MXPA06001531A - A method of suspending, completing and working over a well - Google Patents
A method of suspending, completing and working over a wellInfo
- Publication number
- MXPA06001531A MXPA06001531A MXPA/A/2006/001531A MXPA06001531A MXPA06001531A MX PA06001531 A MXPA06001531 A MX PA06001531A MX PA06001531 A MXPA06001531 A MX PA06001531A MX PA06001531 A MXPA06001531 A MX PA06001531A
- Authority
- MX
- Mexico
- Prior art keywords
- well
- casing
- barriers
- barrier
- pipe
- Prior art date
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Abstract
In the various methods of the present invention, reliance is placed on a first and second barrier (26) and (30) respectively positioned in a well (10) to provide well control during well suspension, completion and/or workover operations. Each of the barriers is below the depth of the lowermost end of a completion string when that string is installed in the well (10). By not placing either barrier higher up in the well-bore, both of the barriers can remain in place during suspension and completion and workover operations, thus obviating the need to use a BOP stack to supplement well control. This results in a considerable saving in drill rig time and thus significantly reduces the cost of constructing a well.
Description
A METHOD TO SUSPEND, COMPLETE AND WORK ON A WELL
FIELD OF THE INVENTION The present invention relates to a method for suspending, finishing or reconditioning a well and especially, but not exclusively, to a method for suspending, finishing or reconditioning a well while maintaining at least two fixed barriers. in deep. The present invention also relates to a suspended or finished well provided with at least two depth-fixed barriers. The methods of the present invention refer to any type of well, including subsea wells, wells in platforms and wells on land. The present invention especially relates, although not exclusively, to wells used for oil and / or gas production, and gas and / or water injection wells.
BACKGROUND OF THE INVENTION In order to provide adequate control of the well and to comply with the legal safety requirements of many of the jurisdictions worldwide, most operating companies adopt the principle of ensuring that at least two barriers verified in the independently they are in place at all times during the construction or suspension of wells. The term "barrier", as used throughout this specification, refers to a physical measure capable of forming a seal to prevent a release or uncontrolled flow of liquid from the pressure side of the barrier. Well construction operations include all activities from the time the well is drilled until it is completed and ready for production through the installation of a production flow control device. The most commonly used production flow control device is typically referred to as "connection trees." During the construction of a well from the moment you can install and verify at least two barriers in the hole of the well can be said that such a well is "suspended". A well can not be temporarily suspended or permanently abandoned without making sure that the two independently verified barriers required are at least in place. From moment to moment, during the life of a well in production, it is required to take corrective measures such as repairs or maintenance. Such operations of corrective measures, including interventions, in the present description are called "conditioning operations". When a conditioning operation is needed, once again, it is generally a legal safety requirement of many jurisdictions in the world, that at all times at least two independently verified barriers are installed. Frequently, a plurality of wells are constructed to take advantage of a reservoir or a given oil and / or gas formation. Depending on the geology of the particular site, as well as the requirements established by the programming, it is common for one or more of the wells to be temporarily suspended for a period of time. These suspended wells can be re-entered and can be completed as productive wells or in development at a later date. In some places, each well is drilled and completed in a sequence. In other places, well construction operations can be carried out "in batches". When done in this way, the well construction processes are carried out following differentiated steps. For example, a first sequence of steps is performed in a number of wells, followed by a second sequence of steps that will be performed in such wells. The process is repeated until each well is completed. The batch system is used to allow the logistic optimization of the well construction operations or for the completion operations to be carried out by using a drilling tower or a different vessel, usually smaller, than the one used for the initial drilling. Typically, the first step in the construction of a well involves drilling a hole for the well. Figure 1 illustrates an example of a typical 1 0 submarine well that was drilled but not yet suspended. With reference to Figure 1, the well 10 is provided with a head of the well 1 1 and a guide base 12. A stack of submarine BOP 40, like the marine pipe 42 associated therewith, is positioned in the head of the well 1 1 to provide well control during the drilling operation. Subsequently, well control is achieved by placing at least two barriers independently verified elsewhere. Drilling continues to expand the well diameter and the casing strings are sequentially installed in the well 10. In the example illustrated in Figure 1, a first casing string 14 having a nominal size of 76.2 centimeters is installed first. A second string of casing 16 having a nominal size of 50.8 centimeters is run with the well head 1 1 and cemented in position. A third string of the casing 1 8 having a nominal size of 33.9725 centimeters is provided in the second string of the casing 16. A fourth and last string of casing 20 having a nominal size of 54 μm. third coater strand 18. In the case of platform wells, coater strings may extend over the mud line or sea floor to the floor of drill tower 46 or drilling platform 44. The well head is typically located at the highest point of the well hole in the mud line in the case of subsea wells, at the level of the platform in the case of platform wells or at sea level in the case of the wells on land. After the required amount of casing strings has been installed, it is common, but not essential, for a casing 22 to be installed which is a set of coupled tubes extending to the surface. The coater is typically suspended from a casing hanger 24 installed within the lower casing string 20. During the drilling of a well, it is common to maintain a sufficient hydraulic fluid load in the hole of the well to provide a superior equilibrium relative to the pressure expected to exert the reservoir or the formation in which the well is drilled. When the well must be suspended, other barriers must be provided. The requirement that a second barrier be in place at all times must be met during drilling and casing operations by placing a BOP burst controller assembly on top of the well. Some of the casing strings, the casing, the casing pendant, the first barrier and the completion string run through the hole in the BOP stack. In the case of subsea wells that do not use a surface BOP stack, the equipment used in the well should also be used through the marine pipe hole associated with the submarine BOP stack.
To accommodate the descent of the equipment that is used in the well through the BOP stack, the hole in the BOP stack typically has an inside diameter of 45.72 centimeters and is therefore an extremely large piece of equipment. In the case of subsea wells, the time it takes to place and / or remove the BOP stack depends on the distance between the water line and the mud line, and in deep water this task can take several days. The economic viability of marine operations depends directly on the time taken by the modality of the different construction operations. In this way, the descent and removal of a BOP stack is considered to be one of the most costly operations related to the construction of subsea wells. If existing methods are applied in the art, a first barrier, "B 1" is typically placed above the reservoir or formation, as illustrated in Figure 2. If the well should be suspended, a second barrier, " B2", must be established and verified in another place in the well hole before the BOP battery can be removed. It is a long-standing issue and practice in the highly accepted industry to position the second required barrier, B2 towards the upper end of the well hole and typically at the head of well 1 1 or at the highest end of the well string. finishing coater 20, with reference to Figure 2. This second barrier, B2 traditionally took the form of a cement plug. However, in recent times, this cement plug was replaced by the use of mechanical barriers to overcome the cleaning problems that relate to the removal of cement plugs. Among the different types of mechanical barriers that are used as the second barrier include attachable or removable devices by the drill pipe such as plugs or shutters. There are several factors that motivate the operating companies to place a second barrier towards the top of the well. One of the key reasons is the reduced cost of the placement and / or removal of the second barrier, when it is located at the highest point of the hole in the well. It is also widely accepted that the barriers, first and second, should be placed as widely as possible, to facilitate the verification of each of them independently. If the barriers, first and second, are placed very close, it has been considered almost impossible to verify the integrity of the second barrier independently of the first. The integrity of the first barrier is verified by filling the hole in the well with a fluid and pressurizing the fluid string until a certain pressure is reached. Due to the compressibility of the fluid or trapped gas, the pressure typically falls after a short period of time before being re-leveled. If the barrier presents losses, then the pressure does not reach level. This procedure is repeated after the installation of the second barrier. When the second barrier is positioned at the highest end of the wellbore, the amount of fluid needed to pressurize the wellbore during the evaluation of the pressure drops significantly if the second barrier has the necessary integrity. In this way, it is easy to detect if the fluid is passing through this upper barrier. For the purpose of preparing a well for production, a "completion string" is installed in the hole of the well. The term "completion string", as used throughout this description, refers to the pipe and equipment that is installed in the hole in the well to allow production from a formation. The upper end of the completion string typically ends in and includes a hanging support of the pipe from which the completion string hangs. The completion string typically includes an annular production obturator located toward the lower end of the completion string. The plug isolates the hole ring from the well from the completion string, the ring being the space through which the fluid can flow between the completion string and the coater string and / or the coater. The lower end of the completion string is usually referred to as the "tail tube". When the well is ready for production, the oil, water and / or gas passes through the casing or coater and through the termination coater to a production flow control device located in the header of the casing. well or over this.
The methods of suspension of the wells existing in the technique require the extraction of the upper barrier before the well can be finished. In order to supply the second required barrier, the BOP stack must be reinstalled on the well, in what has been a long-standing practice and commonly used in the industry. You can not remove the BOP stack until at least two barriers are established somewhere. The requirement to install a BOP stack generates several drawbacks. First, the operations that must be performed before the BOP stack extraction should be limited to tools that can pass through the internal diameter of the hole in the BOP stack. Secondly, the hole in the BOP stack (and its marine piping for subsea wells) may contain debris such as shavings, cement and / or debris in the hydraulic arrietes or in the annular cavities of the BOP stack, as well as debris in the drilling and / or purging lines and / or corrosion product in the marine pipeline. Consequently, one of the problems with the current well construction practice is the high level of debris that accumulates as the completion string and other equipment pass through the hole in the BOP stack and / or its marine pipeline. . Third, the need to move or remove the BOP stack during well construction operations can add a significant expense to the cost of these operations, since the costs are directly proportional to the amount of drilling time that must be attributed. to these operations.
There is a need for a method for the construction of wells that requires less time and therefore is less expensive. It will be clearly understood that, although reference is made to the prior art herein, this reference does not constitute an admission that what is contained herein is part of general knowledge in the art, in Australia or in another country. In the brief description of the invention and in the description and claims that follow, except when the context requires otherwise due to the words expressly used or because it is necessarily implicit, the word "characterized" and its variations such as "characterized because" they are used with an inclusive sense, that is, to specify the presence of the established characteristics but does not prevent the presence or the addition of other characteristics in several of the embodiments of the invention.
BRIEF DESCRIPTION OF THE INVENTION The present invention is based on an advanced modality so that well construction operations can be radically simplified by positioning at least two verifiable barriers independently below the lower end anticipating the string. of completion. By not placing any of the barriers higher up in the hole of the well, both barriers can remain in place during the suspension and termination operations, and thus, the need to use a BOP stack is avoided. complement the control of the well. This causes a significant saving in drilling time and thus reduces the cost of building a well significantly. The term "barrier" as used throughout this specification refers to a physical measure capable of forming a seal in a manner that prevents a release or uncontrolled flow of fluid from the pressure side of the barrier. To fulfill the barrier function, the physical measurement must be able to keep its position in the hole of the well. The barrier does not necessarily have to be removable. A variety of physical measurements may be used in combination to provide the barrier, with one or more of the measures serving as a sealant and one or more other measures that are used to secure the barrier in position, typically against an external wall. from one of the coater or coater strings. The expression "barrier fixed at depth" as used throughout this description, refers to the barrier that is below the depth of the lower end of a pipe string (typically hanging from a hanging support of the pipe or other equipment) when the pipe string is installed in its final position in the water well. The term "BOP stack" as used in the present description includes both surface BOPs and submarines. The BOP stack would typically comprise a combination of blind hydraulic pipes and arrietes, annular preservatives, injection lines and purge lines and may include a connector at the lower end and an ascending and / or rising marine pipeline. According to one aspect of the present invention, a method for suspending a well is provided: providing a first barrier in the well; verify the integrity of the first barrier; providing at least one second barrier in the well at a location above the first barrier to define a space between the first barrier and the second; and, verify the integrity of the second barrier; the barriers, first and second, are below the lower end of a completion string when the completion string is installed in the well and retains its position while the well is suspended. Preferably, the verification of the integrity of the second barrier further comprises the measurement of the pressure existing in the space between the first barrier and the second. Preferably, a barrier or both, the first and the second, is selected from the group consisting of: a cement plug; an undrilled casing; a section of an undrilled casing; a top valve of the coater; a bridge plug; expandable plug; a stopper of disappearance; a rupture disk; and / or an inflatable cap. One or both, the first and second barrier, may be provided as a combination of a physical device, a means for securing the physical device in position in the well, and a sealing means. Preferably, the sealing means is selected from the group consisting of: a ball valve; clapper valve; a sliding shirt; pressure cyclic plug; recoverable plug by fastener; a rupture disk; an insulation-forming device; a cutting disc; an open pump device. The sealing means can be placed separately from the physical device or in the same location. Preferably, the method further comprises installing a first casing hanging support or a first casing hanging support and a second casing hanging support in the well. More preferably, one or both of the barriers, the first and the second, are provided in the first casing hanging support or in the second of them. Alternatively or additionally, the method further comprises the installation of a first coater or a first coater and a second coater in the well. More preferably one or both barriers, the first and the second, are provided in the first coater. Preferably, the well comprises at least one string of the casing and the first and / or the second barrier are provided in the at least one string of the casing.
According to a second aspect of the present invention, there is provided a method for terminating a well comprising: providing a first barrier in the well; verify the integrity of the first barrier; then, provide at least one second barrier in the well at a location above the first barrier so as to be able to define a space between the first barrier and the second; verify the integrity of a second barrier; the support in the first barrier and in the second to provide control of the well during the installation of a completion string in the well, the completion string has a lower end; and, installing a production flow control device in the well to regulate the flow of fluids through the well; The barriers, first and second, are below the lowest point of the completion string when the completion string is installed in the well. Preferably, the method further comprises installing a pipe reel in the well head before the installation step of the completion string in the well. The production flow control device can be a connection tree. Preferably, the production flow control device is a horizontal connection tree. More preferably, the horizontal connection tree includes a body, the completion string ends at its highest end and is suspended from a pipe hanging support, and the method further comprises the step of forming an assembly comprising the connection shaft horizontal and the hanging support of the pipe by supporting and closing the hanging support of the pipe in the body of the horizontal connecting shaft before the installation step of the production flow control device of the well. Alternatively, the connection tree is a vertical connection tree. According to a third aspect of the present invention, a method for conditioning a finished well is provided. The finished well includes a production flow control device and a completion string installed in the hole of the well, being that the completion string has an upper end that ends in a hanging support of the pipe from which the completion string hangs and a lower end, the method comprises: providing a first barrier in the well; verify the integrity of the first barrier; and then providing at least one second barrier in the well at a location above the first barrier to define a space between the first and second barriers; verify the integrity of the second barrier;
the support at the first and second barriers to provide control of the well during the extraction of the hanging support from the pipeline, the completion string, and / or the production flow control device from the well; and the method characterized in that the first barrier and the second one are deeper than the lower end of the completion string, in cases where the completion string is installed in the well. Preferably the horizontal connection shaft comprises a body and the method for conditioning the well further comprises the step of extracting the suspended pipe support and / or the completion string from the body of the horizontal connection shaft by unlocking the hanging support of the pipe from the Body body production of the horizontal connection tree. Alternatively, the horizontal connection tree comprises a body and the method for conditioning the well further comprises extracting the horizontal connection tree and the completion string as an assembly. Preferably, the well conditioning method further comprises the passage resting on the first and second barriers to provide control of the well up to both the hanging support of the pipe, the completion string and / or the flow control device of production are reinstalled in or on the well. According to a fourth aspect of the present invention there is provided a suspended well comprising;
a well hole having an upper end; a wellhead installed towards the upper end of the hole in the well; and at least one first and second barrier independently verified spaced apart in the hole of the well to define a space between the first and second barriers; the barriers, first and second, are below an anticipated depth of the lower end of a completion string when the completion string is installed in the well. According to a fifth aspect of the present invention, there is provided a finished well comprising: a well hole having an upper end; a well head installed to the upper end of the hole in the well; a production flow control device in or on the wellhead; a completion string installed in the hole of the well and having a lower end; and, at least a first barrier and a second barrier independently verified both spaced apart in the hole of the well to define a space between the barriers, first and second; The barriers, first and second, are below the lower end of the completion string. Preferably, the suspended or finished well further comprises a means for measuring the pressure that generates a signal indicating the pressure in the space between the first and second barriers. More preferably, the suspended or completed well further comprises a signal receiving means generated by the means for measuring the pressure. More preferably still, the suspended or completed well comprises means for transmitting the signal of the medium for measuring the pressure to the receiving medium of the pressure signal. Preferably, the means for measuring the pressure is a transducer. The suspended or finished well can be an underwater well, a well on the mainland or a platform well. Preferably, the suspended or finished well further comprises a first coater or a first coater and a second coater installed in the well. More preferably, one or both of the barriers, the barriers, first and second, are within the first or second coater. Preferably, the suspended or finished well includes at least one string of the casing and one or both of the barriers, first and second, are provided within the at least one string of the casing. Preferably, the completed well further comprises a pipe reel installed in the wellhead. Preferably, the production flow control device is a connection tree. More preferably, the production flow control device is a horizontal connection tree. Alternatively, the production flow control device is a vertical connection tree. According to a sixth aspect of the present invention, a double barrier system is provided for use in the suspension, termination or conditioning of a well, the double barrier system comprising: a first and a second barrier body positioned in a spaced relation in the well that defines a space between the barriers, first and second; a device for measuring the pressure that generates a signal indicating the pressure existing in the space between the barriers, first and second; a receiver of the pressure signal that receives the signal generated by the devices that measure the pressure; and, a transmitter that transmits the signal from the device that measures the pressure to the receiver of the pressure signal. According to a seventh aspect of the present invention, there is provided a method for terminating a subsea well using a horizontal connection tree for the control of the production flow, such a connection tree having a body, the method comprising: the formation of a assemble by installing a completion string that at its upper end terminates in and is suspended from a pipe hanging bracket on the body of the horizontal connecting shaft; and, run the assembly in the submarine well; The hanging support of the pipe and the horizontal connection shaft are above sea level during the formation of the assembly. Preferably, the formation of the assembly further comprises supporting and securing the hanging support of the drill pipe in the body of the connection shaft. More preferably, the method of terminating a subsea well using a horizontal connection shaft for flow control of Production also includes verification of the integrity of the completed assembly above sea level. Preferably, the integrity check comprises the verification of the hydraulic and electrical interfaces between the hanging support of the pipe and the body of the connection shaft. More preferably, the verification of the integrity further comprises the verification of the integrity of the assembly pressure. . Preferably, running the assembly to the wellhead comprises the use of a riser package.
BRIEF DESCRIPTION OF THE DRAWINGS Preferred embodiments of the present invention will now be described, by way of example only, with reference to the accompanying drawings, in which:
Figure 1 illustrates a typical well drilled before its suspension by applying the existing well suspension method in the art; Figure 2 illustrates a well suspended in accordance with a prior art well-used slurry method in the art; Figure 3 illustrates a first step in the completion sequence of a well of a first embodiment of the present invention showing the location of the casing strings and the casing as well as dual barriers set at depth with BOP stack in position; Figure 4 illustrates a next step in the termination sequence of a well of a first embodiment of the present invention showing a suspended well with dual barriers set at depth; Figure 5 illustrates a modality of a double barrier system that is used to suspend a well; Figure 6 illustrates a next step in the completion sequence of a well according to the present invention showing the partial formation of the HXT / TH assembly after suspending the well according to Figure 4; Figure 7 illustrates a next step in a well termination sequence according to the present invention showing the use of an LRP to place the HXT / TH assembly in the wellhead; Figure 8 illustrates a next step in a completion sequence of a well according to the present invention showing the HXT / TH assembly in position in the wellhead; Figure 9 illustrates yet another step in the completion sequence of a well according to the present invention which shows the installation of dual barriers in the hanging support of the drill pipe and / or top of the tree or assembly which combines the hanging / lid support assembly; Figure 10 illustrates a final step in a completion sequence of a well according to the present invention showing a finished well with double barrier in the hanging support of the pipe and the top of the hanging support of the pipe; Figure 1 1 illustrates a step in a completion sequence of a well of a first embodiment of the present invention for a well using a vertical connection tree for production flow control, which shows the use of THRT and a mechanism of orientation to guide, support and secure the hanging support of main pipe in the head of the well; Figure 12 illustrates a next step in a well termination sequence of a first embodiment of the present invention showing a vertical connection tree with LRP and EDP prepared on the drilling platform; Figure 13 illustrates yet another step in a well termination sequence of the first embodiment of the present invention that shows the well after the vertical connection tree, LRP and EDP were installed on the suspended main pipe support; Figure 14 illustrates a next step in a well termination sequence of a first embodiment of the present invention that shows the well when the depth-fixed barriers were removed with support in the flow control valves of the vertical connection shaft and / or the LRO assembly to meet the legal requirement of having at least two verifiable barriers; Figure 15 illustrates the finished well of the first embodiment of the present invention with a tree cover in place; Figure 16 illustrates a step in a completion sequence of a well according to a second preferred embodiment of the present invention showing the location of a pipe reel in the well head after suspending the well according to Figure 4; Figure 17 illustrates a next step in a well termination sequence of a second embodiment of the present invention that shows the use of THRT and orientation mechanism to orient, support and secure the suspended pipe support on the pipe reel; Figure 1 8 illustrates a next step in a completion sequence of a well of a second embodiment of the present invention that shows the vertical connection tree with LRP and EDP prepared on the drilling platform while maintaining the two barriers placed at depth. Figure 19 illustrates yet another step in a well termination sequence of a second embodiment of the present invention that shows the well after installation of the vertical connection shaft, LRP and EDP on the hanging support of pipe production with the barriers deep fixed and extracted and the support placed on the flow valves in each vertical hole of the vertical connection shaft and / or LRP assembly; and, Figure 20 illustrates the finished well of the second embodiment of the present invention with a tree cap in place; and Figures 21 to 23 illustrate alternative modes of double barrier systems to that illustrated in Figure 5.
DESCRIPTION OF THE PREFERRED MODALITIES Before the preferred embodiments of the present invention are described, it is understood that the present invention is not limited to a particular sequence or to the types of barriers described. It should also be understood that the terminology used herein is for the sole purpose of describing particular modalities only, and that the scope of the present invention is not intended to be limited by such terminology. Unless otherwise defined, all the technical and scientific expressions used herein present the same meanings commonly used by a person skilled in the art to which the present invention pertains. Although other types of barriers and special well terminations and / or conditioning sequences similar or equivalent to those described herein can be used for the purpose of practicing or evaluating the different aspects of the present invention, the barriers and the methods that are preferred are described at this time with reference to the suspension, termination and conditioning of a submarine well. It should be clearly understood that the present invention is equally applicable to wells on land and to platform wells. It should be noted that Figures 1 to 20 are not to scale and that the length of several of the sets of coupled, casing and / or casing tubes will vary depending on the requirements of each particular location, such as the depth of the water per envelope. the mud line and the depth and geology of the reservoir or of the particular formation that is drilled. As an example, in the case of submarine wells the mud line can be found in the order of 20 to 3000 meters below sea level and the reservoir or formation would be in the order of one to three kilometers below of the mud line. Also, it should be noted that the subsea connection tree of the example illustrated in Figures 3 to 10 is a type of mono perforation, while the connection tree illustrated in Figures 1 to 15 and 17 to 20 is a type of double hole tree. It should be clearly understood that different aspects of the present invention apply equally to single hole wells as well as double hole ones. A first mode of the one-well suspension method is illustrated in the sequence of Figures 3 and 4. With reference to Figure 3, a 1 0 underwater well has been drilled and supplied with a wellhead 1 1 and a guide base 12. A BOP 40 submarine stack, like the associated marine pipe 42, is positioned at the wellhead 1 1 for temporary well control. Subsequently, well control will be achieved by placing at least independently verified barriers somewhere. A necessary quantity of casing strings is installed in the well. In the embodiment illustrated in Figure 3, a first string of the casing 14 with a nominal size of 76.2 centimeters is installed first. A second string of casing 16 with a nominal size of 50.8 centimeters is run with the well head 1 1 and cemented in position. A third string of casing 18 having a nominal size of 33.9725 centimeters is provided in the second string of casing 16. A fourth and last string of casing 20 having a nominal size of 24.4475 centimeters is provided within the third casing 18. It should be Understand that while Figure 4 illustrates four strings of the concentric casing, the present invention is equally applicable to subsea wells with any other number of casing strings of other nominal sizes, as necessary. With reference to Figure 3, then a casing 22 is installed within the string of the final casing 20. The casing 22 hangs from a first casing hanging support 24. It should be understood that while a casing 22 and a casing hanging support 24 are used in the modality illustrated in Figure 3, the method of suspension of a well is equally applicable to wells that do not use casing coaters or hanging supports. A first deep-seated barrier 26 is installed in the first casing hanging support 24 and / or first casing 22. Then the integrity of the first barrier 26 is verified. Then, a second casing hanging support 28 ther with a second casing 23 it is positioned in the end casing string 20 on the first casing hanging support 24, and thus defines a space 35 between them. A second depth-fixed barrier 30 is placed on the second casing hanging support 28 and / or the second casing 23 and the integrity of the second barrier 30 is verified independently. A preferred embodiment for the provision of the two independently fixed depth-verified barriers in the form of a double barrier system 32 is illustrated in Figure 5. With reference to Figure 5, the first barrier 26 is provided by the combination of a physical measurement in the form of a first plug 25 and a separate sealing means in the form of a first annular seal 27. Then, the first plug 25 is secured in position and forms a seal through the hole of the first hanging support coater 24 and / or of the first coater 22. The first annular seal 27 is provided with the first coater pendant 24 and / or the first coater 22 to form a seal between the outer diameter of the first coater pendant 24 and / or the first coater 22 and the internal diameter of the pipe of the final coater 20. The integrity of the first barrier 26 is then verified by using the techniques that are known. The second barrier 30 of the double barrier system 32, as illustrated in Figure 5, is provided by, first, the installation of a second casing hanging support 28 ther with a second coater 23 on the first casing hanging support 24 defining so a space 35 between them. The second barrier 26 is provided by the combination of a physical measurement in the form of a second plug 27, typically a removable plug per fastener, and a separate sealing means in the form of a second annular seal 29. The second plug 27 is secure in position in and forming a seal through the hole of the second casing hanger 28 and / or second casing 23. The second annular seal 29 is provided with the second casing hanger 28 and / or the second casing 23 to form a seal between the outer diameter of the second casing hanging support 28 and / or the second casing 23 and the inner diameter of the string of the final casing 20.
The integrity of the second barrier 30 can then be verified. It was previously considered that the barriers supported above to provide control of the well during the completion and / or conditioning operations should not be positioned close to each other, as mentioned above. This happens because it is considered that it is difficult to verify the independence of the second barrier if the space between the two barriers has a relatively small volume. Such a problem is solved in the embodiment illustrated in Figure 5 by providing a device for measuring the pressure in the form of a pressure transducer 34 in the space between the barriers, first and second. The pressure transducer 34 is capable of generating a pressure indicating signal in the space 35. The signal of the pressure transducer 34 is transmitted by the use of any suitable means such as a wireless signal, a breakable wired connection or a wired line disconnectable to a pressure signal receiver. In the embodiment illustrated in Figure 5, the pressure signal receiver 36 is incorporated in a tool that runs the plug 38 in electrical communication with a means for interpreting the pressure signal [not shown] positioned above sea level , typically with access on the floor of the drilling tower 46 and less preferably on the drilling platform 44. It should be understood that the pressure transducer 34 does not need to be provided with the second barrier 30, the only condition being that the pressure transducer 34 is capable of generating a signal indicator of the pressure in the space between the barriers, first and second. The pressure transducer 34 can then be positioned equally on an upper surface of the first barrier, on an internal diameter of the casing hanging support or on an internal diameter of a section of the lower casing tube. In practice, the signal from the pressure transducer 34 is received and interpreted by the pressure signal receiver 36 which allows independent verification of the integrity of the second barrier 30 after the integrity of the first barrier 26 was verified independently. The placement of at least two independently verifiable barriers within the hanging casing supports in the preferred embodiment represents a way of placing these barriers. There are other options for providing a first and a second barrier for the double barrier system as described below with reference to Figures 21, 22 and 23. In Figure 21, the first [lower] barrier 26 is already provided either with an upper cladding isolation device, a multi-action reciprocal device, a ball valve or flapper valve that forms a barrier across the full width of the casing hole 22. The second [upper] barrier 30 is provided in the form of a mechanical device such as a removable plug per fastener also installed in the first casing 22.
In Figure 22, the first barrier 26 is provided in the form of a removable plug by full-hole fastener or a cement plug in the first coater 22. The second barrier 30 is provided in the form of an upper coiler insulation device, a multi-action reciprocal device, a ball valve or flap valve also installed in the first coater 22. In Figure 23, the first barrier 26 is provided in the form of a removable plug with full-hole wire line or with cement in the first coater 22. The second barrier 30 is provided by a removable plug per fastener or cement plug installed to seal through the entire hole of the string of the final coater 20. In this manner, the first and / or the second barrier can can be selected equally from the group consisting of: a cement plug; a coater - without drilling; a section of an undrilled casing; a top valve of the coater; a bridge plug; expandable plug; a stopper of disappearance; a rupture disk; and / or an inflatable plug packer. Either one or both of the first and second barriers can be provided by using a combination of means to secure the position of a seal and a separate sealing means. The means for securing the position of the seal and the sealing means need not necessarily be found in the same position in the casing, the casing and / or the casing hanging support. Suitable means for sealing include, but are not limited to the following: a ball valve, a flapper valve; a sliding shirt; a cyclic pressure stopper; recoverable plug by fastener; a rupture disk; an insulation training device; a cutting disc; and / or an open pump device. A hydrostatic column of fluid in the hole of the well can be considered sufficient to serve as one of the barriers, provided that the level of the fluid string can be monitored and filled to the top if necessary. This option can be used to terminate a well according to the preferred embodiments of the present invention. However, while in order to facilitate the installation of the completion string in the depth of the well it would not be necessary to remove a hydrostatic column of fluid, the support in such a barrier is typically not acceptable, especially for the suspension of a well, except that is used for a training that has a training pressure below normal. Once the well 10 is provided with two independently fixed depth-checked barriers 26 and 30, the BOP stack can be removed and removed to the drill tower. The well, as illustrated in Figure 4, can now be considered to be suspended. The well can be completed at this time or it can be left in the conditions it is in for completion after a period of time.
An advantage of being able to suspend the well in this state, that is to say with the first and second barriers, fixed in depth in position, is that for the first time it would be possible to install the completion string in the well without the need of having a pile of BOP to provide one or both barriers. Another advantage of being able to suspend the well in this state with at least two depth-fixed barriers is that it is possible to drill and suspend a number of different wells at a particular location on a formation using the type of drilling rigs that place the pile of BOP 40 and other distribution pipes for the casing, casing and finishing strings. When a plurality of wells were suspended, as illustrated in Figure 4, the BOP stack 40 is no longer needed and the drilling equipment can be moved to another location. In addition, by drilling and suspending a plurality of wells by using the embodiments of the present invention, the BOP 40 stack can be moved laterally [underwater] from one well to the next well and not necessarily be removed to the set to the drilling tower between wells. Then, there is the potential for the completion of the suspended wells by using a smaller vessel than is normally needed for the installation of the hanging support of the pipe and the connection shaft
Another advantage of being able to suspend the well in the manner illustrated in Figure 4 is that it is possible to perform the spacing measurements of the hanging support of the coater by ROV while the well is suspended when necessary. The sequence of steps used to complete a well ready for production depends in part on the type of production flow control device or connection tree that was chosen to control the flow of the well during production. It should be understood that the embodiments of the present invention are not limited to the particular device type that is used to control the flow of fluids from and / or to the well. Generally speaking, Christmas trees are classified, namely, trees with horizontal connections and trees with vertical connections. Next, a method for finishing and / or conditioning an underwater well using a horizontal connection tree as a device for controlling the production flow is described. A typical method of existing technique for finishing a well using horizontal Christmas trees is based on the following sequence of steps: a) a BOP stack is used to provide control of the well while the well is drilled and encamised and a casing is [optionally] installed; b) a first barrier is placed in its place in the general zone on the formation or the reservoir; c) the integrity of the first barrier is verified; d) then, the second barrier is positioned towards the upper end of the hole in the well or in the head of the well; e) the integrity of the second barrier is verified; f) then, the BOP battery is removed from the well head to facilitate the installation of the horizontal connection shaft in the wellhead; g) then, the BOP stack is run again and positioned in the horizontal connection tree to provide control of the well when the second (upper) barrier is removed to facilitate the passage of the completion string through the hole in the well; h) a tool for running the hanging support of the pipeline is used in combination with a submarine test shaft [SSTT] to run the completion string suspended from a hanging support of the pipeline pipe through the inner hole of the stack of BOP and its marine pipeline; i) the hanging support of the pipe is oriented, supported and fixed inside the body of the horizontal underwater connection shaft; j) the lower barrier is removed; k) a new barrier is provided in the suspended support of the pipeline and verified; I) a second new barrier is positioned over the first, typically in an internal tree cap and verified; and, m) when the integrity of the barriers, first and second, both new, was verified, the BOP stack can be extracted and the well is ready to produce. One embodiment of the well termination method of this aspect of the present invention, for wells using a horizontal connection shaft as a production flow control device, is illustrated with reference to the suspended well. Figures 3, 4 and 6 10. An underwater well 10 is drilled and suspended as described above with reference to Figures 3 and 4. With reference to Figure 6, a horizontal shaft 50 is positioned on the drilling platform 44 below the floor of the floor. the drilling tower 46. A hanging support of the drill pipe 60 was installed inside the body of the horizontal connection shaft 50. From the hanging support of the pipe 60 a completion string is suspended and is supplied with a safety valve in the well 64 and a plug assembly 65. The horizontal connection shaft 50 has a body 52 that includes a bolt 54 against a bolt 63 which was given the appropriate shape of the hanging support of the tub Figure 60 rests when the hanging support of the pipe 60 is accommodated in the body 52 of the horizontal connection shaft 50. The horizontal connection shaft 50 can also be provided with a propeller (not shown) to orient the hanging support of the pipe. 60 inside the horizontal connection shaft 50. The installation of the suspension support of the pipe 60 on the horizontal connection shaft is conducted above sea level 66 and, more specifically, on the drilling platform 44 below the floor of the tower of drilling 46, to form a combined horizontal connection shaft / hanging support of the pipe (hereinafter the HXT / TH assembly) 70 which can be lowered to its position in the well after the installation was verified. To verify the integrity of the HXT / HT 70 assembly, all electrical and hydraulic connections are checked. The HXT / TH 70 assembly can also be subjected to a pressure evaluation. The ability to perform the installation of the hanging support of the pipe in the body of the horizontal connection shaft above sea level and preferably on the platform of installation of a derrick or a boat, provides an important advantage over having to perform the installation and verifications in submarine form. With reference to Figure 7, an ascending column package [LRP] 80 is positioned on the HXT / TH 70 assembly while the HXT / TH 70 assembly is on the platform of the well 44. The LRP 80 is stocked with hydraulic arrietes and / or valves in their vertical hole as a means of providing a barrier. The LRP 80 has an attached disconnector / connector [EDC] 90 to allow the LRP 80 to be disconnected if necessary, for example, in poor condition. With reference to Figure 8, once the LRP 80 was installed, the HXT / TH 70 and LRP 80 assemblies are run to the wellhead in a single operation. During the run of the assembly HXT / TH 70 towards the head of the well 1 1, the control of the well is carried out by means of the first and second barriers 26 and 30 respectively, which remain in position. An ascending junction column, in this example, a single-ended termination ascending column 92 is placed over the LRP, ending in a surface flow tree 88. The terminating rising column is held and tensioned in the usual manner to accommodate the movement of the derrick because of sea conditions. The surface flow tree 88 together with the LRP 80 allows for appropriate pressure control to be maintained to facilitate wired operations and / or well cleaning if desired.
Once the HXT / TH 70 assembly is installed in the wellhead 1 1, the integrity is verified by evaluation. Then, the support is placed in the hydraulic levers / valves of the LRP 80 and / or the valves of the surface shaft 88 and / or the valves in the connection shaft 50, to meet the legal requirement of having two independent barriers during the extraction, typically using a wire medium, of the barriers, first and second, 26 and 30, respectively. At this stage of the process, the barriers, first and second, 26 and 30, respectively, are removed to prepare the well for production. With reference to Figure 9, after the extraction of the first and second barriers, 30 and 26, respectively, two new independent barriers must be installed on the level of the fluid outlet port 68 of the HXT / TH 70 assembly. A stopper Pipe hanging support 96 and a top pipe hanging support or tree top cap 98 are run through the single hole termination riser 92 and are installed in the hanging support of the pipe 60 and / or tree cover 74 respectively, to supply these new barriers. Once the integrity of the plug of the hanging support of the pipe 96 and the plug of the top of the shaft 98 is checked, the LRP 80 and the associated single-ended termination riser 92 of the HXT / TH 70 assembly are removed. Reference to Figure 10, the final step in the illustrated sequence of completion operations of a well, is to place a debris cover 71, typically by using ROV. Then, the well is ready to produce. When the mode of conditioning operations is required in a well that uses a horizontal connection tree to control the production flow, steps similar to those described above are carried out, but in a different order. Conditioning can be performed to recover a failed connection tree or a suspended support from the failed pipe or both. The use of depth-fixed barriers allows the conditioning operation to be carried out without the need to run a BOP stack in the well. Next, with reference to Figures 6 to 10, with the same reference numbers for the parts are the same, an example of conditioning in a submarine well using a horizontal connection tree as a production flow control device is shown according to one embodiment of the present invention. As described above in relation to the completion of a well by using a horizontal connection tree for the control of production flow, it should be understood that the sequence of steps in particular will vary depending on the purpose of each conditioning operation. in particular. The description to follow refers to the extraction of the HXTrrH 70 assembly. As a first step, the debris cover 71 is removed, typically using an ROV. An LRP 80 and EDC 90 are prepared on the drilling platform 44. Then, this LRP / EDC assembly is run in an upward terminating column 92 up to over the horizontal connection shaft. The surface tree 88 is made in the usual way and the LRP 80 is installed on the horizontal connection tree 50. The integrity of the connections between LRP 80 and the horizontal connection tree 50 is verified, typically by pressure and other evaluations. of operation. Once LRP 80 is in position, the hydraulic levers and / or valves in the vertical hole of the LRP 80 meet the legal requirement of the two independently verified barriers, allowing removal of the tree cap and plugs from the hanging support of the pipe, 98 and 96, respectively. Typically, these plugs are recovered using a wired medium. The next step is to reinstall the first barrier set at depth 26, in this example, in the first casing hanging support 24. The integrity of the first barrier 26 is verified. Then the second barrier fixed at depth 30 is installed, in this example, on the second casing hanging support 28 and is verified its integrity as is usually done. Once the integrity of the first and second barriers, 26 and 3D, respectively, has been verified, the HXT / TH 70 assembly of the well head 1 1 can be unlocked and it can be extracted above sea level 66. The barriers, first and second, 26 and 30, respectively, are used to meet the legal requirement of having two barriers identified independently on site, during the conditioning operations. The corrective, maintenance or any other necessary repair work is performed on the horizontal connection shaft and / or the hanging support of the pipe, typically on the floor of the drill tower 46 or on the drilling platform 44. Once the repair is made, the HXT / TH 70 assembly is reformed above sea level and placed back into the well 10 by using a process as described above in relation to the modality of a termination. of well in a well that uses a horizontal connection tree to control the flow of production. It should be understood that a conditioning operation may also be performed in accordance with this aspect of the present invention and, if desired, without the removal of the horizontal connection shaft. With this option, the LRP 80 and its upward connecting column 92 run in the well as described above, allowing the extraction of the shaft cover 74 and the plugs of the hanging supports of the production pipes, 98 and 96, respectively. The barriers, first and second, fixed at depth 26 and 30 are installed and verified as described above. Then, LRP is brought back to the platform 44. In order to extract only the hanging support from the pipe 60 (together with the completion string 62 suspended from the hanging support of the pipe 60), a tool running through the hanging support the pipe (not shown) is run in the well to unsecure the body of the connection shaft and extract the hanging support from the pipe 60 and the completion string 62, and thus leave the horizontal connection shaft 50 installed in the header of the pipe. well 1 1. In the case of wells using a vertical connection tree for production flow control, it is described in detail below with reference to Figures 1 to 20 in which the same numbers refer to the same parts, examples of the form of termination and / or conditioning of said well according to embodiments of the invention. First the well is drilled, encamised and suspended as described above with reference to Figures 3 and 4. With reference to Figure 1 1, a completion string is made .62 on the floor of the tower perforation 46 terminating at its upper end in a hanging support of the pipe 60. A tool for running the suspended pipe support [THRT] 200 is placed over the hanging support of the pipe 60 and is used to assist orientation and the support and to ensure the hanging support of the pipe in the head of the well 1 1. The THRT 200 can also be used to establish seals between the hanging support of pipe 60 and the well head 1 1. The THRT 200 is provided with a hanging support orientation mechanism of the pipe 202, which is configured to interface with the orientation devices that are in the guide base 12. The orientation mechanism 202 may not be necessary when using a concentric tree. The suspended support of the pipe 60 with the completion string 62 suspended there, is run in the well in open water together with the THRT 200 and the mechanism of orientation of the hanging support of the pipe. An ascending riser column or drop string 92 extends over the THRT 200 to the floor of the drilling platform 46. While running the completion string 62, the THRT 200 and the mechanism of orientation of the hanging support of the pipe 202 to the well, the main control of the well is carried out by means of at least two barriers identified independently, 26 and 30. These barriers are retained in their position at least until that the completion string 62 is installed in the wellhead 1 1. Once the orientation of the hanging support of the pipe 60 relative to the well head 1 1 was verified, if necessary, by using the THRT 200 AND its orientation mechanism 202, the hanging support of the pipe 60 is supported in the head of the well 1 1 and secured in position. The installation of the hanging support of the pipe 60 in the well is verified by checking the integrity of all the hydraulic and electrical connections between the hanging support of the pipe 60 and the head of the well 1 1 and / or the equipment in the well . Then, the THRT 200 AND the orientation mechanism 202 associated with it and the rising riser column 92 are extracted to the floor of the drill tower. With reference to Figure 12, a vertical connection shaft 51 with an equivalent amount of flow holes as the hanging support of the pipe 60 is positioned on the drilling platform 44. If necessary, once installed, the tree is provisioned of vertical connections 51 with the orientation means to assist in the correct orientation of the vertical connection shaft 51 relative to the hanging support of the pipe 60 once. With reference to Figure 12, an ascending column package [LRP] 80 is positioned on the vertical connection shaft 51 on the drilling platform 44. The LRP is stocked with hydraulic arrietes and / or valves in the vertical hole as a means to provide barriers. The LRP 80 is a significantly smaller unit than the BOP 40 stack and, as such, can be run from a smaller vessel than is needed to accommodate and place a BOP stack. The LRP 80 is used in conjunction with an emergency connector disconnect (EDC) 90 to allow disconnection of the completion string 92 from the LRP 80 if necessary; for example, in bad conditions. With reference to Figure 13, the LRP 80, EDC 90 and the vertical connection shaft 51 are run in the well and positioned in the well head 1 1. An ascending connecting column, in this example, a double-ended termination rising column 92 extends over the EDC 90 towards the floor of the pier 46. The rising ascending column 92 is supported and tensioned in the usual way known in the art to accommodate the movement of the derrick because of the state of the sea. A surface flow shaft 88 is used in connection with the LRP 80 and / or the connection shaft 51 to provide pressure control during well cleaning, if desired, as well as to facilitate registration operations and / or drilling. With reference to Figure 14, once it was oriented, the connection shaft 51 was fitted and secured in the well head 1 1, the electrical and hydraulic connections between the hanging support of the pipe 60 and / or the wellhead 1 1 and vertical connection shaft 51. Each of the flow holes of the vertical connection shaft 70 is provided with at least two valves, plugs and / or caps 75 are used to control the flow from the well during production. The support is then based on the hydraulic arrietes of the riser package 80, the valves of the surface tree assembly 88 and / or the valves of the connection shaft 51 to meet the legal requirement of two verifiable barriers independently. At this height, the second and the first barrier, 30 and 26 respectively, are extracted, typically using a wired medium or any other suitable means of extraction, depending on the type of barrier that has been used. The LRP 80 and EDC 90, as well as the associated termination riser 92 are removed to the floor of the drill tower 46.
With reference to Figure 15, then a shaft cap 77 is placed on the vertical connection shaft 51 and the well is finished. A method to terminate a subsea well incorporating a pipe reel is illustrated in Figures 16 to 20. Pipe reels are used when the requirements in the well require a large amount of flow and communication paths from the well bore to the vertical connection tree 51. When a pipe reel is used, some of the communication paths can be guided through the pipe reel instead of through the pipe hanger. It is possible to run the head of the pipe reel from a different alternative vessel to a drilling vessel that is needed to accommodate and run a BOP stack. In the present embodiment, it is possible to run the head of the pipe reel from a different alternative vessel to a drill vessel that is needed to accommodate and run a BOP stack. The barriers, first and second 26 and 30, respectively, verifiable independently, are positioned in the same manner as described in the first embodiment with reference to Figures 3 and 4. With reference to Figure 16, a guide base for Pipe reel 1 15 is installed on the terminating guide base 15. Then, a pipe reel 1 10 is installed in the head of well 1 1 of the suspended pit of Figure 4. The pipe reel guide base 1 15 it may be used to assist in the orientation of the hanging support of the pipe 60 relative to the pipe reel 1 10. Alternatively, the pipe reel 1 10 may include an induction mechanism for this function. With reference to Figure 17, a completion string 62 is made, which at its upper end terminates in a hanging support of the pipe 60 in the manner described above. A THRT 200 with an associated orientation mechanism 202 is used to orient the hanging support of the pipe 60 relative to the pipe reel 1 10. As an alternative, if preferred, the orientation mechanism 202 can be provisioned in the reel head of the reel. pipe 1 10 instead of with the THRT 200. When finished with the proper orientation, the hanging support of the pipe 60 rests on the pipe reel 1 10 and is secured in position. Then, the integrity of the interfaces between the hanging support of the pipe 60 and the pipe reel 1 10 is checked. The THRT 200 is removed to allow the installation of the vertical connection shaft 51. With reference to Figure 18, a vertical connection shaft 51 is positioned with an equivalent amount of flow holes to that of the hanging support of the pipe 60 on the drilling platform 44. If necessary, the vertical connection shaft 51 is provision with a means of orientation to assist in the correct orientation of the vertical connection tree 51 relative to the hanging support of the pipe 60 once installed. An ascending column package [LRP] 80 is positioned by envelope of the vertical connection tree 51 on the drilling platform 44. The LRP 80 is used in conjunction with an emergency connector disconnect (EDC) 90 to allow the rising termination column 92 disconnect from the LRP 80 if necessary; for example, in bad conditions. The LRP 80, EDC 90 and the vertical connection shaft 51 are run in the well and placed on the pipe reel 1 10.
An ascending connecting column, in this example, a double-hole ascending column 92 extends over the EDC 90 towards the floor of the drilling platform 46. With reference to Figure 1 9, once the connection shaft is installed on the head of the pipe reel 1 10 and the hanging support of the pipe 60, the barriers, first and second, fixed at depth 26 and 30 respectively, are removed as described in the case of the first embodiment above. The flow valves 75 of the connection shaft 51 are closed to allow removal of the package from the rising column and the well is supplied with a shaft cover 77 if desired, as shown in Figure 20. When it is necessary to perform conditioning operations in the subsea well by using a vertical connection tree to control the flow of product, steps similar to those described above are taken but in a different order. A conditioning operation can be performed to recover a failed connection tree, a suspended support from the failed pipe and / or a failed completion string. As a first step in a conditioning operation, the barriers, first and second, 26 and 30 respectively, are restored and verified in a sequenced manner to provide a main well control prior to removal of the vertical connection shaft 51 and / or the hanging support for pipe 60. Once again, the use of two independently set depth-verified barriers allows the conditioning operation to be performed without the need to run a BOP stack in the well. Next, with reference to the embodiment shown in Figures 1 to 15, a typical sequence is described for a conditioning operation for a well using a vertical connection tree for the control of the production flow. It should be appreciated that if the well includes a pipe reel, the pipe reel typically remains in position in the wellhead while the correction operations are carried out on the pipe hanging support and / or on the tree. vertical connections. In the case of a conditioning operation that requires the removal of the hanging support from the pipe 60, the tree cover 77 is removed, typically by the use of ROV. An ascending column package [LRP] 80 and an emergency disconnect / connector [EDC] 90 are prepared on drilling platform 44 and run in the well. A surface tree 88 is made in the usual manner and the ascending column package 80 is installed in the vertical connection tree 51. The integrity of the connections between LRP 80 and the connection tree 51 are verified in the usual way.
With the LRP 80 in position, the hydraulic arrietes and / or the valves in the vertical hole of the LRP 80 are sufficient to meet the legal requirement of provision of two independently verifiable barriers, which allow the opening of the flow valves 75 in the vertical flow holes of the vertical connection shaft 51. The next step is to restore the barriers, first and second 26 and 30 as described above with reference to Figure 4. Once the integrity of the first barrier 26 was verified, the second barrier 30 is installed and then it is verified. Then, the vertical connection shaft 51 can be unlocked from the hanging support of the pipe 60 and it can be extracted to the drill tower where the correction tasks will be performed. The hanging support of the pipe 60 can also be unlocked and removed from the drill rig for the mode of other correction, maintenance or repair work that is needed. The correction work is typically performed on the floor of the drilling tower 46 or on the drilling platform 44. Once the repair is made, the hanging support of the pipe 60 is returned and installed in the wellhead. 1 1 or on the reel of pipe 1 10 in the manner described above for the case of well completions. Then, the vertical connection tree 51 in the wellhead 1 1 is reinstated by the procedure described above in relation to the methods for the completion of a well.
Now that the preferred embodiments of the present invention have been described in detail, the present invention has several advantages over the existing technique, including the following: (a) eliminating the need to run a BOP stack a second time for the modality of termination operations; (b) the ability to use a rising column package in place of a BOP stack during the installation of the production flow control device for subsea wells; (c) the ability to use only a rising column package instead of a BOP stack for conditioning operations and other interventions presents significant cost savings, eliminating the traditional need to use a drilling BOP stack and a marine pipeline for subsea wells; (d) the risk of debris entering the suspended support of the pipe is reduced, since it is not necessary for the hanging support of the pipe to be installed through the hole of a BOP stack [and a marine pipe in the case of underwater wells]. In the case of wells using horizontal connecting shafts for production flow control, the methods of the present invention provide additional advantages including the following: (e) the ability to perform the installation of the suspended support of the pipe in the body of a tree of horizontal connections above sea level, which is a much simpler operation than if it is done underwater and simplifies all corrective actions; (f) the ability to perform and verify all electrical and hydraulic connections and penetrations above sea level; (g) the elimination of the need to use a submarine test tree for subsea wells that use underwater Christmas trees; and, (h) the ability to use a rising column package (LRP) instead of SSTT for wells that use a horizontal connection tree. The LRP is considerably more robust and reliable and eliminates the need to feed and interact with rental equipment that has a high cost. Many variants and modifications will suggest the people with experience in the pertinent technique, in addition to those already described, without departing from the basic inventive concepts. All such variants and modifications should be considered within the scope of the present invention, the nature of which will be determined from the foregoing description and the appended claims.
Claims (100)
- CLAIMS 1. A method for suspending a well comprising: providing a first barrier in the well; verify the integrity of the first barrier; 5 providing at least one second barrier in the well at a location on the first barrier to define a space between the barriers, first and second; and verify the integrity of the second barrier; the barriers, first and second, are located below the lower end of the completion string, when the completion string is installed in the well and remains in position while the well is suspended.
- 2. A method for suspending a well according to claim 1 characterized in that the verification of the The integrity of the second barrier also includes the measurement of the pressure in the space between the barriers, first and second.
- 3. A method for suspending a well according to claim 1 or 2, characterized in that one or both barriers, first and second, are selected from the group consisting of: 20 cement plug; an undrilled casing; a section of an undrilled casing; a top valve of the coater; a bridge plug; expandable plug; a stopper of disappearance; a rupture disk; and / or an inflatable plug packer. '4. A method for suspending a well in accordance with Any of claims 1-3, characterized in that one or both of the first and second barriers is provided as a combination of a physical device, a means for securing the physical device in position in the well, and a sealing means. A method for suspending a well according to claim 4, characterized in that the sealing means is selected from the group consisting of: a ball valve; clapper valve; a sliding shirt; pressure cyclic plug; recoverable plug by fastener; a rupture disk; an insulation-forming device; a cutting disc; an open pump device 6. A method for suspending a well according to claim 4 or 5, characterized in that the sealing means is positioned remote from the physical device. A method for suspending a well according to any of claims 1-6, further comprising the installation of: a first casing hanging support; or, a first and a second hanging casing support, in the well. A method for suspending a well for suspending a well according to claim 7, characterized in that the first barrier is provided within the first or the second hanging casing holder, and the second barrier is provided within the first or second support casing pendant. A method for suspending a well according to any of the claims 1-7, further comprising the installation of a first coater or a first and a second coater in the well. 1 0. A method for suspending a well according to claim 9, characterized in that the first barrier is provided within the first or second coater, and the second barrier is provided within the first or second coater. eleven . A method for suspending a well according to any of claims 1-6 characterized in that the well comprises at least one string of the casing and one or both barriers, first and second, are provided within the at least one string of the casing. 12. A method to complete a well, comprising: providing a first barrier in the well; verify the integrity of the first barrier; providing at least one second barrier in the well at a location on the first barrier to define a space between the barriers, first and second; and verify the integrity of the second barrier; be based on the barriers, first and second, to provide control of the well during the installation of the completion string in the well, the completion string has a lower end; and installing a production flow control device in the well to regulate the flow of fluids through the well. The barriers, first and second, are below the lower end of the completion string when the completion string is installed in the well. A method for completing a well according to claim 12, characterized in that the verification of the integrity of the second barrier further comprises measuring the pressure in the space between the first barrier and the second. 14. A method for completing a well according to claim 12 or 13, characterized in that one of the barriers or both barriers, first and second, are selected from the group consisting of: a cement plug; an undrilled casing; a section of an undrilled casing; a top valve of the coater; a bridge plug; expandable plug; a stopper of disappearance; a rupture disk; and / or an inflatable plug packer. A method for completing a well according to any of claims 12 - 14, characterized in that one or both barriers, first and second, are provided as a combination of a physical device, a means for securing the position of the physical device and a sealing means. 16. A method for completing a well according to claim 15, characterized in that the sealing means is selected from the group consisting of: a ball valve; clapper valve; a sliding shirt; pressure cyclic plug; recoverable plug by fastener; a rupture disk; an insulation-forming device; a cutting disc; an open pump device. 17. A method for completing a well according to claim 15 or 16, characterized in that the sealing means is positioned remote from the physical device. A method for completing a well according to any of claims 12-17, further comprising the installation of: a first casing hanging support; or, a first and a second hanging casing support, in the well. 9. A method for completing a well according to claim 18, characterized in that one or both barriers, the first and the second, is provided inside the first casing hanging support or the second casing hanging support. 20. A method for completing a well according to any of claims 12-17 further comprising the installation of a first coater or a first coater and a second coater in the well. twenty-one . A method for completing a well according to claim 20, characterized in that one or both barriers, first and second, are provided within the first coater or the second coater. 22. A method for completing a well according to any of claims 12-17 characterized in that the well comprises at least one string of the casing and one or both barriers, first and second, is provided within at least one string of the casing. 23. A method for completing a well according to any of claims 12-22 further comprising the installation of a pipe reel in a well head before installing the completion string in the well. 24. A method for completing a well according to any of claims 12-24 characterized in that the installation of the production flow control device comprises the installation of a connection shaft 25. A method for completing a well according to the claim 24, characterized in that the installation of the connection tree comprises the installation of a horizontal connection tree. 26. A method for completing a well according to claim 25, characterized in that the completion string ends at its upper end and is suspended from a hanging support of the pipe, and the method further comprises forming an assembly comprising the horizontal connections and the suspended support of the pipe supporting and securing the suspended support of the pipe in the horizontal connection tree before taking the step of installing the flow control device in the well. 27. A method for completing a well according to claim 26, further comprising installing the assembly in the well in a single operation. 28. A method for completing a well according to claim 24, characterized in that the installation of the connection shaft comprises the installation of a vertical connection tree. .29. A method for reconditioning a finished well, characterized in that a production flow control device and a completion string installed in the hole of the well, the completion string has an upper end that terminates in a hanging support of the pipe of which suspends the completion string at a lower end, the method comprising: providing a first barrier in the well; verify the integrity of the first barrier; providing at least one second barrier in the well at a location above the first barrier to define a space between the first and second barriers; verify the integrity of the second barrier; the support at the first and second barriers to provide control of the well while removing the suspended support from the pipe, the completion string or the production flow control device from the well, or both; The barriers, first and second, are below the lower end of the completion string when the completion string is installed in the well. 30. A method for reconditioning a finished well according to claim 29, characterized in that the verification of the integrity of the second barrier further comprises measuring the pressure in the space between the first and second barriers. 31 A method for reconditioning a finished well according to claim 29 or 30, characterized in that one of the barriers and barriers, first and second, are selected from the group consisting of: a cement plug; an undrilled casing; a section of an undrilled casing; a top valve of the coater; a bridge plug; expandable plug; a stopper of disappearance; a rupture disk; and / or an inflatable plug packer. 32. A method for reconditioning a finished well according to any of claims 29-31, characterized in that one or both barriers, first and second, are provided as a combination of a physical device, a means for securing the position of the physical device. , and a means of sealing. 33. A method for reconditioning a finished well according to claim 32 characterized in that the sealing means is selected from the group consisting of: a ball valve, a flapper valve; a sliding shirt; pressure cyclic plug; recoverable plug by fastener; a rupture disk; an insulation-forming device; a cutting disc; an open pump device. 34. A method for reconditioning a finished well according to claim 32 characterized in that the sealing means is positioned remote from the physical device. 35. A method for reconditioning a finished well according to claim 29, further comprising installing a first casing hanging support or a first casing hanging support and a second casing hanging support in the well. 36. A method for reconditioning a finished well according to claim 35, characterized in that one or both barriers, the first and the second, are provided in the first casing hanging support or the second hanging support of the casing. 37. A method for reconditioning a finished well according to any of claims 29-35 further comprising the installation of a first coater or a first coater and a second coater in the well. 38. A method for reconditioning a finished well according to claim 37, characterized in that one or both barriers, first and second, are provided within the first coater or the second coater. 39. A method for reconditioning a finished well according to any of claims 29-34, characterized in that the well comprises at least one string of the casing and, one or both barriers, first and second, are provided within the at least one coater string. 40. A method for reconditioning a finished well according to any of claims 29-39, further comprising the installation of a pipe reel in the well and then the installation of a hanging support of the pipe of the completion string in the well. pipe reel. 41 A method for reconditioning a finished well according to any of claims 29-40, characterized in that the installation of the production flow control device comprises the installation of a connection shaft 42. A method for reconditioning a finished well in accordance with claim 41, characterized in that the connection tree is a horizontal connection tree. 43. A method for reconditioning a finished well according to claim 41, characterized in that if the production control device is a horizontal connection tree, the method further comprises extracting the hanging support from the pipe and / or the string from Completion of the horizontal connection tree by unlocking the hanging support of the horizontal connection shaft pipe. 44. A method for reconditioning a finished well according to claim 42, further comprising extracting the connection shaft and the completion string as an assembly. 45. A method for reconditioning a finished well according to claim 41 characterized in that the connection tree is a vertical connection tree. 46. A method for reconditioning a finished well according to any of claims 29-45 further comprising the support at the barriers, first and second, to provide control of the well until the hanging support of the pipe, the termination pipe and / or the production flow control device are reinstalled in or on the well. 47. A suspended well comprising: a well hole that has an upper end; a wellhead installed towards the upper end of the hole in the well; and at least one first barrier and a second barrier that are independently verified positioned spaced apart in the hole of the well in such a way that a space is defined between the first barrier and the second that are located below an anticipated depth of the bottom end of a completion string when it is installed in the well. 48. A suspended well according to claim 47, further comprising a means for measuring the pressure for the generation of a signal indicating the pressure in the space between the barriers, first and second. 49. A suspended well according to claim 48, further comprising a signal receiving means for receiving the signal generated by the means for measuring the pressure. 50. A suspended well according to claim 49, further comprising means for transmitting the signal from the medium for measuring the pressure to the signal receiving means. 51 A suspended well according to any of claims 48-50 characterized in that the means for measuring the pressure is a transducer. 52. A suspended well according to any of claims 47-51 characterized in that the well is one of: an underwater well; a well on the ground or a platform well. 53. A suspended well according to any of claims 47-52, characterized in that one or both barriers, the first and the second, are selected from the group consisting of: a cement plug; an undrilled casing; a section of an undrilled casing; a top valve of the coater; a bridge plug; expandable plug; a stopper 'of disappearance; a rupture disk; and / or an inflatable plug packer. 54. A suspended well according to any of claims 47-53 characterized in that one or both barriers, first and second, comprise a combination of a physical device, a means for securing the position of the physical device and a sealing means. 55. A suspended well according to claim 54, characterized in that the sealing means is selected from the group consisting of: a ball valve; clapper valve; a sliding shirt; pressure cyclic plug; recoverable plug by fastener; a rupture disk; an insulation-forming device; a cutting disc; an open pump device. 56. A suspended well according to claim 54 or 55 characterized in that the sealing means is positioned distally of the physical device. 57. A suspended well according to any of claims 47-56, further comprising: a first casing hanging support; or, a first casing hanging support and a second casing hanging support, installed in the well. 58. A suspended well according to claim 57, characterized in that one or both barriers, first and second, are positioned within the first or the second hanging casing support. 59. A suspended well according to any of claims 47-56 further comprising: a first coater, or a first coater and a second coater, installed in the well. 60. A suspended well according to claim 59, characterized in that one or both barriers, first and second, are positioned in the first coater or in the second coater. 61 A suspended well according to any of claims 47-56 characterized in that the well comprises at least one string of the casing and one or both barriers, first and second, are provided within the at least one string of the casing. 62. A finished well comprising: a well hole having an upper end; a wellhead installed towards the upper end of the hole in the well; a device for controlling the flow of production in the well head or above it; a completion string installed in the hole of the well and having a lower end; and at least one first and second barrier verified independently located with a space between them in the hole of the well in such a way that a space is defined between the first barrier and the second, the barriers, first and second, are located below the lower end of the completion string. 63. A finished well according to claim 62 further comprising a means for measuring the pressure for the generation of a signal indicating the pressure in the space between the first and second barrier. 64. A finished well according to the claim 63, further comprising a signal receiving means for receiving the signal generated by the means for measuring the pressure. 65. A well finished according to the claim 64, characterized in that furthermore a means for transmitting the signal from the medium for measuring the pressure to the signal receiving means. 66. A well finished according to any of claims 62-65 characterized in that the means for measuring the pressure is a transducer. 67. A finished well according to any of claims 62-66 characterized in that the production flow control device is a horizontal or vertical connection tree. 68. A finished well according to any of claims 62-67 characterized in that in addition a pipe reel installed in the wellhead. 69. A finished well according to any of claims 62-68, characterized in that the well is an underwater well, a well on land or a platform well. 70. A finished well according to any of claims 62-69, characterized in that one or both barriers, the first and the second, are selected from the group consisting of: a cement plug; an undrilled casing; a section of an undrilled casing; a top valve of the coater; a bridge plug; expandable plug; a stopper of disappearance; a rupture disk; and / or an inflatable plug packer. 71. A finished well according to any of claims 62-69 characterized in that one or both barriers, first and second, comprise a combination of a physical device, a means for securing the position of the physical device and a sealing means. 72. A finished well according to claim 71 characterized in that the sealing means comprises one of the group consisting of: a ball valve; clapper valve; a sliding shirt; pressure cyclic plug; recoverable plug by fastener; a rupture disk; an insulation-forming device; a cutting disc; an open pump device. 73. A well finished according to the claim 71 or 72 characterized in that the sealing means is positioned remote from the physical device. 74. A finished well according to any of claims 62-73, further comprising a first casing hanging support; or, a first casing hanging support and a second casing hanging support, installed in the well. 75. A finished well according to claim 74, characterized in that one or both barriers, first and second, are positioned within the first or second casing hanging support. 76. A finished well according to any of claims 62-74 further comprising: a first coater, or a first coater and a second coater installed in the well. 77. A finished well according to claim 76, characterized in that one or both barriers, first and second, are positioned in the first or in the second coater. 78. A finished well according to any of claims 62-73 characterized in that the well comprises at least one string of the casing and one or both barriers, first and second, is provided within the at least one string of the casing. 79. A double barrier system for its use for the suspension, termination or conditioning of a well, the double barrier system comprising: a first barrier and a second barrier that are positioned spaced from each other in the well in such a way that a space is defined between the first barrier and the second; means for measuring the pressure to generate a signal indicating the pressure in the space between the first and the second barrier; means for receiving the pressure signal that receives the signal generated by the means for measuring the pressure; and, means for transmitting the signal from the medium to measure the pressure to the receiving medium of the pressure signal. 80. A double barrier assembly according to claim 79, characterized in that the means for measuring the pressure is a transducer. 81 A double barrier assembly according to claim 79 or 80, characterized in that one or both barriers, the first and the second, is selected from the group consisting of: a cement plug; an undrilled casing; a section of an undrilled casing; a top valve of the coater; a bridge plug; expandable plug; a stopper of disappearance; a rupture disk; and / or an inflatable plug packer 82. A double barrier assembly according to claim 79 or 80, characterized in that one or both barriers, the first and the second, comprise a combination of a physical device, a means for securing the position of the physical device, and a means of sealing. 83. A double barrier assembly according to claim 82 characterized in that the sealing means comprises one of the group consisting of: a ball valve; clapper valve; a sliding shirt; pressure cyclic plug; recoverable plug by fastener; a rupture disk; an insulation-forming device; a cutting disc; an open pump device. 84. A double barrier assembly according to claim 82 or 83, characterized in that the sealing means is located separate from the physical device. 85. A double barrier assembly according to any of claims 79-84, characterized in that the well further comprises: a first casing hanging support; or, a first casing hanging support and a second casing hanging support, installed in the well and one or both, the first or second barrier, are positioned in the first or second casing hanging support. 86. A double barrier assembly according to any of claims 79-84, characterized in that the well further comprises a first coater or a first coater and a second coater, installed in the well and one or both barriers, first and second, they are positioned within the first or second coater. 87. A double barrier assembly according to any of claims 79-84, characterized in that the well further comprises a string of the casing and one or both barriers, the first and the second being provided within at least the casing string. 88. A method to terminate a subsea well that uses a horizontal connection tree for the control of the production flow, the method comprising: forming an assembly by installing a completion string that ends in a hanging support at its upper end of the pipe and suspended from this supported on the horizontal connection tree; and, place the assembly in the submarine well; the hanging bracket of the pipe and the horizontal connection tree placed above sea level in the formation step of the assembly. 89. A method for terminating a subsea well using a horizontal connection shaft for the control of the production flow according to claim 88, characterized in that the formation of the assembly further comprises that the hanging support of the pipe between and is secured in the connection tree. 90. A method for terminating a subsea well according to claim 88 or 89 characterized in that further verification of the integrity of the finished assembly while such a finished assembly is above sea level. 91 A method for terminating an underwater well according to claim 90, characterized in that the verification of the integrity comprises the verification of the hydraulic and electrical interfaces between the hanging support of the pipe and the body of the connection shaft. 92. A method for terminating a subsea well according to claim 90 or 91, characterized in that the verification of the integrity further comprises the verification of the integrity of the assembly pressure. 93. A method for terminating a subsea well according to claim 88, characterized in that the installation of the assembly in the wellhead comprises the installation of a rising column package in the horizontal connection shaft. 94. A method, comprising: coupling a pipe string with the connection shaft over the water; and the deposit of the connection shaft in the head of the submarine well. 95. A method according to claim 94, characterized in that the coupling of the pipe string with the connection shaft comprises the installation of a hanging support of the pipe in a connection as high as possible of the pipe string and the Secure the hanging support from the pipe to the connections tree 96. A method, according to claim 94, further comprising running the connection shaft, the hanging support of the pipe, and the pipe string in open water in a well extending from the subsea wellhead. 97. A method, according to claim 96, characterized in that running the connection shaft, the hanging support of the pipe, and the pipe string, further comprises running the connection shaft, the hanging support of the pipe, and the pipe string without an eruption controller. 98. A method, according to claim 94, characterized in that the coupling of the pipe string with the connection shaft comprises the installation of a hanging support of the pipe in the upper connection of the pipe string, the securing of the support hanging the pipe in a tube head and attaching the tube head to the connection shaft 99. A method, comprising: coupling a pipe string to a hanging support of the pipe above sea level; the deposit of the hanging support of the pipe in an underwater wellhead; and the deposit of a connection shaft in an underwater wellhead. 100. A method, according to claim 99, further comprising closing the hanging support of the pipe to the connection shaft 1 01. A method, according to claim 99, further comprising closing the hanging support from the pipe to the wellhead. 1 02. A method, according to claim 99, characterized in that the entrance of the hanging support of the pipeline to the subsea wellhead further comprises the entrance of the hanging support of the pipeline to the subsea wellhead through a pipe reel and the closing of the hanging support of the pipe to the pipe reel.
Applications Claiming Priority (4)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| AU2003904183 | 2003-08-08 | ||
| US10678636 | 2003-10-06 | ||
| AU2003905436 | 2003-10-06 | ||
| AU2003905437 | 2003-10-06 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| MXPA06001531A true MXPA06001531A (en) | 2006-12-13 |
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