Bottom hole assembly for subterranean operations.

(54) Title: WELL FUND ASSEMBLY FOR UNDERGROUND OPERATIONS. (54) Title: BOTTOM HOLE ASSEMBLY FOR SUBTERRANEAN OPERATIONS.

(57) Summary

Methods and systems for stimulating a drill hole are described. A continuous pipe downhole assembly is described that includes a jet tool. A non-caged ball substitute joint is attached to the jet tool and a ported substitute joint is attached to the non-caged ball substitute joint. Additionally, a caged ball substitute joint is mated to the substitute union with ports.

(57) Abstract

Methods and systems for stimulating a wellbore. A coil tubing bottom hole assembly is disclosed which ineludes a jetting tool. A non-caged ball sub is coupled to the jetting tool and a ported sub is coupled to the non-caged ball sub. Additionally, a caged ball sub is coupled to the ported sub.

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Mexican Institute of Industrial Property

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PATENT TITLE NO. 342005

Owner (s): HALLIBURTON ENERGY SERVICES, INC.

Address: 10200 Bellaire Boulevard, Houston, Texas, 77072, USA

Denomination: ASSEMBLY OF WELL FUND FOR UNDERGROUND OPERATIONS. Classification: IC 8: E21B43 / 26

Inventor (s): MILORAD STANOJCIC; LOYD E. EAST JR .; JIM B. SURJAATMADJA; MALCOLM

J. SMITH ¿MX / a / 2012 / 0C ^ 663 ·;

Country: US ;;

Validity: Twenty years | Vencimi * a reference patent is granted ie compliance with the i □ ntada from the first rights.

Luien subscribes the Industrial Pri ropiedad (Di 6/01/2004, 16/06/2005 | iriso a), 4th and 12th

REQUEST

Internal filing date for October 2010

PRIORITY

Date:

October 2009

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Ito: October 20, 2030 based on articles 1, 2, section V, G ”hai i ón ffl.ySSdelaLeytíea Propli | e the Industrial Property Law, the present patent application of international application and will be subject · Industrial lad.

'• áS'tíehU^{1 5}'^{nte years}«^nprorr°^9ables'rife p ira mantel r valid hte titlej ¡officia 25/01/20 snes I 28/07/20 makes with me of the Federation (DO

06/05 / 2009,06 / 01/2010, 18, lll of the Regulations of the Mexican Institute, Τ sjs * ·. ir * roñes lll and 7 ° bis 2 10/25/1996, 12/26/19 012 and 04/09/2012); articles' le Industrial Property (DOF 12/14/199

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the Law of 05/17/1999,

3rd fraction V amended the Organic Institute of the Mexican Institute of Industrial Property (DOF 12/27/1999, amended on 10/10/2002, 07/29/2004, 08/04/2004 and 09/13/2007); 1, 3 and 5 Clause a) of the Agreement that delegates powers to the Deputy Directors General, Coordinator, Divisional Directors, Holders of the Regional Offices, Divisional Deputy Directors, Departmental Coordinators and other subordinates of the Mexican Institute of Industrial Property. (DOF 12/15/1999, amended on 02/04/2000, 07/29/2004, 08/04/2004 and 09/13/2007).

Issue Date: September 9, 2016

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WELL BOTTOM ASSEMBLY FOR OPERATIONS

Field of the Invention

The present invention is generally related to underground operations, and more particularly, to methods and systems to stimulate a well bore.

Background of the Invention

To produce hydrocarbons (eg oil, gas, etc.) from an underground formation, drill holes can be drilled to penetrate hydrocarbon-containing portions of the underground formation. The portion of the underground formation 'from which hydrocarbons can be produced is commonly referred to as a production zone. In some cases, an underground formation penetrated by the drill hole may have multiple production zones at various locations throughout the drill hole.

Generally, after a drill hole has been drilled to a desired depth, completion operations are performed. Such completion operations may include inserting a casing or casing into the drill hole, and sometimes cementing a casing or casing in place. A

IMPI drilling well is completed or © W^{TO THE}I know that

MEXICAN INSTITUTE of the rflei'T.rjAL ·

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(lined, lined, open hole, ^J: δ “CüSTcjuiéi &lt;5ΕϊοΓ '' known completion), a stimulation operation can be performed to enhance the production of hydrocarbons in the drilling well. Examples of some common pacing operations involve hydraulic fracturing, acidification, fracture acidification, and hydraulic blasting. Stimulation operations are intended to increase the flow of hydrocarbons from the underground formation surrounding the drill hole into the drill hole itself, so that the hydrocarbons can then be produced to the wellhead.

In some applications, it may be desirable to individually and selectively create multiple fractures at a predetermined distance from each other along a drill hole by creating multiple producing horizon zones. In order to maximize production, these multiple fractures must have adequate conductivity. Creating multiple producing horizon zones is particularly advantageous when stimulating a drill hole formation or completing a drill hole, specifically, those well bore drills that are highly offset or horizontal. The creation of such multiple zones of · producer horizon can be achieved

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MEXICAN INSTITUTE. '

OF THE PROPERTY

INDUSTRIAL using a variety of tools that may include a mobile fracturing tool with drilling and fracturing capabilities or operable sleeve assemblies placed in a tubular at the bottom of the hole.

A typical formation stimulation process may involve hydraulic fracturing of the formation and placement of a shoring agent in those fractures.

Typically, the fracturing fluid and propping agent are mixed in containers on the surface before it is pumped into the bottom of the hole in order to induce a fracture in the formation. The creation of such fractures will increase the production of hydrocarbons by increasing the flow paths in the drilling well.

However, conventional training stimulation techniques are capital intensive and often involve the use of specialized, high-speed mixing equipment while resulting in excessive wear on the pumping equipment. Additionally, conventional formation stimulation methods are time consuming and involve numerous stages and a number of different types of equipment to prepare and transfer the material used for bottom hole stimulation.

SUMMARY OF THE INVENTION

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MEXICAN INSTITUTE 01 LA l'FOP'LIJAL ·

INDUSTRIAL -

The present invention generally relates to underground operations, and more particularly, to methods and systems for stimulating a drill hole.

In accordance with an aspect of the present invention, a continuous pipe downhole assembly is provided comprising: a jet tool; a substitute non-caged ball joint attached to the jet tool; a substitute union with ports coupled to the non-caged ball substitute union; and a caged ball substitute joint coupled to the substitute port joint.

In accordance with another aspect of the present invention, there is provided a method of stimulating a formation comprising: providing a continuous pipe downhole assembly, wherein the continuous pipe downhole assembly comprises: a jet tool; a non-caged ball substitute joint having a first ball attached to the jet tool; a substitute union with ports coupled to the non-caged ball substitute union; a caged ball substitute joint having a second ball attached to the substitute joint with ports; and a spring coupled to the substitute port union, wherein the spring is operable to open and close a door of the substitute port union; placing the

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HSTlTVrO MEXICAN i DE LA MONEDA »bottom of continuous pipe in a first position in the formation; advancing circulation to a first fluid through the · continuous pipe wellhead assembly; wherein the first fluid seals the uncaged ball substitute joint; and where the first fluid closes the door of the substitute union with ports; advances circulation to a second fluid through the continuous downhole assembly when the noncage ball substitute joint is sealed; where the second fluid exits the continuous pipe downhole assembly through the jet tool; where . the second fluid creates a fracture in the formation; moving the continuous downhole assembly to a second position in the formation; where the second position is above the first position; reverse circulation to a third fluid through the continuous downhole assembly;

wherein the third fluid moves to the first ball out of the continuous downhole assembly; pump a fourth fluid through the continuous downhole assembly; where the 'fourth fluid exits the continuous downhole assembly through the port-replacement union door; pump a fifth fluid through the ring between the continuous pipe downhole assembly and the casing of the

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MEXICAN INSTITUTE j

_. . , PROPERTY training; mix the fourth fluid and the quinJtW-'Wlu treat the fracture with the mixture of c ifOTlns 'f'1' to itkr · and ·· the · fifth fluid.

In accordance with another aspect of the present invention, there is provided a method of stimulating a formation comprising: providing a casing pipe having a sleeve to removably cover one or more perforations in the casing pipe; by placing a continuous pipe downhole assembly within the casing, where the continuous pipe downhole assembly comprises: an exchange tool attached to the sleeve; a non-caged ball substitute joint having a first ball attached to the exchange tool; a substitute union with ports coupled to the non-caged ball substitute union; a caged ball substitute joint having a second ball coupled to the substitute joint with ports; and a spring coupled to the substitute port union, wherein the spring is operable to open and close a port of the substitute port union; placing the continuous pipe downhole assembly in a first position in the formation; advancing circulation to a first fluid through the continuous downhole assembly; wherein the first fluid seals the uncaged ball substitute joint;

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MEXICAN INSTITUTE

FROM PROPERTY OR where the union door replaced dW ^^ uer

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it closes when the first fluid seals the union replacing the non-caged ball; and where the first fluid activates the exchange tool to hook the sheath; moving 5 the sleeve with the exchange tool to expose one or more perforations; reverse circulation to a second fluid through the downhole assembly of the continuous pipeline; where the second fluid moves to the first ball out of the. continuous pipe downhole;

and where the second fluid disconnects the exchange tool from the sheath; moving the substitute union with ports to a position above one or more perforations;

pump a third fluid through the continuous downhole assembly; where the third fluid exits the continuous pipe downhole assembly through the port from the substitute union with ports; pump a fourth fluid through the ring between the continuous pipe downhole assembly and the casing; mix the third fluid and the fourth fluid; and treating the fracture with the mixture of the third fluid and the fourth fluid.

The characteristics and advantages of the current disclosure will be readily apparent to those skilled in the art in a reading of the exemplary embodiment description, which follows.

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MEXICAN INSTITUTE

BRIEF DESCRIPTION OF THE FIGORgy ^ gÍAL

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Some exemplary modalities (agpaffláwfcjoao - ^ e ί »description can be understood by referring, in part, to the following description and accompanying figures.

Figures IA and IB illustrate the operation of a Continuous Pipe Downhole Assembly according to a first exemplary embodiment of the present invention.

Figures 2A and 2B illustrate the operation of the Continuous Pipe Downhole Assembly of Figure 1 in accordance with an exemplary embodiment of the present invention.

Figures 3A and 3B illustrate the operation of a Continuous Pipe Downhole Assembly in accordance with a second exemplary embodiment of the present invention.

Figures 4A and 4B illustrate the operation of the Continuous Pipe Downhole Assembly of Figure 3 in accordance with an exemplary embodiment of the present invention.

Although the embodiments of this disclosure have been represented and described and are defined by reference to the exemplary embodiments of the disclosure, such references 20 do not imply a limitation of. the description, and no such limitation is inferred. The described subject matter is capable of considerable modification, alteration, and equivalents in form and function, as will occur to those experienced in the relevant art and who have the benefit of it.

1M r I description. The modalities of this description are examples of the scope of the description.

MRXICANO INSTITUTE OF PROPERTY, represented and

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only, y'fW-ΉΌ-Η-'DETAILED DESCRIPTION OF THE INVENTION

The present invention generally relates to underground operations, and more particularly, to methods and systems for stimulating a drill hole.

Returning now to Figure 1, a continuous pipe downhole assembly (CTBHA) in accordance with a first exemplary embodiment of the present invention is generally indicated by reference number 100. The CTBHA includes a jet tool · 102, a non-caged ball substitute union 104, a substitute union with ports 106, a substitute caged ball joint 108 and springs 110. The end of the CTBHA 100 near the springs 110 opens. In one mode (not shown), the surrogate join with ports

106 may include ports configured as angled slots. In one embodiment, the jet tool 102 may be a substitute hydraulic jet joint with nozzles.

A hydraulic jet tool is described in

US Application Serial Number 11 / 748,087 assigned to

Halliburton Energy Services, Inc., and incorporated herein in its entirety. Therefore, as should be appreciated

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INSTITUTO MBXICANO Di LA MOMEBA!&gt;

For those of ordinary skill in the art, with the benefit of this description, the union substituted with ports

106 it can be spring loaded (as shown) or an indexing pressure activated circulation valve.

In accordance with an exemplary embodiment of the present invention, the CTBHA 100 is decreased to a predetermined fracture interval. As it should be apparent to those of experience. Ordinary in the art, for the benefit of this disclosure, the fracture interval may be the lowest fracture interval, the surface fracture interval, or any other interval therebetween. With the CTBHA 100 in a desired location for stimulation, the stimulation process begins.

First, as described in Figure IA, a clean fluid is pumped down through the perforation of the

CTBHA 100. As should be appreciated by those of ordinary skill in the art, with the benefit of this description, a number of. Suitable fluids can be used as the clean fluid. For example, the clean fluid can be most brines, including fresh water. Brines can sometimes contain viscosity agents or friction reducers. The clean fluid can also be energized fluids such as foam brines or mixed with carbon dioxide or nitrogen, mixtures of

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INSTITUTO MEXICANO acid or oil, based fluids and fluids cJfe'ANSiSIjutufe iw clean fluid forwards circulates the bolus in the union, replaced non-caged ball 104 and moves the union replaced with ports 106 in the open position by compressing the springs 110. Consequently, the clean fluid that enters through the perforation of the CTBHA 100 exits through the jet tool 102 and the union replaced with ports

106, exiting through ring 112 between CTBHA 100 and the casing. Then, before the clean fluid fits the ball into the uncaged ball substitute union 104, the pumping speed of the fluid at uncaged ball replacement through the perforation of the CTBHA 100 is adjusted to the speed designed by the jetting operations. In one embodiment, the jet operation may be a hydraulic jet operation. Eventually, the pressure of the clean fluid adjusts the ball in the uncaged ball substitute joint 104 as described in Figure IB.

As described in Figure IB, once the ball fits into the non-caged ball substitute joint 104, fluid flow ceases through portions of the CTBHA 100 below the non-caged ball substitute joint 104, and the pressure in the springs 110 'is released, limiting the union ports replaced with ports 106. The abrasive fluid used by jetting operations is then pumped into

IMPI down the hole through the hole

MEXICAN INSTITUTE

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exits through the .fahar-ipwi-n oGomo tool^{1 1} Should be appreciated by those of ordinary skill in the art, the abrasive materials used may be sand, synthetic propping agents or garnet, typically 16/30

Mesh size API or smaller. Jetting will create 114 fractures in the formation.

As shown in Figure 2A, once connectivity for the desired production interval is established, the CTBHA 100 is lifted and the clean fluid is reverse circulated through the tool. Specifically, the clean fluid is pumped down through the ring

112 and move through the perforation of the CTBHA 100. As described in Figure 2A, the reverse flow of clean fluid moves the balls into the caged ball substitute joint 108 and the non-caged ball substitute joint 104.

The ball in the uncaged ball substitute joint 104 is held and captured on the surface. During this stage, the clean fluid also removes the trimming sand and other materials released during surface jetting.

Then, as described in Figure 2B, the downhole mixing treatment and step is carried out. At this stage, the thick mixture of the shoring agent 202 is

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de assembly ¹¹ 'δ'ΠΤ 3133'^{1 1}1Ό 8 pumps down through pressing the ball into the compressing springs 110 and opening the substitute union ports with ports 106. The thick shoring agent 202 then 'exits CTBHA 100 through the substitute union ports with ports 106. At the same time, clean fluid 204 is pumped into the hole through ring 112 and mixed with the thick shoring agent 202 exiting through the substitute port 106 joint. As should be appreciated by those of ordinary skill in the art, the thick shoring agent 202 may be any fracturing fluid capable of suspending and transporting the shoring agent in concentrations above about 5.44 kg (12 lbs) of shoring agent per gallon of fluid. In an exemplary embodiment, the thick shoring agent mixture may be LiquidSand ™ material available from Halliburton

Energy Services, Inc., of Duncan, Oklahoma and described in US Patent No. 5,799,734, which is incorporated herein in its entirety. The desired shoring agent mixture 206 is then placed into the formation. Once the desired shoring agent mixture 206 is placed into the formation, the pumping speed of the thick shoring agent mixture 202 into the .14 bore is reduced.

MAID

MEXICAN INSTITUTE

CTBHA 100 and clean fluid 204 towards e ^ aw ^ S ^ el · rSS ^ -ΪΙ ring 112 then partially open, cowbiulciirdu ·¹ Pres'preten ring surface. Then the highly concentrated liquid sand is slowly put on and a sand plug is adjusted and the pressure is tested. The CTBHA 100 then moves to the next interval that is to be stimulated and the same process is repeated.

The CTBHA 100 can be used for multi-stage stimulation of a drill hole using hydraulic jet drilling and high pump speed fluid mixing. Therefore, as will be appreciated by those of ordinary skill in the art, with the benefit of this disclosure, the CTBHA 100 allows for forward and reverse circulation of fluids in and out of the drill hole.

Figure 3A depicts a continuous pipe downhole assembly in accordance with a second exemplary embodiment of the present invention generally i ndicated by reference number 300. The CTBHA 300 includes a mechanical exchange tool 302, a non-replacement ball joint Caged 304, a substitute joint with ports 306, a substitute caged ball joint 308 and springs

310. The end of the CTBHA 300 near the springs 310 opens. In one embodiment (not shown), the surrogate junction with ports 106 may include ports configured as angled slots. How it should be appreciated

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Ordinary experience in the art, with the —bewef iei'er-'de -esfa · description, in one embodiment, the mechanical exchange tool 302 can be replaced with a hydraulic exchange tool (not shown). Therefore, the substitute union with ports 306 can be spring activated (as shown) or pressure activated. Additionally, the

CTBHA 300 includes a sleeve 312 that attaches to the mechanical exchange tool 302.

First, the CTBHA 300 is moved to a desired location that is to be stimulated and the sheath 312 is in the closed position, blocking the perforations in the casing 314. Then, as described in Figure 3A, a clean fluid is pumped down through the perforation of the CTBHA 300. The clean fluid advances circulation to the ball at the uncaged ball substitute union 304 and the substitute union with ports 306 moves into the open position by compressing the springs 310. Accordingly, the clean fluid entering through the bore The CTBHA 300 exits through the substitute union with ports 306 and through the ring 316 between the CTBHA 300 and the casing 314. The CTBHA 300 then moves down to position the mechanical swap tool 302 near the sleeve 312. With the ball

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MEXICAN INSTITUTE that completely blocks the union replaced caged ^ imSotÍmÉdo10 304, the pressure of the Clean fluid · »» ne ^ 4va ··· -ί · ο mechanical exchange tool 302, extending the drags that hook the sleeve 312 as described in the

Figure 3B.

As described in Figure 3B, once the mechanical exchange tool 302 has engaged the sleeve 312, the CTBHA 300 moves upward, exchanging the sleeve 312 to the open position and exposing the ports in the casing 314.

Then, after confirming connectivity to the production interval, the CTBHA 300 is moved upward as described in Figure 4A, and the clean fluid is reverse circulated through the CTBHA 300. Accordingly, the clean fluid is pumps to the downhole through the ring

316 and it moves up through the perforation of the

CTBHA 300, relaxing spring 310 and moving the ball up in the caged ball substitute joint 308.

Additionally, the clean fluid moves the ball from junction 20 to noncage ball 304 to the surface.

Finally, as described in Figure 4B, the mixing step is carried out inside the treatment well. At this stage, the thick shoring agent mixture 402 is pumped down through the perforation of the CTBHA 300

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MEXICAN INSTITUTE f 1

KLAW&gt; R £ í&gt; AU pushing down the ball in the caged socket 'Έσϊ'5' 308, compressing the springs 310 and opening the * doors of the union replaced with ports 306. With the ball that seals the union replaced ball In cage 308, the thick shoring agent 302 mixture then pulls the CTBHA 300 through the junction gates replaced with ports 306.

At the same time, clean fluid 404 is pumped into the hole through ring 316 and mixed with the thick shoring agent mixture 402, with the mixture 406 exiting through the joint replacing ports 306. As should be appreciated by those of ordinary skill in the art, the thick admixture of proppant 402 can be any fracturing fluid capable of suspending and transporting the proppant at concentrations above about 5.4 kg. lbs) of shoring agent per 3,785 1 (1 gallon) of fluid. In an exemplary embodiment, the thick shoring agent mixture may be LiquidSand ™ material available from Halliburton Energy

Services, Inc., of Duncan, Oklahoma and described in

US Patent number 5,799,734, which is incorporated herein in its entirety. The desired shoring agent mixture 406 is then placed into the formation. Once the desired shoring agent mixture 406 is placed into the formation, pumping the 'thick agent mixture iMPiágg ^

MEXICAN INSTITUTE OF PROPERTY shoring 402 towards the drilling of the CTBHA ^I9W^yesand c ^ a- ^ 1 clean fluid 404 towards ring 316. -

Finally, in one embodiment, the CTBHA 300 can be moved down (not shown) and the ball for the non-caged ball substitute junction · 304 can be moved forward toward the CTBHA 300. The ball is then placed in the substitute junction of non-caged ball 304. The CTBHA 300 can then be pressurized, which extends the pulls of the mechanical swap tool 302 which hooks the sleeve 312 and moves to the closed position. The CTBHA 300 can then be moved to another interval which is to stimulate itself and the CTBHA can again be pressurized, extending the pulls of the mechanical swap tool 302 which engage the sheath 312 and move to the open position to establish connectivity to a second productive interval to treat.

The CTBHA can be used for multi-stage stimulation of a drilling well using hydraulic jet drilling and high pump speed fluid mixing. Therefore, as will be appreciated by those of ordinary skill in the art, with the benefit of this disclosure, the CTBHA allows for forward and reverse circulation of fluid in and out of the drill hole.

As would be appreciated by those of ordinary experience

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ΙΝϊΠΤυΤΟ MEXICAN in the technique, with the benefit of estS^ILAií ^ &amp; í^,átip&gt; e! H ^^ * any suitable pump can be used in addition to clean fluid, abrasive fluid, or downhole mixing agent. For example, the material can be pumped down into the hole using a hydraulic pump, a peristaltic pump, or a centrifugal pump.

Additionally, as should be appreciated by those of ordinary skill in the art, for the benefit of this disclosure, although in an exemplary embodiment, the springs are used to adjust the openings of the surrogate junction with ports, in another embodiment, the openings may be adjusted manually.

Therefore, the present invention is well suited to carry out the objectives and achieve the aims and advantages mentioned as well as those that are inherent in this. Although the invention has been represented and described with reference to the exemplary embodiments of the invention, such reference does not imply a limitation on the invention, and without such limitation it is to be inferred. The invention is capable of considerable modification, alteration, and equivalents in form and function, as will occur to those ordinarily experienced in the relevant techniques and who have the benefit of this disclosure. The depicted and described embodiments of the invention are exemplary only, and not

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INSTITUTO MEXICANO Dt THE PROPERTY are exhaustive of the scope of the '^ fWénc ^ Óivr Consequently, the invention is intended to be limited only by the scope of the appended claims, giving full knowledge to equivalents in all aspects. The terms in the claims have their ordinary, straightforward meaning unless explicitly and clearly defined otherwise by the patent.

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INSTITUTO MAXICAND DE LA P »OPIÍDAn

INDlWmiAL

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