluids and abrasive proppants which the fracturing head 10 conducts down the well for fracturing subterranean hydrocarbon formations. The main body 12 can be secured to the top of a retainer flange 18 which in turn can be secured to a wellhead assembly (not shown) .
As shown in FIG. 2, the fracturing head 10 further includes one or more of a plurality of replaceable wear-resistant inserts and annular sealing elements collectively designated by reference numeral 20. The wear-resistant inserts (or "sleeves") and associated annular sealing elements can be secured within one or more bores in the fracturing head 10 in order to provide a wear-resistant flow-path lining that inhibits erosion of the main body 12
As will be described below, in one embodiment, an entire flow path through the main body is lined with wear-resistant replaceable inserts to further prolong the service life of the main body.
As shown in FIGS. 1 and 2, a fracturing head 10 in accordance with an embodiment of the invention includes a T-shaped main body 12. The main body 12 Includes a top port 14 as well as a pair of opposed side ports 16 to which high-pressure lines (not shown) can be connected and through which pressurized fracturing fluids can then be pumped. As is known in the art, the fracturing fluids include a slurry of treatment fluids and abrasive proppants which the fracturing head 10 conducts down the well for fracturing subterranean hydrocarbon formations. The main body 12 can be secured to the top of a retainer flange 18 which in turn can be secured to a wellhead assembly (not shown) .
As shown in FIG. 2, the fracturing head 10 further includes one or more of a plurality of replaceable wear-resistant inserts and annular sealing elements collectively designated by reference numeral 20. The wear-resistant inserts (or "sleeves") and associated annular sealing elements can be secured within one or more bores in the fracturing head 10 in order to provide a wear-resistant flow-path lining that inhibits erosion of the main body 12
- 6 -DOCSOTT: 356)94\1 and thus prolongs the service life of the fracturing head l0. The various inserts will now be described individually.
As shown in FIG. 2, a main insert 22 can be inserted into a main bore in the main body 12. The main insert 22 is a thick-walled sleeve having circular apertures at top and bottom ends. The main insert 22 further includes, in the cylindrical side wall, two opposed circular apertures each surrounded by an annular lip. The main insert can therefore receive respective side port inserts 26 as well as respective side gaskets 33. The side port inserts 26 are designed to be inserted into respective bores in the opposed side ports 16. Similarly, a top port insert 24 can be inserted into a bore in the top port 14.
Furthermore, a retainer flange insert 28 can be inserted into a bore in the retainer flange 18.
An upper annular sealing element 30 and a lower annular sealing element 32 provide fluid-tight seals above and below the main insert 22. The upper annular sealing element 30 is disposed around a top end of the main insert 22 to inhibit the fracturing fluids from penetrating an annular gap between the main insert 22 and the main body 12. The lower annular sealing element 32 is disposed directly beneath the main insert 22, i.e., where the main insert 22 abuts both the retainer flange 18 and a retainer flange insert 28. A pair of side gaskets 33 provide fluid-tight seals between the side port inserts and the main insert 22.
As will be readily appreciated by those of ordinary skill in the art, the fracturing head 10 may include only a single insert and a respective sealing element or it may include any combination of replaceable inserts and annular DOCS01'1': 356994\1 sealing elements. The inserts and annular sealing elements may be disposed contiguously to provide a protective lining over the entire flow path or merely over only a portion of the flow path.
FIG. 3 is a cross-sectional view of another T-shaped fracturing head 10 in accordance with another embodiment of the invention. The fracturing head 10 shown in FIG. 3 includes a T-shaped main body 12 having a main.
bore 13. The main body 12 also includes a top port 14 having a top bore 15 as well as a pair of opposed side ports 16 having respective side bores 17, all of which are in fluid communication with the main. bore 13. A retainer flange 18 is secured to the bottom of the main body 12.
The retainer flange 18 includes a retainer flange bore 19 which is also in fluid communication with the main bore.
The main bore 13, top bore 15, side bores 17 and retainer flange bore 19 together define a flow path through the fracturing head 10.
The side ports 16 and the top port 14 are threaded for the connection of high-pressure lines (not shown) for.
conducting high-pressure fracturing fluids from a high-pressure pump (not shown) into the well. It is common practice to connect high-pressure lines to two of the three ports for inflow of pressurized fracturing fluids into the fracturing head while the third port is closed with a valve and reserved for pressure alleviation in the event of "screenout". These highly pressurized fracturing fluids mix turbulently at the confluence of the side bores and top bore and then flow downwardly into the well through the main bore 13 and retainer flange bore 19.
As shown in FIG. 3, a main (replaceable wear-resistant) insert 22 is secured within the main bore 13 in _ g -DOCSOT1': 356994\d the main body 12. In this embodiment, the main insert 22 includes a nozzle with an internal taper used to direct a flow of fluid from the side ports (and/or top port) through a bottom of the fracturing head. Upper and lower main annular sealing elements 30, 32 are disposed along the upper and lower surfaces of the main insert 22 in order to inhibit penetration of abrasive fracturing fluids into an annular gap between the main insert 22 and the main body 12. Consequently, the susceptibility of the main body to erosion is diminished, thus prolonging the service life of the fracturing head.
In the embodiment illustrated in FIG. 3, the fracturing head also includes a second main bore insert 23 secured within the main bore 13 upstream of the first main bore insert 22. The second main bore insert and the first main bore insert 22 are separated by the upper annular sealing element 30.
As shown in FIG. 3, the side bores 17 of each side port 16 are also protectively lined with respective side port inserts 26. Similarly, the top bore 15 of the top port 14 includes first and second top port inserts 24, 25 separated by a top port annular sealing element 34. A pair of side port annular sealing elements 36 are disposed circumferentially around the side bores 17 at the abutment of the side port inserts 26 and the second top port insert 25 and the second main bore insert 23.
As shown in FIG. 3, the retainer flange 18 includes a retainer flange insert 28 within the retainer flange bore 19. The top of the retainer flange insert abuts the lower main annular sealing element 32.
_ g _ DOCSOTT: 35699411 As shown in FIG. 3, a pair of annular grooves 38 are machined into the bottom of the main body 12. Each of the annular grooves 38 receives an O-ring for providing a fluid-tight seal between the bottom of the main body 12 and the retainer flange 18. Further annular grooves 40 are machined into both the bottom of the main body 12 and the top of the retainer flange 18 for accommodating a metal ring gasket as described in applicant's co-pending Canadian Patent Application Serial Number 2,445,468 filed October 17, 2003 and entitled METAL RING GASKET FOR A
THREADED UNION.
The retainer flange 18 is secured to the bottom of the main body 12 of the fracturing head 10 using threaded fasteners (which are not shown). The retainer flange 18 includes an upper flange having a plurality of equidistantly spaced bores 42. The bores 42 in the upper flange align with corresponding tapped bores 44 in the bottom of the main body 12.
In one embodiment, the annular sealing elements are ring gaskets made of either a hydrocarbon rubber (such as Viton~ Nordel~ available from Dow Chemical) or a polyurethane.
In one embodiment, the main body 12 and the retainer flange 18 are machined from AISI 4140 heat-treated steel whereas the inserts are machined from a harder steel such as AISI 4340 steel having a Rockwell C Hardness of 48-56.
FIG. 4 is a cross-sectional view of a Y-shaped fracturing head in accordance with yet a further embodiment of the invention. In this embodiment, the fracturing head 10 includes two angled side ports 16 each having a UOCS01'T: 356994\l side bore 17 in fluid communication with a main bore 13.
In use, high-pressure lines are connected to the angled side ports 16 and/or to the top port 14 in the manner described above. High-pressure fracturing fluids are thus conducted at high velocity down the side bores and/or top bore. These fracturing fluids mix turbulently at the confluence of the maim bore, top bore and side bores and the fluids flow downwardly into the well through the main bore 13 and the retainer flange bore 19.
As shown in FIG. 4, a main replaceable wear-resistant insert 22 is secured in the main bore 13 downstream of the side ports 16. The main insert 22 has an impingement surface 50 against which substantially all of a jet of pressurized fracturing fluids directly impinges when pressurized fracturing fluids are pumped through one or more of the angled side ports 16. The impingement surface 50 is a portion of the exposed inner surface of the main insert that is spaced far enough beneath the top of the main insert that substantially none of the jet impinges on the interface between the top of the main insert and the main body. In other words, the main replaceable wear-resistant insert 22 is positioned within the main bore so that the fracturing fluids pumped through the angled side ports generally impinge only the impingement surface 50 spaced beneath the top surface of the insert and above a bottom surface of the insert.
As shown in FIG. 4, the fracturing head 10 may further include one or more annular grooves 38 that are machined into the main insert and/or the main body. These annular grooves 38 each accommodate an O-ring for providing a fluid-tight seal between the main insert 22 and the main body. The O-rings inhibit fracturing fluids from DOCSOTT: 356994\l penetrating between the main insert and the main body. As noted above, the seals inhibit erosion of the main body and thus prolong the service life of the fracturing head.
As shown in FIG. 4, the fracturing head 10 further includes an auxiliary replaceable wear-resistant insert 22a that is secured within the main bore 13 downstream of the main insert 22. The auxiliary insert 22a includes a top annular groove in which an O-ring is seated for providing a fluid-tight seal between the auxiliary insert 22a and the main insert 22. The auxiliary insert 22a also includes three peripheral annular graoves 38 in which O-rings are seated for providing a fluid-tight seal between the auxiliary insert 22a and the bottom of the main body 12.
In addition, the auxiliary insert 22a includes a bottom annular groove 40 (corresponding to an annular groove in the top of the retainer flange 18) in which a metal ring gasket can be seated to provide a fluid-tight seal between the top of the retainer flange and the bottom of the auxiliary insert.
As shown in FIG. 4, the auxiliary insert 22a is retained within the bore 13 by a retainer ring 48 which, in turn, is fastened to the bottom of the main body with threaded fasteners 46: As was noted above with respect to the previous embodiment, the retainer flange 18 is secured to the main body 12 using fasteners that are inserted through boreholes 42 and threaded into tapped boreholes 44.
As shown in FIG. 4, at the top of the fracturing head 10 is a stud pad 60 having tapped boreholes 62 as well as an annular groove in which a metal ring gasket can be seated. The stud pad 60 permits stacking of two or more fracturing heads.
DOCSO'rT: 35699411 In one embodiment, the main body 12, retainer flange 18, retainer ring 48 and auxiliary insert 22a are machined from AISI 4140 heat-treated steel. The main insert 22, against which the fracturing fluid impinges, is machined from a harder steel such as AISI 4340 steel having a Rockwell C Hardness of 48-56. The auxiliary insert is made of a softer, more elastic steel which compresses more readily than the 4340 steel of the main insert 22, and thus permits the retainer flange to be fastened tightly to the bottom of the main body without risk of cracking the brittle main insert 22.
The service life of the fracturing head can be prolonged by replacing worn inserts and/or worn annular sealing elements. To refurbish the fracturing head, the fracturing head is disassembled by detaching the main body from the retainer flange. The inserts and sealing elements can then be removed and inspected. Any worn inserts and/or sealing elements can then be replaced before the fracturing head is reassembled.
Persons of crdinary skill in the art will appreciate, in light of this specification, that minor variations may be made to the components of the fracturing head without departing from the sprit and scope of the invention. The embodiments of the invention described above are therefore intended to be exemplary only and the scope of the invention is limited only by the scope of the appended claims.
DOCSOTT: 35699411
As shown in FIG. 2, a main insert 22 can be inserted into a main bore in the main body 12. The main insert 22 is a thick-walled sleeve having circular apertures at top and bottom ends. The main insert 22 further includes, in the cylindrical side wall, two opposed circular apertures each surrounded by an annular lip. The main insert can therefore receive respective side port inserts 26 as well as respective side gaskets 33. The side port inserts 26 are designed to be inserted into respective bores in the opposed side ports 16. Similarly, a top port insert 24 can be inserted into a bore in the top port 14.
Furthermore, a retainer flange insert 28 can be inserted into a bore in the retainer flange 18.
An upper annular sealing element 30 and a lower annular sealing element 32 provide fluid-tight seals above and below the main insert 22. The upper annular sealing element 30 is disposed around a top end of the main insert 22 to inhibit the fracturing fluids from penetrating an annular gap between the main insert 22 and the main body 12. The lower annular sealing element 32 is disposed directly beneath the main insert 22, i.e., where the main insert 22 abuts both the retainer flange 18 and a retainer flange insert 28. A pair of side gaskets 33 provide fluid-tight seals between the side port inserts and the main insert 22.
As will be readily appreciated by those of ordinary skill in the art, the fracturing head 10 may include only a single insert and a respective sealing element or it may include any combination of replaceable inserts and annular DOCS01'1': 356994\1 sealing elements. The inserts and annular sealing elements may be disposed contiguously to provide a protective lining over the entire flow path or merely over only a portion of the flow path.
FIG. 3 is a cross-sectional view of another T-shaped fracturing head 10 in accordance with another embodiment of the invention. The fracturing head 10 shown in FIG. 3 includes a T-shaped main body 12 having a main.
bore 13. The main body 12 also includes a top port 14 having a top bore 15 as well as a pair of opposed side ports 16 having respective side bores 17, all of which are in fluid communication with the main. bore 13. A retainer flange 18 is secured to the bottom of the main body 12.
The retainer flange 18 includes a retainer flange bore 19 which is also in fluid communication with the main bore.
The main bore 13, top bore 15, side bores 17 and retainer flange bore 19 together define a flow path through the fracturing head 10.
The side ports 16 and the top port 14 are threaded for the connection of high-pressure lines (not shown) for.
conducting high-pressure fracturing fluids from a high-pressure pump (not shown) into the well. It is common practice to connect high-pressure lines to two of the three ports for inflow of pressurized fracturing fluids into the fracturing head while the third port is closed with a valve and reserved for pressure alleviation in the event of "screenout". These highly pressurized fracturing fluids mix turbulently at the confluence of the side bores and top bore and then flow downwardly into the well through the main bore 13 and retainer flange bore 19.
As shown in FIG. 3, a main (replaceable wear-resistant) insert 22 is secured within the main bore 13 in _ g -DOCSOT1': 356994\d the main body 12. In this embodiment, the main insert 22 includes a nozzle with an internal taper used to direct a flow of fluid from the side ports (and/or top port) through a bottom of the fracturing head. Upper and lower main annular sealing elements 30, 32 are disposed along the upper and lower surfaces of the main insert 22 in order to inhibit penetration of abrasive fracturing fluids into an annular gap between the main insert 22 and the main body 12. Consequently, the susceptibility of the main body to erosion is diminished, thus prolonging the service life of the fracturing head.
In the embodiment illustrated in FIG. 3, the fracturing head also includes a second main bore insert 23 secured within the main bore 13 upstream of the first main bore insert 22. The second main bore insert and the first main bore insert 22 are separated by the upper annular sealing element 30.
As shown in FIG. 3, the side bores 17 of each side port 16 are also protectively lined with respective side port inserts 26. Similarly, the top bore 15 of the top port 14 includes first and second top port inserts 24, 25 separated by a top port annular sealing element 34. A pair of side port annular sealing elements 36 are disposed circumferentially around the side bores 17 at the abutment of the side port inserts 26 and the second top port insert 25 and the second main bore insert 23.
As shown in FIG. 3, the retainer flange 18 includes a retainer flange insert 28 within the retainer flange bore 19. The top of the retainer flange insert abuts the lower main annular sealing element 32.
_ g _ DOCSOTT: 35699411 As shown in FIG. 3, a pair of annular grooves 38 are machined into the bottom of the main body 12. Each of the annular grooves 38 receives an O-ring for providing a fluid-tight seal between the bottom of the main body 12 and the retainer flange 18. Further annular grooves 40 are machined into both the bottom of the main body 12 and the top of the retainer flange 18 for accommodating a metal ring gasket as described in applicant's co-pending Canadian Patent Application Serial Number 2,445,468 filed October 17, 2003 and entitled METAL RING GASKET FOR A
THREADED UNION.
The retainer flange 18 is secured to the bottom of the main body 12 of the fracturing head 10 using threaded fasteners (which are not shown). The retainer flange 18 includes an upper flange having a plurality of equidistantly spaced bores 42. The bores 42 in the upper flange align with corresponding tapped bores 44 in the bottom of the main body 12.
In one embodiment, the annular sealing elements are ring gaskets made of either a hydrocarbon rubber (such as Viton~ Nordel~ available from Dow Chemical) or a polyurethane.
In one embodiment, the main body 12 and the retainer flange 18 are machined from AISI 4140 heat-treated steel whereas the inserts are machined from a harder steel such as AISI 4340 steel having a Rockwell C Hardness of 48-56.
FIG. 4 is a cross-sectional view of a Y-shaped fracturing head in accordance with yet a further embodiment of the invention. In this embodiment, the fracturing head 10 includes two angled side ports 16 each having a UOCS01'T: 356994\l side bore 17 in fluid communication with a main bore 13.
In use, high-pressure lines are connected to the angled side ports 16 and/or to the top port 14 in the manner described above. High-pressure fracturing fluids are thus conducted at high velocity down the side bores and/or top bore. These fracturing fluids mix turbulently at the confluence of the maim bore, top bore and side bores and the fluids flow downwardly into the well through the main bore 13 and the retainer flange bore 19.
As shown in FIG. 4, a main replaceable wear-resistant insert 22 is secured in the main bore 13 downstream of the side ports 16. The main insert 22 has an impingement surface 50 against which substantially all of a jet of pressurized fracturing fluids directly impinges when pressurized fracturing fluids are pumped through one or more of the angled side ports 16. The impingement surface 50 is a portion of the exposed inner surface of the main insert that is spaced far enough beneath the top of the main insert that substantially none of the jet impinges on the interface between the top of the main insert and the main body. In other words, the main replaceable wear-resistant insert 22 is positioned within the main bore so that the fracturing fluids pumped through the angled side ports generally impinge only the impingement surface 50 spaced beneath the top surface of the insert and above a bottom surface of the insert.
As shown in FIG. 4, the fracturing head 10 may further include one or more annular grooves 38 that are machined into the main insert and/or the main body. These annular grooves 38 each accommodate an O-ring for providing a fluid-tight seal between the main insert 22 and the main body. The O-rings inhibit fracturing fluids from DOCSOTT: 356994\l penetrating between the main insert and the main body. As noted above, the seals inhibit erosion of the main body and thus prolong the service life of the fracturing head.
As shown in FIG. 4, the fracturing head 10 further includes an auxiliary replaceable wear-resistant insert 22a that is secured within the main bore 13 downstream of the main insert 22. The auxiliary insert 22a includes a top annular groove in which an O-ring is seated for providing a fluid-tight seal between the auxiliary insert 22a and the main insert 22. The auxiliary insert 22a also includes three peripheral annular graoves 38 in which O-rings are seated for providing a fluid-tight seal between the auxiliary insert 22a and the bottom of the main body 12.
In addition, the auxiliary insert 22a includes a bottom annular groove 40 (corresponding to an annular groove in the top of the retainer flange 18) in which a metal ring gasket can be seated to provide a fluid-tight seal between the top of the retainer flange and the bottom of the auxiliary insert.
As shown in FIG. 4, the auxiliary insert 22a is retained within the bore 13 by a retainer ring 48 which, in turn, is fastened to the bottom of the main body with threaded fasteners 46: As was noted above with respect to the previous embodiment, the retainer flange 18 is secured to the main body 12 using fasteners that are inserted through boreholes 42 and threaded into tapped boreholes 44.
As shown in FIG. 4, at the top of the fracturing head 10 is a stud pad 60 having tapped boreholes 62 as well as an annular groove in which a metal ring gasket can be seated. The stud pad 60 permits stacking of two or more fracturing heads.
DOCSO'rT: 35699411 In one embodiment, the main body 12, retainer flange 18, retainer ring 48 and auxiliary insert 22a are machined from AISI 4140 heat-treated steel. The main insert 22, against which the fracturing fluid impinges, is machined from a harder steel such as AISI 4340 steel having a Rockwell C Hardness of 48-56. The auxiliary insert is made of a softer, more elastic steel which compresses more readily than the 4340 steel of the main insert 22, and thus permits the retainer flange to be fastened tightly to the bottom of the main body without risk of cracking the brittle main insert 22.
The service life of the fracturing head can be prolonged by replacing worn inserts and/or worn annular sealing elements. To refurbish the fracturing head, the fracturing head is disassembled by detaching the main body from the retainer flange. The inserts and sealing elements can then be removed and inspected. Any worn inserts and/or sealing elements can then be replaced before the fracturing head is reassembled.
Persons of crdinary skill in the art will appreciate, in light of this specification, that minor variations may be made to the components of the fracturing head without departing from the sprit and scope of the invention. The embodiments of the invention described above are therefore intended to be exemplary only and the scope of the invention is limited only by the scope of the appended claims.
DOCSOTT: 35699411
Claims (36)
PROPERTY OR PRIVILEGE IS CLAIMED ARE DEFINED AS FOLLOWS:
1. A fracturing head comprising:
a main body having a side port for connection to a high pressure line that conducts high pressure fracturing fluids from a high pressure pump, the main body including a main bore in fluid communication with the side port for conveying the fracturing fluids through the fracturing head;
a replaceable wear-resistant insert secured within the main bore; and an annular sealing element disposed around a top end of the insert for inhibiting the fracturing fluids from penetrating an annular gap between the insert and the main body.
a main body having a side port for connection to a high pressure line that conducts high pressure fracturing fluids from a high pressure pump, the main body including a main bore in fluid communication with the side port for conveying the fracturing fluids through the fracturing head;
a replaceable wear-resistant insert secured within the main bore; and an annular sealing element disposed around a top end of the insert for inhibiting the fracturing fluids from penetrating an annular gap between the insert and the main body.
2. The fracturing head as claimed in claim 1 further comprising a plurality of annular sealing elements disposed between the insert and the main body for inhibiting the fracturing fluids from penetrating the annular gap between the insert and the main body.
3. The fracturing head as claimed in claim 2 wherein the annular sealing elements comprise O-rings.
4. The fracturing head as claimed in any one of claims 1-3 further comprising a plurality of main bore inserts that are aligned to provide a main bore that is highly resistant to erosion.
5. The fracturing head as claimed in claim 4 further comprising an annular sealing element disposed between each pair of abutting ends of the plurality of inserts.
6. The fracturing head as claimed in claim 5 wherein each annular sealing element comprises a ring gasket.
7. The fracturing head as claimed in claim 6 wherein the ring gaskets comprise one of a hydrocarbon rubber and a polyurethane.
8. The fracturing head as claimed in claim 4 further comprising two opposed side ports, each side port including a replaceable wear-resistant side port insert, and an annular sealing element disposed between the side port insert and a one of the main bore inserts for inhibiting the fracturing fluids from penetrating between the one of the main bore inserts and the respective side port inserts.
9. The fracturing head as claimed in one of claims 1-8 further comprising a retainer connected to a bottom of the main body for retaining the insert within the main bore.
10. A fracturing head comprising:
a main body having at least two angled side ports for connection to respective high pressure lines that conduct high pressure fracturing fluids from high pressure pumps, the main body including a main bore in fluid communication with the angled side ports for conveying the fracturing fluids through the fracturing head;
a replaceable wear-resistant insert secured in the main bore downstream of the side ports, the insert having an impingement surface against which substantially all of a jet of pressurized fracturing fluids directly impinges when pressurized fracturing fluids are pumped through one or more of the angled side ports, the impingement surface being between top and bottom ends of the wear resistant insert; and at least one annular sealing element disposed between a top end of the wear resistant insert and the main body for inhibiting the fracturing fluids from penetrating between the wear resistant insert and the main body.
a main body having at least two angled side ports for connection to respective high pressure lines that conduct high pressure fracturing fluids from high pressure pumps, the main body including a main bore in fluid communication with the angled side ports for conveying the fracturing fluids through the fracturing head;
a replaceable wear-resistant insert secured in the main bore downstream of the side ports, the insert having an impingement surface against which substantially all of a jet of pressurized fracturing fluids directly impinges when pressurized fracturing fluids are pumped through one or more of the angled side ports, the impingement surface being between top and bottom ends of the wear resistant insert; and at least one annular sealing element disposed between a top end of the wear resistant insert and the main body for inhibiting the fracturing fluids from penetrating between the wear resistant insert and the main body.
11. The fracturing head as claimed in claim 10 further comprising a plurality of annular sealing elements disposed between the wear resistant insert and the main body.
12. The fracturing head as claimed in claim 11 wherein the annular sealing elements comprise O-rings.
13. The fracturing head as claimed in any one of claims 10-12 wherein the wear resistant insert comprises a nozzle having an internal taper used to direct a flow of fluid from the side ports through a bottom of the fracturing head.
14. The fracturing head as claimed in any one of claims 10-13 wherein the wear resistant insert is made of a steel having a Rockwell C Hardness of 48 to 56.
15. The fracturing head as claimed in any one of claims 10-14 further comprising a second insert secured in the main bore downstream of the wear resistant insert.
16. The fracturing head as claimed in claim 15 further comprising a second annular sealing element disposed between the second insert and the wear resistant insert to provide a fluid-tight seal between the second insert and the wear resistant insert.
17. The fracturing head as claimed in claim 16 further comprising an annular sealing element disposed between the second insert and the main body to provide a fluid-tight seal between the second insert and the main body.
18. The fracturing head as claimed in claims 16 or 17 wherein each of the second insert and the wear resistant insert are made of steel and the second insert is made of a softer steel than that of the wear resistant insert.
19. The fracturing head as claimed in claim 18 further comprising a retainer ring for retaining the wear resistant insert and the second insert in the bore.
20. A method of refurbishing a fracturing head, the method comprising the steps of:
disassembling the fracturing head;
removing a worn replaceable insert from a bore of a main body of the fracturing head;
removing, inspecting and replacing any worn annular sealing elements associated with the worn replaceable insert;
inserting a new replaceable insert in the bore of the main body to replace the worn replaceable insert;
and reassembling the fracturing head.
disassembling the fracturing head;
removing a worn replaceable insert from a bore of a main body of the fracturing head;
removing, inspecting and replacing any worn annular sealing elements associated with the worn replaceable insert;
inserting a new replaceable insert in the bore of the main body to replace the worn replaceable insert;
and reassembling the fracturing head.
21. The method as claimed in claim 20 wherein disassembling the fracturing head comprises:
removing threaded fasteners securing a retainer ring to the main body; and removing the retainer ring to permit the worn replaceable insert to be removed from the bore of the main body.
removing threaded fasteners securing a retainer ring to the main body; and removing the retainer ring to permit the worn replaceable insert to be removed from the bore of the main body.
22. The method as claimed in claim 20 wherein disassembling the fracturing head comprises:
removing threaded fasteners securing a retainer flange to the main body; and removing the retainer flange to permit a plurality of worn replaceable inserts to be removed from the bore of the main body.
removing threaded fasteners securing a retainer flange to the main body; and removing the retainer flange to permit a plurality of worn replaceable inserts to be removed from the bore of the main body.
23. A fracturing head comprising:
a main body having a replaceable wear-resistant insert secured within a main bore; and an annular sealing element disposed around a top end of the replaceable wear-resistant insert for inhibiting fracturing fluids pumped through the main bore from penetrating an annular gap between the replaceable wear-resistant insert and the main body.
a main body having a replaceable wear-resistant insert secured within a main bore; and an annular sealing element disposed around a top end of the replaceable wear-resistant insert for inhibiting fracturing fluids pumped through the main bore from penetrating an annular gap between the replaceable wear-resistant insert and the main body.
24. The fracturing head as claimed in claim 23 further comprising a plurality of annular sealing elements disposed between the replaceable wear-resistant insert and the main body for inhibiting the fracturing fluids from penetrating the annular gap between the insert and the main body.
25. The fracturing head as claimed in claim 24 wherein the annular sealing elements comprise O-rings.
26. The fracturing head as claimed in claim 25 further comprising a plurality of main bore inserts that are aligned to provide a main bore that is fully lined with replaceable wear-resistant inserts.
27. The fracturing head as claimed in claim 26 further comprising an annular sealing element disposed between each pair of abutting ends of the plurality of replaceable wear-resistant insert inserts.
28. The fracturing head as claimed in claim 27 wherein each annular sealing element comprises a ring gasket.
29. The fracturing head as claimed in claim 28 wherein the ring gaskets comprise one of a hydrocarbon rubber and a polyurethane.
30. The fracturing head as claimed in any one of claims 26-29 further comprising two opposed side ports, each side port including a replaceable wear-resistant side port insert, and an annular sealing element disposed between the respective side port inserts and a one of the main bore replaceable wear-resistant inserts for inhibiting the fracturing fluids from penetrating between the one of the main bore replaceable wear-resistant inserts and the respective side port inserts.
31. The fracturing head as claimed in any one of claims 23-30 further comprising a retainer connected to a bottom of the main body for retaining the replaceable wear-resistant insert within the main bore.
32. A fracturing head comprising:
a main body having a main bore in fluid communication with at least one angled side port for conveying fracturing fluids through the fracturing head;
a replaceable wear-resistant insert secured in the main bore downstream of the at least one side port, the insert having an impingement surface against which pressurized fracturing fluids impinge when pumped through one or more of the angled side ports; and at least one annular sealing element disposed between a top end of the wear resistant insert and the main body for inhibiting the fracturing fluids from penetrating between the wear resistant insert and the main body.
a main body having a main bore in fluid communication with at least one angled side port for conveying fracturing fluids through the fracturing head;
a replaceable wear-resistant insert secured in the main bore downstream of the at least one side port, the insert having an impingement surface against which pressurized fracturing fluids impinge when pumped through one or more of the angled side ports; and at least one annular sealing element disposed between a top end of the wear resistant insert and the main body for inhibiting the fracturing fluids from penetrating between the wear resistant insert and the main body.
33. The fracturing head as claimed in claim 32 further comprising a plurality of annular sealing elements disposed between the wear resistant insert and the main body.
34. The fracturing head as claimed in claim 33 wherein the annular sealing elements comprise O-rings.
35. The fracturing head as claimed in any one of claims 32-34 wherein the wear resistant insert comprises a nozzle having an internal taper used to direct a flow of fluid from the at least one side port through a bottom of the fracturing head.
36. The fracturing head as claimed in any one of claims 32-35 wherein the wear resistant insert is made of steel having a Rockwell C Hardness of 48 to 56.
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002601268A CA2601268C (en) | 2004-11-01 | 2004-11-01 | Fracturing head with replaceable inserts for improved wear resistance and method of refurbishing same |
| CA002486513A CA2486513C (en) | 2004-11-01 | 2004-11-01 | Fracturing head with replaceable inserts for improved wear resistance and method of refurbishing same |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002486513A CA2486513C (en) | 2004-11-01 | 2004-11-01 | Fracturing head with replaceable inserts for improved wear resistance and method of refurbishing same |
Related Child Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002601268A Division CA2601268C (en) | 2004-11-01 | 2004-11-01 | Fracturing head with replaceable inserts for improved wear resistance and method of refurbishing same |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2486513A1 CA2486513A1 (en) | 2006-05-01 |
| CA2486513C true CA2486513C (en) | 2008-07-15 |
Family
ID=36283103
Family Applications (2)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002601268A Active CA2601268C (en) | 2004-11-01 | 2004-11-01 | Fracturing head with replaceable inserts for improved wear resistance and method of refurbishing same |
| CA002486513A Active CA2486513C (en) | 2004-11-01 | 2004-11-01 | Fracturing head with replaceable inserts for improved wear resistance and method of refurbishing same |
Family Applications Before (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002601268A Active CA2601268C (en) | 2004-11-01 | 2004-11-01 | Fracturing head with replaceable inserts for improved wear resistance and method of refurbishing same |
Country Status (1)
| Country | Link |
|---|---|
| CA (2) | CA2601268C (en) |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7992635B2 (en) | 2006-08-08 | 2011-08-09 | Isolation Equipment Services Inc. | System and apparatus for sealing a fracturing head to a wellhead |
-
2004
- 2004-11-01 CA CA002601268A patent/CA2601268C/en active Active
- 2004-11-01 CA CA002486513A patent/CA2486513C/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CA2601268C (en) | 2009-10-13 |
| CA2486513A1 (en) | 2006-05-01 |
| CA2601268A1 (en) | 2006-05-01 |
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