Sliding sleeve for stimulating a horizontal wellbore, and method for completing a wellbore
원문보기
IPC분류정보
국가/구분
United States(US) Patent
등록
국제특허분류(IPC7판)
E21B-043/26
E21B-043/267
E21B-033/13
E21B-034/14
E21B-043/14
출원번호
US-0827913
(2015-08-17)
등록번호
US-9951596
(2018-04-24)
발명자
/ 주소
Lynk, John M.
출원인 / 주소
ExxonMobil Uptream Research Company
대리인 / 주소
ExxonMobil Upstream Research Company—Law Department
인용정보
피인용 횟수 :
0인용 특허 :
74
초록▼
A method of completing a wellbore involves placing a series of sliding sleeves along a string of production casing in the wellbore and includes dropping a frac ball into the wellbore and landing it on a seat associated with an uppermost sleeve. Pressure is applied to activate the sleeve, open ports
A method of completing a wellbore involves placing a series of sliding sleeves along a string of production casing in the wellbore and includes dropping a frac ball into the wellbore and landing it on a seat associated with an uppermost sleeve. Pressure is applied to activate the sleeve, open ports along the casing, and fracture a surrounding subsurface formation at a selected zone. Ball sealers are pumped down the well and seated within the sleeve ports. Additional fluid pressure is applied to cause the sleeve to shift further down the well and to release the ball, whereupon the frac ball is pumped to a next lower sleeve. This process may be repeated for multiple sleeves at multiple zones for top-down, multi-stage perforations. A novel sliding sleeve that permits a single ball to be used for activating multiple of the sleeves in series, from heel-to-toe, is also offered.
대표청구항▼
1. A method of completing a well in a subsurface formation, comprising: lining at least a lower portion of a wellbore with a string of production casing;placing a series of sliding sleeves along the production casing, with each sliding sleeve including a tubular housing threadedly connected at oppos
1. A method of completing a well in a subsurface formation, comprising: lining at least a lower portion of a wellbore with a string of production casing;placing a series of sliding sleeves along the production casing, with each sliding sleeve including a tubular housing threadedly connected at opposing ends to joints of the production casing so as to reside along a subsurface formation and each tubular housing including one or more ports along the tubular housing, and each sliding sleeve including a tubular sleeve comprising a pair of first and second elastomeric seals connected to the tubular sleeve and residing in an annular region between the tubular sleeve and the tubular housing, each of the pair of first and second elastomeric seals straddling one or more openings along the tubular sleeve;dropping a fracturing ball into the wellbore;pumping a hydraulic fluid into the wellbore, thereby causing the ball to land on a seat associated with a first sleeve of the series of sliding sleeves;continuing to pump the hydraulic fluid until the tubular sleeve associated with the first sliding sleeve slides a first portion, thereby exposing the one or more ports along the tubular housing of the first sleeve and aligning the one or more ports with the one or more openings along the tubular sleeve;pumping the hydraulic fluid through the one or more openings and the one or more ports in the first sliding sleeve, thereby creating fractures in the subsurface formation adjacent the first sliding sleeve;increasing pumping pressure, thereby causing the first sliding sleeve to slide from the first portion to a second portion along the tubular housing until the first elastomeric seal of the pair of elastomeric seals covers the one or more ports and further increasing pressure within the first sliding sleeve to cause the first seat to release the ball so that the ball drops further down the wellbore;pumping additional hydraulic fluid into the wellbore, thereby causing the ball to land on a seat associated with a second sliding sleeve of the series of sliding sleeves further downhole;continuing to pump the hydraulic fluid into the wellbore until a tubular sleeve associated with the second sliding sleeve slides the first portion, thereby exposing one or more ports along a tubular housing of the second sleeve;pumping the hydraulic fluid through the one or more openings and the one or more ports in the second sliding sleeve, thereby creating fractures in the subsurface formation adjacent the second sliding sleeve; andagain increasing pumping pressure, thereby causing the second sliding sleeve to slide from the first portion to the second portion along the tubular housing until the first elastomeric seal of the pair of elastomeric seals covers the one or more ports and further increasing pressure within the second sliding sleeve to cause the second seat to release the ball so that the ball drops still further down the wellbore. 2. The method of claim 1, further comprising: disposing the production casing along the lower portion of the wellbore in the subsurface formation in a substantially horizontal orientation;a horizontal portion of the production casing comprises a heel and a toe; andthe method further comprises opening the production casing to the formation along the toe. 3. The method of claim 2, further comprising: increasing pumping pressure, thereby causing the first seat to release the ball so that the ball drops further down the wellbore, is conducted after recognizing a condition of screen-out while pumping the hydraulic fluid through the one or more ports in the first sliding sleeve; andremediating the condition of screen-out by exposing one or more ports along the tubular housing of the second sliding sleeve. 4. The method of claim 2, wherein the hydraulic fluid is a slurry comprising a fracturing proppant. 5. The method of claim 2, further comprising: after the step of creating fractures in the subsurface formation adjacent the first sliding sleeve, dropping one or more ball sealers into the wellbore so that the one or more ball sealers seals corresponding ports in the first sleeve, thereby forming a pressure vessel in the first sliding sleeve; andafter the step of creating fractures in the subsurface formation adjacent the second sliding sleeve, dropping one or more ball sealers into the wellbore so that the one or more ball sealers seals corresponding ports in the second sleeve, thereby forming a pressure vessel in the second sliding sleeve. 6. The method of claim 5, further comprising providing each sliding sleeve with components including: the tubular housing;the one or more ports placed along the tubular housing;the tubular sleeve residing within the tubular housing, with the tubular sleeve being held concentrically in place along the housing by a first shear pin;the one or more openings along the tubular sleeve;the seat, with the seat being disposed proximate a lower end of the tubular sleeve and sized to sealingly receive the ball; anda second shear pin residing in an annular region between the tubular sleeve and the surrounding housing. 7. The method of claim 6, further comprising exposing the one or more ports along the tubular housing of a sliding sleeve by shearing the first shear pin, causing the tubular sleeve to slide down the tubular housing in response to fluid pressure applied to the ball until openings along the tubular housing are generally aligned with the one or more ports along the tubular housing. 8. The method of claim 7, wherein each sliding sleeve further comprises: providing a shoulder residing in the annular region between the tubular sleeve and the surrounding tubular housing, the shoulder being configured to rest against the second shear pin to align the openings along the tubular housing with the one or more ports along the tubular housing in response to the first fluid pressure; andproviding a recess along an inner diameter of the tubular housing, the recess residing below the one or more ports. 9. The method of claim 8, further comprising: providing the seat with at least two collet fingers extending from the tubular sleeve, and connected dogs, wherein the dogs are biased in a closed and overlapping position, creating a fluid flow barrier in the wellbore;causing the seat to release the ball comprises overcoming a biasing force such that the dogs are opened and the fluid flow barrier is removed; andcausing the seat to release the ball further comprises causing the shoulder to shear the second shear pin at a second fluid pressure, thereby allowing the tubular sleeve to slide further along the tubular housing until the opened dogs are expanded into the recess along the tubular housing, and allowing the ball to be released to a next sleeve in the series of sleeves. 10. The method of claim 9, further comprising: securing the second shear pin to the inner diameter of the tubular housing;securing the shoulder to an outer diameter of the tubular sleeve. 11. The method of claim 8, further comprising: determining a formation parting pressure of the subsurface formation;ensuring that the first shear pin of each of the series of sliding sleeves is designed to shear at the first fluid pressure, which is lower than the formation parting pressure; andensuring that the second shear pin of each of the series of sliding sleeves is designed to shear at the second fluid pressure, which is greater than the formation parting pressure. 12. The method of claim 1, further comprising: perforating the production casing at a level of the second of the series of sliding sleeves. 13. The method of claim 1, further comprising: perforating the production casing at the level of each of the sliding sleeves in the series of sliding sleeves. 14. A sliding sleeve for a downhole completion operation, comprising: a tubular housing having a first end and a second end, each end being configured to threadedly connect to joints of production casing;one or more ports disposed at a location along the tubular housing;a tubular sleeve residing concentrically within a bore of the tubular housing;a plurality of radially disposed ball seat dogs extending from a lower end of the tubular sleeve, wherein the ball seat dogs are biased to collapse into the bore of the tubular housing, thereby forming a seat for receiving a fracturing ball;a first shear pin proximate the first end of the tubular sleeve, securing the tubular sleeve to the tubular housing proximate a first end of the tubular housing, wherein the shear pin is configured to shear in response to a first degree of hydraulic pressure applied to a ball when the ball has landed on the seat, thereby permitting the tubular sleeve to slide along the tubular housing in a direction of the second end of the tubular housing;one or more openings along the tubular sleeve intermediate a first end and a second end of the tubular sleeve; andelastomeric seals disposed within an annular region formed between the tubular sleeve and the surrounding tubular housing, straddling the one or more openings wherein the tubular sleeve is configured so that when the tubular sleeve slides further along the tubular housing in response to a second degree of hydraulic force, the first elastomeric seal covers the one or more ports;and wherein: the one or more openings are sized and arranged to reside adjacent the one or more ports when the tubular sleeve slides towards the second end of the tubular housing in response to the first degree of hydraulic pressure; andthe ball seat dogs are configured to open and to release the ball from the sliding sleeve in response to a second degree of hydraulic pressure that is greater than the first degree of hydraulic pressure. 15. The sliding sleeve of claim 14, wherein the one or more ports are sized to receive a respective ball sealer. 16. The sliding sleeve of claim 15, further comprising: a second shear pin residing in the annular region between the sleeve and the surrounding housing;a shoulder residing in the annular region between the sleeve and the surrounding housing, the shoulder being configured to serve as a stop against the second shear pin when the opening along the tubular housing is aligned with the one or more ports along the tubular housing anda recess along an inner diameter of the tubular housing, the recess residing below the one or more ports proximate the second end of the tubular housing, the recess dimensioned to receive outer surfaces of the ball seat dogs when the dogs are opened in response to the second degree of hydraulic pressure and after the tubular sleeve slides along the tubular housing. 17. The sliding sleeve of claim 16, wherein: the seat comprises two or more collett fingers, each of which supports a respective ball seat dog, and wherein the dogs are biased in a closed and overlapping position. 18. The sliding sleeve of claim 17, wherein: the second shear pin is secured to an inner diameter of the tubular housing;a shear catch is secured to an outer diameter of the tubular sleeve; andthe sleeve further comprises first and second elastomeric seals connected to the tubular sleeve and residing in the annular region, the elastomeric seals straddling the openings along the tubular sleeve. 19. The sliding sleeve of claim 18, wherein: the first degree of hydraulic pressure is lower than a parting pressure of a surrounding formation; andthe second degree of hydraulic pressure is greater than the formation parting pressure.
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