USRE42030E1 - Critical velocity reduction in a gas well - Google Patents
Critical velocity reduction in a gas well Download PDFInfo
- Publication number
- USRE42030E1 USRE42030E1 US12/492,526 US49252609A USRE42030E US RE42030 E1 USRE42030 E1 US RE42030E1 US 49252609 A US49252609 A US 49252609A US RE42030 E USRE42030 E US RE42030E
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- US
- United States
- Prior art keywords
- string
- tubing
- tubing string
- dead
- well
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
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- 239000012530 fluid Substances 0.000 claims abstract description 32
- 239000003153 chemical reaction reagent Substances 0.000 claims abstract description 16
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- 239000000463 material Substances 0.000 claims 12
- 238000011084 recovery Methods 0.000 abstract description 2
- 230000002708 enhancing effect Effects 0.000 abstract 1
- 238000004519 manufacturing process Methods 0.000 description 40
- 239000007789 gas Substances 0.000 description 17
- 239000007788 liquid Substances 0.000 description 14
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 10
- 238000002955 isolation Methods 0.000 description 9
- 239000004576 sand Substances 0.000 description 9
- 230000015572 biosynthetic process Effects 0.000 description 6
- 230000007423 decrease Effects 0.000 description 6
- 239000003345 natural gas Substances 0.000 description 5
- 244000309464 bull Species 0.000 description 4
- 230000003247 decreasing effect Effects 0.000 description 4
- 239000002343 natural gas well Substances 0.000 description 4
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 230000007246 mechanism Effects 0.000 description 3
- 210000002445 nipple Anatomy 0.000 description 3
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- 230000008901 benefit Effects 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 239000006260 foam Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 238000009825 accumulation Methods 0.000 description 1
- 230000000712 assembly Effects 0.000 description 1
- 238000000429 assembly Methods 0.000 description 1
- 238000012937 correction 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
- -1 foamers Substances 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Images
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
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
Definitions
- the invention relates to the recovery of natural gas from natural gas wells and more particularly concerns an apparatus for reducing the critical velocity required to unload extended perforated intervals in liquid-loaded gas wells.
- FIG. 1 illustrates a production tubing string 13 deployed in a cased natural gas wellbore 101 having an extended perforated interval 102 .
- the production rate of a natural gas well is a function of the pressure differential between the underground reservoir and the well head. This differential is decreased by back pressure against the reservoir pressure. As natural gas and associated liquids are extracted during production, a gradual loss of reservoir pressure occurs in some natural gas wells, thus decreasing the pressure differential. Natural gas wells produce liquids such as water and hydrocarbon. Removal of these produced liquids depends on the velocity of the gas stream produced from the formation. As reservoir pressure and flow potential decrease, there is a corresponding drop in the flow velocity of the natural gas through the production tubing to the well head.
- FIG. 2 illustrates one of the methods that have been used in the art to overcome the problem of liquid loading.
- Production tubing 13 is extended to include a ported tubing section 17 and a “dead string” 14 .
- Ported tubing section 17 can be a length of production tubing, for example one joint of production tubing or a smaller length of tubing i.e., a pup joint, having holes 18 drilled therein.
- the inner diameter (ID) of production tubing section 13 and the ID of dead string 14 are isolated from each other by plug 15 .
- this design can include a “bull plug” on the bottom of dead string 14 to force the flow up to the ported section 17 . Thus, fluids do not flow through the ID of dead string 14 .
- dead string 14 is to decrease the area of the annular space 106 between the dead string and the face of the wellbore (or casing). During operation, gas and formation fluids 11 in perforated interval 102 flow in the annular region 106 around dead string 14 .
- Dead string 14 typically has a larger outer diameter (OD) than production tubing section 13 , though the dead string 14 can also be the same size as the production tubing 13 . For example, in a well with 41 ⁇ 2′′ casing having an ID of 4′′, the production string might have an OD of 23 ⁇ 8′′ and the dead string might have an OD of 27 ⁇ 8′′.
- Dead string 14 reduces the flow area in the perforated interval, thereby decreasing the required flow rates (critical velocities) to lift produced liquid in the wellbore to surface and reduce the effects of liquid loading. Formation fluids and gas 11 cross over into the production tubing section 13 via holes 18 in ported tubing section 17 .
- Perforated regions of a gas well often produce sand, which can stick to the tubing (i.e., to dead string 14 inside the casing), fill the tubing, or fill the wellbore below the dead string 14 .
- Several actions that well operators would typically perform to diagnose and correct these sand problems are not possible with the apparatus illustrated in FIG. 2 . and other dead string installations or designs known in the art.
- plug 15 isolating the dead string from the production string or a permanent “bull plug” on the bottom of dead string 14 , as mentioned above
- the operator lacks the ability to run a wireline to the bottom of the wellbore to check for sand fill levels below the dead string 14 .
- perforated tubing section 17 limits an operator's ability run fluid down the annular region between the tubing and the casing to the bottom of the wellbore because such fluids would tend to cross over into the ID of the tubing via holes 18 .
- the configuration illustrated in FIG. 2 severely limits an operator's ability to access regions of the wellbore below plug 15 , for example, to deliver chemical foamer to the end of the dead string.
- the presently disclosed apparatus provides a dead string for reducing the critical velocity of gas produced in a perforated interval of a gas well while still providing the well operator with the ability to access the well bore below the dead string.
- the apparatus features a tubing string extending into the gas well and having a ported member co-axially disposed within the tubing string.
- Typical ported members include sliding sleeve valves or ported flow subs, which are described in more detail below.
- the ported member will typically be positioned at the top of or in the top third of the perforated interval.
- the ported member is configured to selectively permit or prevent fluid communication between the interior of the ported member and the annular region between the tubing string and a wall of the well.
- fluids and gasses can enter the tubing string from the annulus via ports in the ported member.
- the ports can be closed to allow fluids to be run through the ported member to sections of the tubing string below the ported member.
- the apparatus includes a retrievable plug disposed within the tubing string below the ported member.
- a retrievable plug disposed within the tubing string below the ported member.
- fluid flow will be entering the tubing string from the annulus via the ported member and flowing toward the surface in the tubing string.
- the operator simply removes the plug to access lower regions of the string because the dead string is open ended below the plug.
- the apparatus also includes a dead string co-axially disposed in the tubing string below the retrievable plug. Flow between the dead string and the upper part of the tubing string is blocked by the retrievable plug.
- the dead string operates simply to decrease the flow area of the annulus and thereby decrease the critical velocity of gas produced in the perforated interval.
- an operator can access the dead string by removing the retrievable plug.
- Embodiments of the apparatus are also configured to deliver reagents such as foamers and/or surfactants to the extended perforated interval.
- capillary tubing can be attached to tubing string to provide a conduit for such reagents.
- a valve or inlet such as a gas lift mandrel or injection sub can provide a crossover of the reagents from the capillary tubing to the inside of tubing string.
- the retrievable plug is configured to be moved either above or below the depth where reagent is delivered into the tubing string.
- FIG. 1 illustrates a length of production tubing string deployed in a cased natural gas wellbore having a perforated interval, as is common in the prior art.
- FIG. 2 illustrates a prior art configuration of a dead string attached to a production string.
- FIG. 3 illustrates a production string having a ported member, a retrievable plug, and a dead string.
- FIG. 4 illustrates a ported flow sub having configured to engage an isolation tool.
- FIG. 5 illustrates a production string having a ported member, a retrievable plug, and a dead string, exteriorly banded capillary tubing, and a gas lift valve.
- FIG. 3 illustrates an embodiment of the presently disclosed apparatus.
- the apparatus 100 can be deployed in a cased wellbore 101 having a perforated interval 102 .
- Apparatus 100 includes a production tubing section 103 and a dead string 104 .
- the inner diameter (ID) of production tubing section 103 and the ID of dead string 104 are isolated from each other by retrievable plug 105 .
- gas and formation fluids in perforated interval 102 flow in the annular region 106 around dead string 104 .
- Dead string 104 typically has a larger outer diameter (OD) than production tubing section 103 but could be the same size as the production tubing.
- Dead string 104 reduces the flow area in the perforated interval, thereby decreasing the critical velocity needed to lift produced liquids in the wellbore reducing the effects of liquid loading. It is often preferable that the couplings used for dead string 104 be configured flush with the profile of the OD of the dead string and not have external collars, etc., which cause accumulation sites for sand and particulate in the wellbore.
- Such “Ultra Flush Joint” pipe is known in the art. A particularly suitable joint is the ULTRA-FJ, available from Weatherford International, Inc. (Houston, Tex.). Additionally, various sizes of coil tubing are known in the art and can be used.
- ported member 107 is configured such that ports 108 can be closed, i.e., so that fluid communication between the inside and the outside of ported member 107 can be selectively permitted or prevented.
- Ported member 107 can be, for example, a sliding sleeve valve, as is known in the art. When the sliding sleeve valve is open, formation fluids can enter the ID production tubing via ports in the valve. Likewise, the valve can be closed, thereby isolating the valve.
- a ported member 107 can be a ported flow sub instead of a sliding sleeve valve.
- An example of a ported flow sub is schematically illustrated in FIG. 4 .
- Ported flow sub 201 is configured to integrate into a production stream via threaded ends 202 and 203 and its simplest embodiment is a length of tubing having ports 204 disposed therein.
- a ported flow sub 201 typically provides greater flow area than is available with a sliding sleeve valve.
- Flow sub 201 can include an isolation tool 205 for closing off ports 204 .
- Isolation tool 205 is a tubular member that is configured to fit within the ID of flow sub 201 as depicted by dashed line 206 .
- Isolation tool 205 can be designed to lockingly engage within flow sub 201 , for example, via locking mechanism 207 , which is configured to engage mating receiver 208 on flow sub 201 .
- the isolation tool illustrated in FIG. 3 also features a seal ring packing 209 that is configured to seal within a polished bore 210 in flow sub 201 .
- isolation tool 205 When isolation tool 205 is inserted in flow sub 201 it effectively isolates ports 204 and provides a flow path through the inner diameter 211 of the isolation tool.
- a particularly suitable ported member is a Heavy Duty Flow Sub (Weatherford International, Inc., Houston, Tex.), which is compatible with a locking isolation tool as described above.
- plug 105 is a retrievable plug and thus can be removed to provide an operator access to the tubing string below the plug.
- Retrievable plugs are known in the art.
- a particularly suitable retrievable plug assembly is a WX Nipple with a retrievable equalizing plug (Weatherford International, Inc., Houston, Tex.).
- an operator can remove retrievable plug 105 and run a wire line down the tubing.
- the wire line can exit the bottom of the dead string and continue to the bottom of the well.
- the end of the dead string can include a wire line re-entry guide to assist in pulling the wire line tools back up into the dead string. If sand levels are acceptable, retrievable plug 105 is simply reinstalled and the system is immediately operational.
- dead string 104 If dead string 104 is sanded in, an operator can try. to establish circulation down the tubing and back up the annulus while pulling or jarring on the production tubing string. To do this, the operator would typically shut off ports 108 , for example by installing an isolation tool as described above if ported member 107 is a ported flow sub. The operator can then deliver fluid to the bottom of the dead string while attempting to free the dead string.
- the apparatus can include a safety release mechanism such as a shear-out joint, for example, between the removable plug 105 and the dead string 104 .
- a safety release mechanism such as a shear-out joint, for example, between the removable plug 105 and the dead string 104 .
- a shear-out joint for example, between the removable plug 105 and the dead string 104 .
- Such a mechanism provides the operator the option to shear off and pull out the tubing, ported member, and plug assembly, should the previously described correction attempts fail.
- the operator simply applies adequate tension to tubing string to shear the tubing string at the shear-out joint and removes the string components above the joint.
- the operator can then recover the component(s) below the shear-out joint (namely, dead string 104 ) via fishing operations known in the art.
- This embodiment includes capillary tubing 301 or a side string banded to the OD of the tubing string and connecting to a gas lift mandrel 302 or injection sub installed in the tubing string below removable plug 105 .
- This embodiment provides the ability to deliver reagents, such as foamers, surfactants, etc. to the perforated interval 102 (shown in FIG. 1 ).
- the gas lift mandrel is installed below retrievable plug 105 so that such reagents can be injected into dead string 104 via inlet 303 , rather than being routed back up the production tubing.
- the reagents will be injected into the top of dead string 104 and can then fall through the ID of the dead string and into perforated interval 102 .
- the apparatus can include nipples configured to receive retrievable plug 105 below inlet 303 , rather than above inlet 303 as illustrated in FIG. 5 because in some situations it might be desirable to remove retrievable plug 105 and reinstall it below inlet 303 .
- the perforated interval does not generate sufficient gas to generate foam in the annular region around dead string 104
- the operator can reinstall plug 105 below inlet 303 and inject foamer into the production tubing below ported member 107 .
- the apparatus will be installed in the wellbore so that ported member 107 is at or near the top third of the perforated interval. There will typically be enough turbulence due to gas entering the production tubing via ported member 107 to generate foam.
- a plunger lift system can be installed in the production tubing above ported member 107 .
- Plunger lift systems are known in the art and need not be explained in detail here, other than to mention that they are typically implemented in conventional systems, such as illustrated in FIG. 1 , wherein the production tubing terminates at the top of the perforated interval or in roughly the top third of a perforated interval.
- the effectiveness of plunger lift systems suffers if the tubing terminates too high above or too deep within the perforated interval.
- a plunger lift system can be installed in the production tubing above ported member 107 .
- ported member 107 is analogous to the terminus of the production tubing in a conventional system and is typically disposed at the top of or within the top third of the perforated interval for optimum plunger lift operation.
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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)
- Pipe Accessories (AREA)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
- Sampling And Sample Adjustment (AREA)
Abstract
Description
Claims (44)
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/492,526 USRE42030E1 (en) | 2006-01-10 | 2009-06-26 | Critical velocity reduction in a gas well |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/330,361 US7409998B2 (en) | 2006-01-10 | 2006-01-10 | Critical velocity reduction in a gas well |
US12/492,526 USRE42030E1 (en) | 2006-01-10 | 2009-06-26 | Critical velocity reduction in a gas well |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/330,361 Reissue US7409998B2 (en) | 2006-01-10 | 2006-01-10 | Critical velocity reduction in a gas well |
Publications (1)
Publication Number | Publication Date |
---|---|
USRE42030E1 true USRE42030E1 (en) | 2011-01-18 |
Family
ID=38231649
Family Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/330,361 Ceased US7409998B2 (en) | 2006-01-10 | 2006-01-10 | Critical velocity reduction in a gas well |
US12/492,526 Active 2026-09-18 USRE42030E1 (en) | 2006-01-10 | 2009-06-26 | Critical velocity reduction in a gas well |
Family Applications Before (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/330,361 Ceased US7409998B2 (en) | 2006-01-10 | 2006-01-10 | Critical velocity reduction in a gas well |
Country Status (2)
Country | Link |
---|---|
US (2) | US7409998B2 (en) |
CA (1) | CA2539832C (en) |
Families Citing this family (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8196663B2 (en) * | 2008-03-25 | 2012-06-12 | Baker Hughes Incorporated | Dead string completion assembly with injection system and methods |
US9068444B2 (en) | 2012-02-08 | 2015-06-30 | Weatherford Technology Holdings, Llc | Gas lift system having expandable velocity string |
US20190063198A1 (en) * | 2017-08-28 | 2019-02-28 | Flow Resource Corporation Ltd. | System, method, and apparatus for hydraulic fluid pressure sweep of a hydrocarbon formation within a single wellbore |
Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2425202A (en) | 1943-01-12 | 1947-08-05 | Shell Dev | Apparatus for completing wells |
US3901318A (en) | 1974-06-19 | 1975-08-26 | Baker Oil Tools Inc | Method and apparatus for packing gravel in a subterranean well |
US4427070A (en) | 1982-03-29 | 1984-01-24 | O'brien-Goins Engineering, Inc. | Circulating and pressure equalizing sub |
US6491107B2 (en) | 2000-11-29 | 2002-12-10 | Rolligon Corporation | Method and apparatus for running spooled tubing into a well |
US20030047316A1 (en) | 2001-09-10 | 2003-03-13 | Bosley Gordon F. | Open well plunger-actuated gas lift valve and method of use |
US6585050B1 (en) | 1999-09-17 | 2003-07-01 | Timothy E. Etzkorn | System and process for reducing the flowing bottom hole pressure in a natural gas well |
Family Cites Families (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6431107B1 (en) * | 1998-04-17 | 2002-08-13 | Novellant Technologies, L.L.C. | Tendon-based floating structure |
-
2006
- 2006-01-10 US US11/330,361 patent/US7409998B2/en not_active Ceased
- 2006-03-16 CA CA2539832A patent/CA2539832C/en active Active
-
2009
- 2009-06-26 US US12/492,526 patent/USRE42030E1/en active Active
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2425202A (en) | 1943-01-12 | 1947-08-05 | Shell Dev | Apparatus for completing wells |
US3901318A (en) | 1974-06-19 | 1975-08-26 | Baker Oil Tools Inc | Method and apparatus for packing gravel in a subterranean well |
US4427070A (en) | 1982-03-29 | 1984-01-24 | O'brien-Goins Engineering, Inc. | Circulating and pressure equalizing sub |
US6585050B1 (en) | 1999-09-17 | 2003-07-01 | Timothy E. Etzkorn | System and process for reducing the flowing bottom hole pressure in a natural gas well |
US6491107B2 (en) | 2000-11-29 | 2002-12-10 | Rolligon Corporation | Method and apparatus for running spooled tubing into a well |
US20030047316A1 (en) | 2001-09-10 | 2003-03-13 | Bosley Gordon F. | Open well plunger-actuated gas lift valve and method of use |
Non-Patent Citations (1)
Title |
---|
Campbell, Scott; Weatherford quotation entitled "Weatherford Critical Velocity Reducing System (WCVR)"; Jul. 7, 2005. |
Also Published As
Publication number | Publication date |
---|---|
US7409998B2 (en) | 2008-08-12 |
CA2539832A1 (en) | 2007-07-10 |
US20070158074A1 (en) | 2007-07-12 |
CA2539832C (en) | 2010-09-28 |
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