US20100224374A1 - Apparatus and Method for Lubricating and Injecting Downhole Equipment Into a Wellbore - Google Patents
Apparatus and Method for Lubricating and Injecting Downhole Equipment Into a Wellbore Download PDFInfo
- Publication number
- US20100224374A1 US20100224374A1 US12/781,582 US78158210A US2010224374A1 US 20100224374 A1 US20100224374 A1 US 20100224374A1 US 78158210 A US78158210 A US 78158210A US 2010224374 A1 US2010224374 A1 US 2010224374A1
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- United States
- Prior art keywords
- packing gland
- hydraulic
- assembly
- spool
- blowout preventer
- Prior art date
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- Abandoned
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- 238000000034 method Methods 0.000 title claims abstract description 12
- 230000001050 lubricating effect Effects 0.000 title claims abstract description 7
- 238000002955 isolation Methods 0.000 claims abstract description 33
- 238000012856 packing Methods 0.000 claims description 54
- 210000004907 gland Anatomy 0.000 claims description 45
- 125000006850 spacer group Chemical group 0.000 claims description 22
- 230000003213 activating effect Effects 0.000 claims 1
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 230000000717 retained effect Effects 0.000 description 2
- 239000002253 acid Substances 0.000 description 1
- 238000009844 basic oxygen steelmaking Methods 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000010168 coupling process Methods 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 238000003780 insertion Methods 0.000 description 1
- 230000037431 insertion Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000012806 monitoring device Methods 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
- E21B19/22—Handling reeled pipe or rod units, e.g. flexible drilling pipes
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Definitions
- the present invention relates generally to the production of petroleum products from subterranean wells.
- the present invention more particularly relates to the assembly of downhole equipment before deployment into a subterranean well.
- Coiled tubing is often used to deploy downhole equipment.
- Coiled tubing can be defined as any continuously-milled tubular product manufactured in lengths that require spooling onto a take-up reel.
- coiled tubing is now used in other applications, including well unloading, fishing, tool conveyance, setting plus and retrieving plugs.
- the term “downhole tool” or “downhole assembly” refers generally to the downhole equipment that is deployed and used in a subterranean well. Electrical submersible pumps, fishing tools and monitoring devices are common examples of downhole equipment.
- Coiled tubing units typically include an injector head that is suspended above the wellhead by a crane or derrick.
- the injector head provides the surface drive force to run and retrieve the coiled tubing from the well.
- the injector head is often used in conjunction with a stripper and a blowout preventer.
- the stripper is typically located between the injector head and the blowout preventer and provides the primary operational seal between pressurized wellbore fluids and the surface environment.
- the blowout preventer may include one or more rams that perform various functions, including supporting the hanging coiled tubing, sealing around the coiled tubing and shearing the coiled tubing.
- One of the drawbacks of using coiled tubing in conjunction with downhole equipment is the process used to connect the downhole equipment to the coiled tubing before lowering the downhole equipment into the well.
- a conventional lubricator was used to load tools before running the tools into the live well.
- the lubricator is a long, high-pressure pipe that is fitted between the top of a wellhead and the bottom of the injector head.
- the tools are assembled inside the lubricator and connected to the coiled tubing.
- the lubricator is then pressurized to wellbore pressure and the assembled tools are deployed through the wellhead in the well.
- An objective of the present invention is to provide an improved apparatus and method for lubricating and infecting downhole equipment into a wellbore.
- the present invention includes an apparatus comprising a spool for enclosing the downhole equipment.
- the apparatus further comprises a pressure isolation window positioned above the spool.
- the pressure isolation window preferably includes a lower packing gland to retain the pressure in the spool and an upper packing gland to retain the pressure in a hydraulic cylinder.
- the apparatus further comprises a hydraulic cylinder positioned above the pressure isolation window, and a rod connected to the downhole equipment. The hydraulic cylinder lowers the downhole equipment into the wellbore.
- the pressure invention allows downhole equipment to be substantially lowered into the wellbore, and allows the spool to be removed before a coiled tubing injector is attached to the well.
- the use of the present invention obviates the need for a conventional lubricator under the coiled tubing injector head.
- the injector head can be operated much closer to the ground with smaller equipment and with reduced risk to person and property.
- FIG. 1 is a side cross-sectional elevational view of a preferred embodiment of the present invention.
- FIG. 2 is a side cross-sectional elevational view of the pressure isolation window of a preferred embodiment of the present invention.
- FIG. 1 shows a hydraulic lubricator assembly apparatus 100 constructed in accordance with a preferred embodiment of the invention.
- the apparatus 100 preferably includes a hydraulic cylinder 102 , a pressure isolation window 104 , a spool 106 , and a blowout preventer 108 .
- the blowout preventer 108 is connected to the top of a wellhead 110 .
- the apparatus 100 is mounted on a truck (not shown) having a derrick or mast sufficient to suspend the apparatus 100 over the wellhead 110 . It will be understood, however, that the apparatus 100 can alternatively be used in offshore applications and mounted on a boat or barge.
- the blowout preventer 108 is preferably a standard blowout preventer used in coiled tubing operations and should be selected based on the particular requirements of specific applications.
- the blowout preventer 108 preferably includes a pair of internal rams 112 .
- the blowout preventer may also include one or more pairs of shear rams or blind rams.
- the blowout preventer may also be attached to other BOPs.
- the apparatus 100 is used to lower downhole equipment 138 into the wellbore.
- the downhole equipment 138 may be a single component, or alternatively made up of multiple components 138 a , 138 b , 138 c and 138 d that connect together to form the downhole equipment 138 . It will be understood that the downhole equipment 138 may be made up of fewer components or more components than are shown in FIG. 1 .
- the spool 106 may be comprised of one or more spool segments 106 a , 106 b , and 106 c .
- the spool 106 is designed to contain the downhole equipment 138 prior to the insertion of the downhole equipment 138 into the wellbore.
- the number of spool segments depends on the length of the downhole equipment 138 .
- Each spool segment 106 a , 106 b , and 106 c is preferably a 3 ′′ diameter, high-pressure spacer spool.
- the spool 106 is 30 feet in length, and the spool segments are installed in series.
- the hydraulic cylinder 102 preferably includes a cylinder 114 having a bore 116 , a rod 118 and pressure couplings 120 .
- the hydraulic cylinder 102 is preferably connected to a hydraulic power pack or hydraulic pump (not shown) and, unless otherwise specified, is structurally and functionally similar to conventional hydraulic rams.
- a dedicated diesel engine is used to drive the hydraulic power pack or hydraulic pump.
- the rod 118 is preferably constructed in modular rod segments such that additional lengths can be added or removed as needed as spool segments are added and removed, as discussed below.
- the top of rod segment 118 b is configured for threaded engagement with the bottom of rod segment 118 a .
- the top of rod segment 118 c is preferably configured for threaded engagement with the bottom of rod segment 118 b . It will be understood that additional, or fewer, rod segments may be used.
- the apparatus 100 also includes a connector sub 136 that serves as a joint between the distal end of the rod 118 and the connected downhole equipment 138 .
- the connector sub 136 is configured as a “pup-joint” with opposing ends capable of being secured to the downhole equipment 138 and the hydraulic rod 118 . The functionality of the connector sub 136 is discussed below.
- the pressure isolation window 104 includes a base 122 , a top 124 and a series of support posts 126 .
- the base 122 of the pressure isolation window 104 can be connected to the top of the first spool segment 106 a .
- the top 124 of the pressure isolation window 104 is preferably connected to the cylinder 114 of the hydraulic cylinder 102 .
- the pressure isolation window 104 is rigidly fixed to the hydraulic cylinder 102 for ease of transportation.
- the pressure isolation window 104 also preferably includes a lower packing gland 127 and an upper packing gland 129 .
- the lower packing gland 127 is configured to seal around the rod 118 to retain the pressure inside the spool 106 .
- the base 122 of the pressure isolation window 104 is configured to be secured to the top spool segment 106 a through the use of a plurality of fastening devices (not shown).
- the lower packing gland 127 includes a packing gland body 128 , a packing gland nut 134 , V-packing 135 , an upper packing gland pusher 136 , and a lower packing gland pusher 137 .
- the packing gland body 128 is preferably retained within the base 122 and includes a ring seal 132 adapted to provide a suitable seal between the pressure isolation window 104 and the top spool segment 106 a .
- the ring seal 132 is constructed from a material that exhibits some degree of elasticity.
- the packing gland nut 134 engages the packing glad body 128 to improve the seal about rod 118 .
- Packing gland pushers 136 and 137 exert force on the V-packing 135 to tighten the seal around rod 118 .
- the upper packing gland 129 is configured to seal around the rod 118 to retain the pressure within the hydraulic cylinder 114 .
- the upper packing glad 129 preferably uses a packing gland body 130 , a packing gland nut 134 , V-packing 135 , an upper packing gland pusher 136 , and a lower packing glad pusher 137 to seal around rod 118 .
- the pressure isolation window 104 isolates the pressure in the hydraulic cylinder 114 from the pressure in the spacer spools 106 .
- the pressure isolation window 104 is preferably sized and configured to permit the introduction of a counter wheel or digital encoder (not shown) that can track the progression of the rod 118 in and out of the hydraulic cylinder 114 .
- the apparatus 100 is used to assemble and load the downhole equipment 138 before the downhole equipment 138 is connected to coiled tubing and deployed in the well.
- the use of the apparatus 100 obviates the need for a conventional lubricator under the coiled tubing injector head.
- the injector head can thereby be operated much closer to the ground with smaller equipment and with reduced risk to person and property.
- the blowout preventer 108 is bolted to the top of the wellhead 110 .
- the downhole equipment 138 is assembled and placed inside the requisite spool 106 .
- the connector sub 136 is attached to the top of the downhole equipment 138 and the bottom of the hydraulic rod 118 .
- the hydraulic rod 118 is first connected to the connector sub 136 , which in turn, is connected to the top component 138 a within the downhole equipment 138 .
- the next component 138 b of the downhole equipment 138 is then connected to the top component 138 a .
- the downhole equipment 138 is placed in the first spool segment 106 a , and the spool segment 106 a is secured to the base 122 of the pressure isolation window 104 .
- the spacer spool 106 can be secured between the blowout preventer 108 and the pressure isolation window 104 .
- the spacer spool 106 is pressurized to wellbore pressure.
- the spacer spool 106 is pressurized using a suitable compressed gas or fluid (e.g., methanol) stored on the truck.
- the spacer spool 106 can be pressurized with a bypass line connected directly to the wellbore.
- the operator moves the master valve on the wellhead to full open.
- the hydraulic assembly 102 is then activated to push the downhole equipment 138 through the blowout preventer 108 and the wellhead 110 into the well.
- the internal rams 112 are closed to lock the downhole equipment 138 in place.
- the travel of the hydraulic rod 118 required to move the connector sub 136 through the blowout preventer 108 is measured, preferably with the counter wheel or digital encoder, and recorded.
- the pressure in the spacer spool 106 is released and the spacer spool segments 106 a - c are disconnected from the blowout preventer 108 .
- the rod 118 is then disconnected from the connector sub 136 , and the depressurized spacer spool segments 106 a - c, pressure isolation window 104 and hydraulic assembly 102 are moved out of the way or rigged-down.
- the wellbore pressure is retained by the blowout preventer 108 , and the downhole equipment 138 is suspended from the connector sub 136 .
- the connector sub 136 is captured by the internal rams 112 of the blowout preventer 108 with the top portion of the connector sub 136 extending above the top of the blowout preventer 108 .
- Coiled tubing (not shown) is then attached to the exposed end of the connector sub 136 and to a coiled tubing injector head (not shown). Any intervening components, such as additional blowout preventers (not shown), are attached to the top of the blowout preventer 108 . Once the intervening components are brought to wellbore pressure, the internal rams 112 are opened and the coiled tubing injector head deploys the downhole equipment 138 into the well. At the end of the coiled tubing operation, the coiled tubing is retracted until the connector sub 136 is properly positioned adjacent the internal rams 112 of the blowout preventer 108 .
- the internal rams 112 are closed around the connector sub 136 , and the injector head and any intervening components can be removed from the well site.
- the spacer spool 106 , hydraulic assembly 102 and pressure isolation window 104 are then installed and pressurized so that the downhole equipment 138 can be retracted into the spacer spool 106 for disassembly.
- the preferred embodiment provides for a hydraulically powered lubricator that can be advantageously used to load downhole equipment in a well in a separate operation before connecting coiled tubing and a coiled tubing injector head.
- the apparatus and method of the preferred embodiment provide an efficient and safe alternative to conventional lubricators used in combination with coiled tubing systems.
Abstract
An apparatus and method for lubricating and injecting downhole equipment into a wellbore includes a blowout preventer, a spool for enclosing the downhole equipment, a pressure isolation window, and a hydraulic cylinder. The blowout preventer is positioned above a wellhead. The spool is positioned above the blowout preventer. The pressure isolation window is positioned above the spool. The hydraulic cylinder is positioned above the pressure isolation window. The hydraulic cylinder comprises a rod connected to the downhole equipment, and the hydraulic cylinder is used to lower the downhole equipment into the wellbore.
Description
- This application is a continuation of U.S. Ser. No. 11/731,639, filed Mar. 30, 2007, which claims the benefit of U.S. Provisional Application No. 60/787,264, filed Mar. 30, 2006, both of which are incorporated herein by reference in their entirety.
- 1. Field of the Invention
- The present invention relates generally to the production of petroleum products from subterranean wells. The present invention more particularly relates to the assembly of downhole equipment before deployment into a subterranean well.
- 2. Description of Related Art
- Coiled tubing is often used to deploy downhole equipment. Coiled tubing can be defined as any continuously-milled tubular product manufactured in lengths that require spooling onto a take-up reel. Although initially used primarily for well cleanout and acid stimulation applications, coiled tubing is now used in other applications, including well unloading, fishing, tool conveyance, setting plus and retrieving plugs. The term “downhole tool” or “downhole assembly” refers generally to the downhole equipment that is deployed and used in a subterranean well. Electrical submersible pumps, fishing tools and monitoring devices are common examples of downhole equipment.
- Coiled tubing units typically include an injector head that is suspended above the wellhead by a crane or derrick. The injector head provides the surface drive force to run and retrieve the coiled tubing from the well. The injector head is often used in conjunction with a stripper and a blowout preventer. The stripper is typically located between the injector head and the blowout preventer and provides the primary operational seal between pressurized wellbore fluids and the surface environment. The blowout preventer may include one or more rams that perform various functions, including supporting the hanging coiled tubing, sealing around the coiled tubing and shearing the coiled tubing.
- One of the drawbacks of using coiled tubing in conjunction with downhole equipment is the process used to connect the downhole equipment to the coiled tubing before lowering the downhole equipment into the well. In the past, a conventional lubricator was used to load tools before running the tools into the live well. The lubricator is a long, high-pressure pipe that is fitted between the top of a wellhead and the bottom of the injector head. The tools are assembled inside the lubricator and connected to the coiled tubing. The lubricator is then pressurized to wellbore pressure and the assembled tools are deployed through the wellhead in the well.
- While generally effective, the prior art method of lubricating tools into the well suffers significant drawbacks. Most significantly, the use of a lubricator raises the injector head high above the wellbore for the duration of the coiled tubing operation. This requires the use of large cranes or derricks that decrease the cost effectiveness and efficiency of the coiled tubing deployment. Many well sites are too remote or too small to support the use of large cranes or derricks. Furthermore, elevated injector heads are unstable in high winds and pose an increased rick to operators and equipment.
- In light of the shortcomings of the existing art, there is a need for an improved apparatus and method for lubricating and injecting downhole equipment into a wellbore. The present invention is directed to these and other deficiencies in the prior art.
- An objective of the present invention is to provide an improved apparatus and method for lubricating and infecting downhole equipment into a wellbore.
- In order to achieve the above-mentioned objective, the present invention includes an apparatus comprising a spool for enclosing the downhole equipment. The apparatus further comprises a pressure isolation window positioned above the spool. The pressure isolation window preferably includes a lower packing gland to retain the pressure in the spool and an upper packing gland to retain the pressure in a hydraulic cylinder. The apparatus further comprises a hydraulic cylinder positioned above the pressure isolation window, and a rod connected to the downhole equipment. The hydraulic cylinder lowers the downhole equipment into the wellbore.
- The pressure invention allows downhole equipment to be substantially lowered into the wellbore, and allows the spool to be removed before a coiled tubing injector is attached to the well. Thus, the use of the present invention obviates the need for a conventional lubricator under the coiled tubing injector head. As such, the injector head can be operated much closer to the ground with smaller equipment and with reduced risk to person and property.
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FIG. 1 is a side cross-sectional elevational view of a preferred embodiment of the present invention. -
FIG. 2 is a side cross-sectional elevational view of the pressure isolation window of a preferred embodiment of the present invention. - The apparatus and method for lubricating and injecting downhole equipment into a wellbore is described below in accordance with the present invention and with reference to the drawings.
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FIG. 1 shows a hydrauliclubricator assembly apparatus 100 constructed in accordance with a preferred embodiment of the invention. Theapparatus 100 preferably includes ahydraulic cylinder 102, apressure isolation window 104, aspool 106, and ablowout preventer 108. Theblowout preventer 108 is connected to the top of awellhead 110. In the preferred embodiment, theapparatus 100 is mounted on a truck (not shown) having a derrick or mast sufficient to suspend theapparatus 100 over thewellhead 110. It will be understood, however, that theapparatus 100 can alternatively be used in offshore applications and mounted on a boat or barge. - The
blowout preventer 108 is preferably a standard blowout preventer used in coiled tubing operations and should be selected based on the particular requirements of specific applications. Theblowout preventer 108 preferably includes a pair ofinternal rams 112. The blowout preventer may also include one or more pairs of shear rams or blind rams. The blowout preventer may also be attached to other BOPs. - The
apparatus 100 is used to lowerdownhole equipment 138 into the wellbore. Thedownhole equipment 138 may be a single component, or alternatively made up ofmultiple components downhole equipment 138. It will be understood that thedownhole equipment 138 may be made up of fewer components or more components than are shown inFIG. 1 . - The
spool 106 may be comprised of one ormore spool segments spool 106 is designed to contain thedownhole equipment 138 prior to the insertion of thedownhole equipment 138 into the wellbore. The number of spool segments depends on the length of thedownhole equipment 138. Eachspool segment spool 106 is 30 feet in length, and the spool segments are installed in series. - The
hydraulic cylinder 102 preferably includes acylinder 114 having abore 116, arod 118 andpressure couplings 120. Thehydraulic cylinder 102 is preferably connected to a hydraulic power pack or hydraulic pump (not shown) and, unless otherwise specified, is structurally and functionally similar to conventional hydraulic rams. - In the preferred truck-mounted embodiment, a dedicated diesel engine is used to drive the hydraulic power pack or hydraulic pump. The
rod 118 is preferably constructed in modular rod segments such that additional lengths can be added or removed as needed as spool segments are added and removed, as discussed below. In a particularly preferred embodiment, the top ofrod segment 118 b is configured for threaded engagement with the bottom ofrod segment 118 a. Similarly, the top ofrod segment 118 c is preferably configured for threaded engagement with the bottom ofrod segment 118 b. It will be understood that additional, or fewer, rod segments may be used. - The
apparatus 100 also includes aconnector sub 136 that serves as a joint between the distal end of therod 118 and the connecteddownhole equipment 138. In a presently preferred embodiment, theconnector sub 136 is configured as a “pup-joint” with opposing ends capable of being secured to thedownhole equipment 138 and thehydraulic rod 118. The functionality of theconnector sub 136 is discussed below. - As shown in greater detail in
FIG. 2 , thepressure isolation window 104 includes abase 122, a top 124 and a series of support posts 126. Thebase 122 of thepressure isolation window 104 can be connected to the top of thefirst spool segment 106 a. The top 124 of thepressure isolation window 104 is preferably connected to thecylinder 114 of thehydraulic cylinder 102. In a particularly preferred embodiment, thepressure isolation window 104 is rigidly fixed to thehydraulic cylinder 102 for ease of transportation. - The
pressure isolation window 104 also preferably includes alower packing gland 127 and anupper packing gland 129. Thelower packing gland 127 is configured to seal around therod 118 to retain the pressure inside thespool 106. Thebase 122 of thepressure isolation window 104 is configured to be secured to thetop spool segment 106 a through the use of a plurality of fastening devices (not shown). Thelower packing gland 127 includes apacking gland body 128, apacking gland nut 134, V-packing 135, an upperpacking gland pusher 136, and a lowerpacking gland pusher 137. - The
packing gland body 128 is preferably retained within thebase 122 and includes aring seal 132 adapted to provide a suitable seal between thepressure isolation window 104 and thetop spool segment 106 a. In a particularly preferred embodiment, thering seal 132 is constructed from a material that exhibits some degree of elasticity. The packinggland nut 134 engages the packingglad body 128 to improve the seal aboutrod 118.Packing gland pushers rod 118. - Similarly, the
upper packing gland 129 is configured to seal around therod 118 to retain the pressure within thehydraulic cylinder 114. Like thelower packing gland 127, the upper packing glad 129 preferably uses apacking gland body 130, apacking gland nut 134, V-packing 135, an upperpacking gland pusher 136, and a lower packingglad pusher 137 to seal aroundrod 118. In this way, thepressure isolation window 104 isolates the pressure in thehydraulic cylinder 114 from the pressure in the spacer spools 106. Thepressure isolation window 104 is preferably sized and configured to permit the introduction of a counter wheel or digital encoder (not shown) that can track the progression of therod 118 in and out of thehydraulic cylinder 114. - In a preferred embodiment, the
apparatus 100 is used to assemble and load thedownhole equipment 138 before thedownhole equipment 138 is connected to coiled tubing and deployed in the well. The use of theapparatus 100 obviates the need for a conventional lubricator under the coiled tubing injector head. The injector head can thereby be operated much closer to the ground with smaller equipment and with reduced risk to person and property. - In a preferred rig-up procedure, the
blowout preventer 108 is bolted to the top of thewellhead 110. Next, thedownhole equipment 138 is assembled and placed inside therequisite spool 106. Once thedownhole equipment 138 is completely assembled, theconnector sub 136 is attached to the top of thedownhole equipment 138 and the bottom of thehydraulic rod 118. - In an alternate preferred embodiment, the
hydraulic rod 118 is first connected to theconnector sub 136, which in turn, is connected to thetop component 138 a within thedownhole equipment 138. Thenext component 138 b of thedownhole equipment 138 is then connected to thetop component 138 a. Once the length of thedownhole equipment 138 is greater than the length of thefirst spool segment 106 a, thedownhole equipment 138 is placed in thefirst spool segment 106 a, and thespool segment 106 a is secured to thebase 122 of thepressure isolation window 104. In this fashion, additionalspacer spool segments spacer spool segment 106 a as the length of thedownhole equipment 138 increases. To facilitate assembly, therod 118 can be extended and retracted to provide easier access to thedownhole equipment 138. - Once the
downhole equipment 138 has been completely assembled, thespacer spool 106 can be secured between theblowout preventer 108 and thepressure isolation window 104. Next, thespacer spool 106 is pressurized to wellbore pressure. In a first preferred embodiment, thespacer spool 106 is pressurized using a suitable compressed gas or fluid (e.g., methanol) stored on the truck. Alternatively, thespacer spool 106 can be pressurized with a bypass line connected directly to the wellbore. - When the pressure inside the
spacer spool 106 is balanced with the wellbore pressure, the operator moves the master valve on the wellhead to full open. Thehydraulic assembly 102 is then activated to push thedownhole equipment 138 through theblowout preventer 108 and thewellhead 110 into the well. Once theconnector sub 136 reaches theblowout preventer 108, theinternal rams 112 are closed to lock thedownhole equipment 138 in place. The travel of thehydraulic rod 118 required to move theconnector sub 136 through theblowout preventer 108 is measured, preferably with the counter wheel or digital encoder, and recorded. - Next, the pressure in the
spacer spool 106 is released and thespacer spool segments 106 a-c are disconnected from theblowout preventer 108. Therod 118 is then disconnected from theconnector sub 136, and the depressurizedspacer spool segments 106 a-c,pressure isolation window 104 andhydraulic assembly 102 are moved out of the way or rigged-down. At this point in the operation, the wellbore pressure is retained by theblowout preventer 108, and thedownhole equipment 138 is suspended from theconnector sub 136. Theconnector sub 136 is captured by theinternal rams 112 of theblowout preventer 108 with the top portion of theconnector sub 136 extending above the top of theblowout preventer 108. - Coiled tubing (not shown) is then attached to the exposed end of the
connector sub 136 and to a coiled tubing injector head (not shown). Any intervening components, such as additional blowout preventers (not shown), are attached to the top of theblowout preventer 108. Once the intervening components are brought to wellbore pressure, theinternal rams 112 are opened and the coiled tubing injector head deploys thedownhole equipment 138 into the well. At the end of the coiled tubing operation, the coiled tubing is retracted until theconnector sub 136 is properly positioned adjacent theinternal rams 112 of theblowout preventer 108. Theinternal rams 112 are closed around theconnector sub 136, and the injector head and any intervening components can be removed from the well site. Thespacer spool 106,hydraulic assembly 102 andpressure isolation window 104 are then installed and pressurized so that thedownhole equipment 138 can be retracted into thespacer spool 106 for disassembly. - Thus, the preferred embodiment provides for a hydraulically powered lubricator that can be advantageously used to load downhole equipment in a well in a separate operation before connecting coiled tubing and a coiled tubing injector head. The apparatus and method of the preferred embodiment provide an efficient and safe alternative to conventional lubricators used in combination with coiled tubing systems.
- It is clear that the present invention is well adapted to carry out is objectives and attain the ends and advantages mentioned above as well as those inherent therein. While presently preferred embodiments of the invention have been described in varying detail for purposes of disclosure, it will be understood that numerous changes may be made which will readily suggest themselves to those skilled in the art and which are encompassed within the spirit of the invention disclosed herein and in the associated drawings. For example, the
hydraulic assembly 102,pressure isolation window 104 andblowout preventer 108 can be cooperatively used for fishing operations that require substantial “push-and-pull” forces.
Claims (16)
1. A hydraulic lubricator assembly for use in inserting a downhole tool into a wellbore, the hydraulic lubricator assembly comprising:
a spool for enclosing the downhole tool, the spool having an upper end and a lower end;
a pressure isolation connector attached to the upper end of the spool, the pressure isolation connector having a lower packing gland and an upper packing gland;
a blowout preventer connected to the lower end of the spool, the blowout preventer having internal rams; and
a hydraulic assembly positioned above the pressure isolation connector, the hydraulic assembly including a rod connected to the downhole tool, the hydraulic assembly configured to lower the downhole tool into the blowout preventer so that the internal rams may be used to suspend the downhole tool in the wellbore.
2. The hydraulic lubricator assembly of claim 1 , wherein the spool comprises a plurality of spool segments.
3. The hydraulic lubricator assembly of claim 1 , wherein the pressure isolation connector comprises a base, a top, and a support.
4. The hydraulic lubricator assembly of claim 1 , wherein the lower packing gland comprises a packing gland body, a packing gland nut that engages the packing gland body, V-packing, and a packing gland pusher.
5. The hydraulic lubricator assembly of claim 1 , wherein the upper packing gland comprises a packing gland body, a packing gland nut that engages the packing gland body, V-packing, and a packing gland pusher.
6. The hydraulic lubricator assembly of claim 1 , wherein the lower packing gland comprises a ring seal.
7. The hydraulic lubricator assembly of claim 1 , wherein the rod is connected to the downhole assembly via a connector sub.
8. The hydraulic lubricator assembly of claim 1 , wherein the rod comprises modular rod segments.
9. A hydraulic lubricator assembly for inserting a downhole tool into a wellbore, the hydraulic lubricator assembly comprising:
a spool for enclosing the downhole tool;
a pressure isolation connector positioned above the spool, the pressure isolation connector comprising a top, a base, a lower packing gland attached to the base, and an upper packing gland attached to the top, the lower packing gland and the upper packing gland each having a packing gland body, a packing gland nut that engages the packing gland body, V-packing, and a packing gland pusher;
a blowout preventer connected below the spool, wherein the blowout preventer includes internal rams; and
a hydraulic assembly positioned above the pressure isolation connector, the hydraulic assembly movable to lower the downhole tool assembly into the blowout preventer, where the internal rams are used to suspend the downhole tool in the wellbore.
10. The hydraulic lubricator assembly of claim 9 , wherein the spool comprises spool segments.
11. The hydraulic lubricator assembly of claim 9 , wherein the hydraulic assembly comprises a rod connected to the downhole assembly.
12. The hydraulic lubricator assembly of claim 11 , wherein the rod is connected to the downhole assembly via a connector sub.
13. The hydraulic lubricator assembly of claim 9 , wherein the lower packing gland comprises a ring seal.
14. The hydraulic lubricator assembly of claim 11 , wherein the rod comprises modular rod segments.
15. A method for lubricating a downhole tool into a wellbore, the method comprising the steps of:
installing a blowout preventer to the top of a wellhead, wherein the blowout preventer includes internal rams;
assembling the downhole tool;
placing the assembled downhole tool in at least one spacer spool;
connecting the spacer spool to the top of the blowout preventer;
installing a pressure isolation connector to the top of the spacer spool, wherein the pressure isolation connector is provided with a lower packing gland and an upper packing gland;
connecting a hydraulic assembly to the top of the pressure isolation connector such that a rod of the hydraulic assembly extends through the lower packing gland and the upper packing gland;
connecting the rod to the downhole tool in the spacer spool;
equalizing the pressure in the at least one spacer spool and the pressure in the wellbore;
holding the pressure in the spacer spool with the lower packing gland;
activating the hydraulic assembly to extend the downhole tool through the blowout preventer; and
suspending the downhole tool in the blowout preventer with the internal rams of the blowout preventer.
16. The method of claim 15 , further comprising the steps of:
releasing the pressure in the at least one spacer spool;
removing the spacer spools, pressure isolation connector, and hydraulic assembly from the blowout preventer;
installing a coiled tubing injector on top of the blowout preventer;
connecting a coiled tubing to the downhole tool; and
lowering the downhole tool into the wellbore with the coiled tubing injector.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/781,582 US20100224374A1 (en) | 2006-03-30 | 2010-05-17 | Apparatus and Method for Lubricating and Injecting Downhole Equipment Into a Wellbore |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US78726406P | 2006-03-30 | 2006-03-30 | |
US11/731,639 US20070227744A1 (en) | 2006-03-30 | 2007-03-30 | Apparatus and method for lubricating and injecting downhole equipment into a wellbore |
US12/781,582 US20100224374A1 (en) | 2006-03-30 | 2010-05-17 | Apparatus and Method for Lubricating and Injecting Downhole Equipment Into a Wellbore |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/731,639 Continuation US20070227744A1 (en) | 2006-03-30 | 2007-03-30 | Apparatus and method for lubricating and injecting downhole equipment into a wellbore |
Publications (1)
Publication Number | Publication Date |
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US20100224374A1 true US20100224374A1 (en) | 2010-09-09 |
Family
ID=38557157
Family Applications (3)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/731,639 Abandoned US20070227744A1 (en) | 2006-03-30 | 2007-03-30 | Apparatus and method for lubricating and injecting downhole equipment into a wellbore |
US12/776,864 Expired - Fee Related US8397825B1 (en) | 2006-03-30 | 2010-05-10 | Hydraulic lubricating system and method of use thereof |
US12/781,582 Abandoned US20100224374A1 (en) | 2006-03-30 | 2010-05-17 | Apparatus and Method for Lubricating and Injecting Downhole Equipment Into a Wellbore |
Family Applications Before (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/731,639 Abandoned US20070227744A1 (en) | 2006-03-30 | 2007-03-30 | Apparatus and method for lubricating and injecting downhole equipment into a wellbore |
US12/776,864 Expired - Fee Related US8397825B1 (en) | 2006-03-30 | 2010-05-10 | Hydraulic lubricating system and method of use thereof |
Country Status (1)
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US (3) | US20070227744A1 (en) |
Families Citing this family (7)
Publication number | Priority date | Publication date | Assignee | Title |
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CA2506446A1 (en) * | 2005-05-06 | 2006-11-06 | Collin Rickey Morris | Coiled tubing counter |
US7520334B2 (en) * | 2006-09-28 | 2009-04-21 | Stinger Wellhead Protection, Inc. | Subsurface lubricator and method of use |
US7584798B2 (en) * | 2006-09-28 | 2009-09-08 | Stinger Wellhead Protection, Inc. | Subsurface lubricator and method of use |
US20150136422A1 (en) * | 2013-11-18 | 2015-05-21 | Rodgers Technology, Llc | Apparatus and method for deploying equipment into a wellbore |
CN104763370A (en) * | 2015-04-23 | 2015-07-08 | 王福全 | Rapid well mouth blowout preventing device for oil well sucker rod operation |
WO2019018481A1 (en) * | 2017-07-19 | 2019-01-24 | Oceaneering International, Inc | Open water coiled tubing sealing device |
GB2618223A (en) * | 2020-11-11 | 2023-11-01 | Wellvene Ltd | Access and/or maintenance method and associated apparatus |
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Also Published As
Publication number | Publication date |
---|---|
US8397825B1 (en) | 2013-03-19 |
US20070227744A1 (en) | 2007-10-04 |
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Legal Events
Date | Code | Title | Description |
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STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |