WO2016048675A1 - Mise en œuvre de tubage enroulé concentrique pour application de fracture hydraulique - Google Patents

Mise en œuvre de tubage enroulé concentrique pour application de fracture hydraulique Download PDF

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Publication number
WO2016048675A1
WO2016048675A1 PCT/US2015/049415 US2015049415W WO2016048675A1 WO 2016048675 A1 WO2016048675 A1 WO 2016048675A1 US 2015049415 W US2015049415 W US 2015049415W WO 2016048675 A1 WO2016048675 A1 WO 2016048675A1
Authority
WO
WIPO (PCT)
Prior art keywords
wellbore
coiled tubing
flow
tubing string
flow area
Prior art date
Application number
PCT/US2015/049415
Other languages
English (en)
Inventor
Juan Carlos Flores
Luis A. Castro
Original Assignee
Baker Hughes Incorporated
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Priority to CA2962579A priority Critical patent/CA2962579A1/fr
Publication of WO2016048675A1 publication Critical patent/WO2016048675A1/fr

Links

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
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/20—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables
    • E21B17/203—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables with plural fluid passages
    • 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

Definitions

  • This disclosure relates to coiled- in-coiled tubing. More particularly, this disclosure relates to systems and methods for concentric coiled-in-coiled tubing for use in treating a wellbore, and the like.
  • Coiled tubing has proven increasingly useful in oil and gas field applications, including workovers, drilling, logging and well stimulation.
  • coiled tubing units comprise a continuous length of several thousand feet (possibly up to 25,000 feet) of steel tubing, capable of withstanding pressures on the order of 15,000 psi, capable of being repeatedly coiled and uncoiled from a mobile spool, and capable of being injected and withdrawn from oil and gas wells without killing the well.
  • Coiled tubing lengths are generally understood in the field to comprise several hundred or several thousand feet of continuous, uniform outer diameter tubing, coilable on a truckable spool and injectable in a bore by means of a coiled tubing injector.
  • the continuous lengths are typically, although not necessarily, manufactured of steel having a longitudinally welded seam. Resin and fiber polymer materials may also be used for continuous tubing. Typically, successive lengths of steel tubing are welded to create a desired unit length.
  • coiled tubing is expected to be able to withstand significant pressure differentials, such as at least 1,000 psi and preferably closer to 15,000 psi, and to be sufficiently corrosive resistant and heat resistant to withstand exposure to common hydrocarbons downhole.
  • truckable spool means a spool or reel having an outside diameter of approximately six meters, and typically less, so that the spool can be transported by a boat or by a truck over land and highways to a site.
  • Coiled tubing generally has sufficient flexibility to be reeled on a truckable spool and repeatedly coiled and uncoiled from such a spool or reel.
  • coiled tubing's ability to be injected in a bore means that the tubing, while flexible, is also sufficiently rigid that lengths of several hundred or thousand feet can be continuously thrust, or injected, in bores using coiled tubing injection equipment.
  • coiled tubing has also been used in hydraulic fracturing applications.
  • one drawback of current fracture methods is that they implement a single coil of tubing and there may be a risk of getting stuck within a wellbore due to the high frequency of screen outs that may occur during some treatment procedures, such as fracturing.
  • Concentric pipe strings provide two non-well bore channels for fluid communication downhole, typically, with one channel, such as the inner channel, used to pump fluid (liquid or gas or multiphase fluid) downhole while a second channel, such as the annular channel formed between the concentric strings, used to return fluid to the surface.
  • One advantage of the disclosed system and methods is they provide an efficient system and method for treating a wellbore and recovery process that enables, if required, the removal of a screen out, treatment, proppant, and/or solids in each fracture created.
  • One embodiment of the present disclosure is a method of treating a wellbore comprising positioning an end of a coiled tubing string adjacent a portion of a wellbore, the coiled tubing string having a first flow area, a second flow area, and a valve configured to control flow out of the first and second flow areas into the portion of the wellbore.
  • the method comprises treating a portion of the wellbore by pumping fluid down at least one of the first and second flow areas.
  • the method may include pumping fluid down both the first flow area and the second flow area to treat the portion of the wellbore.
  • the method may include isolating the portion of the wellbore prior to treating the portion of the wellbore. Isolating the portion of the wellbore may comprises setting a plurality of isolating elements.
  • the valve may be located proximal to the end of the coiled tubing string.
  • the method may include actuating the valve and pumping fluid up the second flow area while pumping fluid down the first flow area.
  • the valve may permit fluid and particulates in the portion of the wellbore to flow up the second flow area.
  • Treating the wellbore may comprise fracturing a formation adjacent the portion of the wellbore. A screen out may have formed in a fracture during the fracturing of the formation.
  • the method may include cleaning out the screen out from the portion of the wellbore. Actuating the valve and pumping fluid up the second flow path may clean out the screen out.
  • One embodiment of the present disclosure is a system to treat a portion of a wellbore.
  • the system comprises a coiled tubing string having a first flow area and a second flow area and at least one valve configured to control flow of both the first and second flow areas out of the coiled tubing string.
  • the system may include at least one isolation element.
  • the valve of the system may be positioned proximate an end of the coiled tubing string.
  • the system may include at least one port that permits communication from the first flow area and an exterior of the coiled tubing string and at least one port that permits communication from the second flow area and the exterior of the coiled tubing string, wherein the at least one valve is configured to control flow out both ports.
  • the at least one isolation element may be actuated to isolate a portion of the wellbore. Fluid may be pumped down the first and second flow areas from a surface location to treat the isolated portion of the wellbore.
  • the valve may be actuated so that fluid may be pumped down from the surface in the first flow area and pumped up to the surface in the second flow area.
  • a formation of the portion of the wellbore may be fractured or stimulated by pumping fluid down both the first and second flow areas. Fluid pumped up to the surface in the second flow area may be used to remove a screen out of a fracture of the portion of the wellbore.
  • FIG. 1 shows an embodiment of a coiled tubing string that may be used to treat a portion of a wellbore.
  • FIG. 2 shows an embodiment of a coiled tubing string that may be used to clear a screen out during a treatment procedure, such as a hydraulic fracturing.
  • FIG. 3 shows a cut away view of a coiled tubing string.
  • FIG. 4 shows a cross-sectional view of an embodiment of a coiled tubing string.
  • FIG. 5 shows a cross-sectional view of an embodiment of a coiled tubing string.
  • FIG. 1 shows a coiled tubing string 100 having a first flow path 101 and a second flow path 102 positioned within a wellbore 1.
  • the coiled tubing string 100 may have various configurations that permit two flow paths 101 and 102.
  • the coiled tubing string 100 may be a coiled-in-coiled tubing string with one flow path down the inner coiled tubing string and the other flow path down the larger coiled tubing string.
  • the coiled tubing string may include an internal wall that separates the interior of the coiled tubing string 100 into two separate flow paths.
  • the coiled tubing string 100 may be used to treat a portion of a wellbore 1.
  • Fluid may be pumped down the first flow path 101, as indicated by the arrow in FIG. 1, and out a port 111 to treat the wellbore 1.
  • fluid may be pumped down the second flow path 102, as indicated by the arrow in FIG. 1, and out a port 112 to treat the wellbore 1.
  • a valve 110 may be used to control fluid flow through the flow paths 101 and 102 in the coiled tubing string 100.
  • the valve 110 may be positioned adjacent the ports 111 and 112 may be used to control the flow of fluid between the ports 111 and 112 and the flow paths 101 and 102.
  • the valve 110 configured to control the fluid flow through the two flow paths 101 and 102 may be positioned at various locations along the coiled tubing string 100 including at the surface.
  • the configuration of the ports 111 and 112 and valve 110 with respect to the end of the tubing string 100 and each other is for illustrative purposes only and may be varied as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
  • the portion of the wellbore 1 may be isolated from the rest of the wellbore by upper and/or lower isolating elements 120.
  • Various isolation elements 120 that may be connected to a coiled tubing string 100 may be used with the coiled tubing string 100 disclosed herein.
  • the coiled tubing string 100 may be connected to the tool disclosed in U.S. patent app. no. 14/318,952 entitled "Synchronic Dual Packer," filed on June 30, 2014, which is incorporated by reference herein in its entirety.
  • the coiled tubing string 100 having two flow paths 101 and 102 with a valve 110 that may be actuated to control the flow of the flow paths 101 and 102 may be used with or without upper and lower isolation elements 120.
  • the coiled tubing string 100 may be used during various treatment procedures to treat a portion of a wellbore 1. For example, an acid may be delivered to a production zone to stimulate production.
  • the coiled tubing string 100 having two flow paths 101 and 102 may also be used to fracture a formation 5 of a wellbore 1.
  • upper and lower isolation elements 120 may be actuated to isolate a portion of the wellbore 1 that includes a perforation 2 in the wellbore casing. Fluid may be pumped down either of the flow paths 101 and 102 or may be pumped down both of the first and second flow paths 101 and 102 to fracture 6 the formation 5.
  • the coiled tubing string 100 may also be used to treat and/or fracture an open hole wellbore as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
  • the portion of the wellbore being treated through the coiled tubing string 100 may require a clean out procedure.
  • a screen out 10 may form in the fracture 6 and wellbore 1 as shown in FIG. 2.
  • Pumping fluid down both the first and second flow paths 101 and 102 of the coiled tubing string 100 will not remove the screen out 10 as there is nowhere for the sand forming the screen out to go.
  • the valve 110 of the coiled tubing string 100 may be actuated to permit fluid to be pumped down one of the flow paths, such as the first flow path 101, and to be pumped up the other flow path, such as the second flow path 102, as indicated by the arrows in FIG. 2. Fluid pumped up one of the flow paths 102 of the coiled tubing string
  • the coiled tubing string 100 permits the removal of the sand forming the screen out 10 from the isolated portion of the wellbore 1.
  • the coiled tubing string 100 having two flow paths 101 and 102 with at least one valve 110 that controls the flow paths 101 and 102 to function as a coiled tubing string 100 to treat a wellbore as well as conduct a cleanout procedure.
  • the coiled tubing string 100 may include more than one valve 110 to control the flow through the flow paths
  • the fluid may be pumped down the second flow path 102 and up the first flow path 101 as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.
  • FIG. 3 shows a cutaway view of an embodiment of a coiled tubing string 200 having an inner coiled tubing 201 positioned within an outer coiled tubing 202.
  • the coiled tubing string 200 includes a first flow area 203 down the interior of the inner coiled tubing 201 and a second flow area 204 between the exterior of the inner coiled tubing 202 and the interior of the outer coiled tubing 202.
  • FIG. 4 shows a cross-section view of an embodiment of coiled tubing string 200 having an inner coiled tubing 201 positioned within an outer coiled tubing 202.
  • the inner coiled tubing 201 may be connected to the outer coiled tubing 202 or may be free to move within the outer coiled tubing 202.
  • FIG. 4 shows the first flow area 203 and the second flow area 204.
  • FIG. 5 shows a cross section view of an embodiment of a coiled tubing string 300 having a first flow area 303 and a second flow area 304.
  • An inner wall 302 in between the outer wall 301 of the coiled tubing string 300 divides the cross-sectional area of the coiled tubing string 300 to form the two flow areas 303 and 304.
  • a coiled tubing string 100 having a first and second flow areas 101 and 102 are for illustrative purposes only. Various configurations may be used to form a coiled tubing string 100 having two flow paths 101 and 102 that may be controlled by one or more valves 110 as would be appreciated by one of ordinary skill in the art having the benefit of this disclosure.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (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)
  • Mechanical Engineering (AREA)
  • Pipeline Systems (AREA)
  • Filtration Of Liquid (AREA)

Abstract

L'invention concerne un procédé et un système de traitement d'une partie d'un puits de forage. Le système comprend une colonne de production enroulée ayant deux zones d'écoulement de fluide et une vanne configurée pour commander l'écoulement de fluide hors des deux zones d'écoulement. Le système peut comprendre au moins un élément d'isolation utilisé pour isoler une partie d'un puits de forage. La partie isolée du puits de forage peut être traitée en pompant du fluide vers le bas dans une des zones d'écoulement ou les deux. La vanne peut être actionnée pour permettre à du fluide d'être pompé vers le bas dans une zone d'écoulement pendant que du fluide est pompé vers le haut dans l'autre zone d'écoulement, ce qui peut être utilisé pour nettoyer un blocage de crépine, un traitement, un agent de soutènement, et/ou des solides dans le puits de forage. La colonne de tubage enroulée avec deux zones d'écoulement de fluide peut être utilisée pour traiter, stimuler, et/ou fracturer une partie d'un puits de forage et fournir des capacités de nettoyage, si nécessaire.
PCT/US2015/049415 2014-09-24 2015-09-10 Mise en œuvre de tubage enroulé concentrique pour application de fracture hydraulique WO2016048675A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CA2962579A CA2962579A1 (fr) 2014-09-24 2015-09-10 Mise en ƒuvre de tubage enroule concentrique pour application de fracture hydraulique

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US14/495,635 US20160084057A1 (en) 2014-09-24 2014-09-24 Concentric coil tubing deployment for hydraulic fracture application
US14/495,635 2014-09-24

Publications (1)

Publication Number Publication Date
WO2016048675A1 true WO2016048675A1 (fr) 2016-03-31

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PCT/US2015/049415 WO2016048675A1 (fr) 2014-09-24 2015-09-10 Mise en œuvre de tubage enroulé concentrique pour application de fracture hydraulique

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US (1) US20160084057A1 (fr)
CA (1) CA2962579A1 (fr)
WO (1) WO2016048675A1 (fr)

Families Citing this family (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11060011B2 (en) * 2016-08-24 2021-07-13 Halliburton Energy Services, Inc. Coil tubing cleanout fluid
CN107288587B (zh) * 2017-08-15 2020-01-31 江苏和信石油机械有限公司 一种新型采油管柱
US11021648B2 (en) * 2019-10-11 2021-06-01 Halliburton Energy Services, Inc. Energized natural gas foam delivery devices and methods
CA3183739A1 (fr) * 2020-07-08 2022-01-13 Dustin K. Ward Tube spirale concentrique etanche

Citations (5)

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WO2004065760A1 (fr) * 2003-01-15 2004-08-05 Halliburton Energy Services, Inc. Filtre a sable a element isolant interne et son procede d'utilisation
US20050224231A1 (en) * 2004-04-07 2005-10-13 Surjaatmadja Jim B Flow switchable check valve
US20060060352A1 (en) * 2004-09-22 2006-03-23 Vidrine William L Sand control completion having smart well capability and method for use of same
US20070151735A1 (en) * 2005-12-21 2007-07-05 Ravensbergen John E Concentric coiled tubing annular fracturing string
US20100155065A1 (en) * 2008-12-22 2010-06-24 Bj Services Company Methods for placing multiple stage fractures in wellbores

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WO1997001017A1 (fr) * 1995-06-20 1997-01-09 Bj Services Company, U.S.A. Tubage enroule, isole et/ou concentrique
DE69531747D1 (de) * 1995-07-25 2003-10-16 Nowsco Well Service Inc Gesichertes verfahren und vorrichtung zum fluidtransport mit gewickeltem rohr, mit anwendung im testen von bohrgestängen
US7066283B2 (en) * 2002-08-21 2006-06-27 Presssol Ltd. Reverse circulation directional and horizontal drilling using concentric coil tubing
ES2449066T3 (es) * 2004-07-19 2014-03-18 Philera New Zealand Limited Síntesis de trietilentetraminas
KR100633330B1 (ko) * 2004-07-30 2006-10-12 주식회사 하이닉스반도체 반도체 장치의 캐패시터 제조방법
AU2008327958B2 (en) * 2007-11-19 2011-12-08 Shell Internationale Research Maatschappij B.V. In-situ fluid compatibility testing using a wireline formation tester
AU2010339027A1 (en) * 2010-01-04 2012-08-16 Packers Plus Energy Services Inc. Wellbore treatment apparatus and method
CA2912919A1 (fr) * 2010-09-17 2012-03-22 Mathew M. Samuel Apport d'agents chimiques dans un sondage pourvu d'un systeme a microcolonne de production

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2004065760A1 (fr) * 2003-01-15 2004-08-05 Halliburton Energy Services, Inc. Filtre a sable a element isolant interne et son procede d'utilisation
US20050224231A1 (en) * 2004-04-07 2005-10-13 Surjaatmadja Jim B Flow switchable check valve
US20060060352A1 (en) * 2004-09-22 2006-03-23 Vidrine William L Sand control completion having smart well capability and method for use of same
US20070151735A1 (en) * 2005-12-21 2007-07-05 Ravensbergen John E Concentric coiled tubing annular fracturing string
US20100155065A1 (en) * 2008-12-22 2010-06-24 Bj Services Company Methods for placing multiple stage fractures in wellbores

Also Published As

Publication number Publication date
CA2962579A1 (fr) 2016-03-31
US20160084057A1 (en) 2016-03-24

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