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Examples of dummy run. dummy run. I fully understand that what they have designed is for the best—that this is a dummy run of an entirely new type of scheme.
Table of contents

During conventional drilling procedures, it is often desirable to conduct various tests of the wellbore and drill string while the drill string is still in the wellbore. In this regard, the SSTT serves as a contingency in the event of an emergency that requires disconnection of the drillstring in the wellbore from the surface, such as in the event of severe weather or malfunction of a dynamic positioning system.

As such, the SSTT includes a decoupling mechanism to unlatch the portion of the drill string in the wellbore from the drill string above the wellbore. Thereafter, the surface vessel and riser can decouple from the BOP and move to safety. Finally, the SSTT typically is deployed in conjunction with a fluted hanger disposed to land at the top of the wellbore to at least partially support the lower portion of the drillstring during DST.

Moreover, the SSTT may be destroyed by the rams to the extent the rams are activated for a particular reason. During conventional dummy runs, a temporary hanger with a painted pipe above it is run into the BOP, typically on jointed tubing.

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Once the temporary hanger lands within the BOP, the rams are closed on the painted pipe with sufficient pressure to leave marks that indicate their position relative to the landed hanger. The rams are then retracted, and the dummy string is retrieved uphole. Although simplistic, there is at least one severe drawback to conventional dummy run operations. Making up the jointed tubing used in the dummy assembly is very time consuming.

dummy run 2 fairing

Given this, and the fact that some wells are drilled at ocean depths of up to 10, feet or deeper, it can take days to complete a single dummy run. At the present time, it is estimated that some floating rigs have a daily cost of upwards of , USD. Therefore, conventional dummy run operations are very expensive. In view of the foregoing, there is a need in the art for cost-effective approaches to properly positioning of the subsea test equipment within the BOP. Illustrative embodiments and related methodologies of the present invention are described below as they might be employed in an assembly and method for eliminating dummy runs using a logging tool.

In the interest of clarity, not all features of an actual implementation or methodology are described in this specification. It will of course be appreciated that in the development of any such actual embodiment, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which will vary from one implementation to another.

Moreover, it will be appreciated that such a development effort might be complex and time-consuming, but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure. Further aspects and advantages of the various embodiments and related methodologies of the invention will become apparent from consideration of the following description and drawings. As described herein, logging assembly 10 forms part of the assembly used to perform borehole logging operations. Since logging operations are performed prior to DST, use of the present invention eliminates the need to perform a dummy run.

In certain exemplary embodiments, logging assembly 10 is carried on a string wireline 12 , for example which extends down through a body of water from a surface vessel not shown , via a riser 14 connected to BOP However, in other embodiments, logging assembly 10 may be carried on, for example, jointed pipe or coil tubing. BOP 16 includes a plurality of BOP rams 20 , as understood in art, and is positioned atop wellbore A wear bushing 24 is disposed at the top of wellbore Logging assembly 10 includes a logging tool 18 utilized to detect and log one or more petrophysical characteristics of a borehole and surrounding geological formation, as will be understood by those ordinarily skilled in the art having the benefit of this disclosure.

Persons ordinarily skilled in the art having the benefit of this disclosure will realize there are a variety of logging tools which may be utilized within the present invention. Moreover, in certain exemplary embodiments, logging assembly 10 may be adapted to perform logging operations in both open and cased hole environments. As described herein, logging tool 18 includes one or more sensors not shown that detect the position of one or more BOP rams 20 and wear bushing Logging assembly 10 then logs the detected positions of the BOP rams 20 and wear bushing Thereafter, as will be described below, the logged positions of BOP rams 20 and wear bushing 24 are used to determine the distance between them, thereby also determining the correct placement of the SSTT in relation to its hanger.

Accordingly, through use of the present invention, the need to perform a dummy run is eliminated because correct placement of the SSTT can be determined during standard logging operations. In certain exemplary embodiments, logging tool 18 may also be configured to detect petrophysical characteristics of wellbore 22 , or other logging devices not shown along logging assembly 10 may be utilized for this purpose.

In certain embodiments, CPU 26 calculates the distance between wear bushing 24 and one or more BOP rams 20 and stores the data in on-board storage. However, in other embodiments, the logged positions of wear bushing 24 and BOP rams 20 may be transmitted to a remote location the surface, for example and the calculations performed there. Moreover, in yet another alternative embodiment, CPU 26 may be located remotely from logging tool 18 and performs the processing accordingly. These and other variations within the present invention will be readily apparent to those ordinarily skilled in the art having the benefit of this disclosure.

Still referring to FIG. In other embodiments, a caliper tool having 2, 4, 6, or 8 arms, or a specialized multi-finger caliper 20, 40, 60 fingers, for example , might be utilized in logging tool Such a caliper tool can be, for example, a simple mechanical two-arm tool, a multi-arm device forming part of a dipmeter or imager tool, a multi-arm caliper run with dipole sonic tools or a multi-finger caliper used for cased hole operations.

In addition, the logging sensors may be adapted to perform, for example, cement evaluation and pipe inspection either simultaneously or in the same downhole trip. Transmitter 28 communicates with a remote location surface, for example using, for example, acoustic, pressure pulse, or electromagnetic methodologies, as will be understood by those ordinarily skilled in the art having the benefit of this disclosure. In certain other exemplary embodiments, logging tool 18 may be equipped with an accelerometer not shown to enhance the accuracy of distance readings.

The accelerometer may be positioned anywhere within logging tool 18 to provide a very accurate delta depth when logging up or down through wear bushing 24 and BOP In one exemplary embodiment, logging tool 18 would be stopped below wear bushing 24 and then the logging would begin. The accelerometer would provide accurate delta depth information in the area of interest as logging tool 18 were slowly raised.

However, in another embodiment, the logging may be conducted while moving logging tool 18 in the downward direction, as will be understood by those ordinarily skilled in the art having the benefit of this disclosure. Referring now to FIGS. When it is desired to perform a logging operation, logging assembly 10 is deployed downhole using, for example, wireline As logging assembly 10 continues its descent, it is eventually passed through BOP 16 , BOP rams 20 , and the hang off location wear bushing While doing so, logging tool 18 detects and logs the position of at least one BOP ram 20 and wear bushing In this example as shown in FIG.

As it continues to be lowered, it encounters wear bushing 24 where it again detects and logs its position FIG. CPU 26 may utilize the logged positions to calculate the distance between one or more BOP rams 20 and wear bushing 24 , and store the logged positions and calculations accordingly.

FIELD OF THE INVENTION

However, in other embodiments, CPU 26 may transmit the logged positions in real-time, via transmitter 28 , to a remote location where the distance is calculated. Also note that logging assembly 10 may log the positions of BOP rams 20 and wear bushing 24 during its uphole assent in other embodiments, as understood in the art.


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Those ordinarily skilled in the art having the benefit of this disclosure will realize that the position of one or more of the rams or the wear bushing may be utilized alone or together to determine correct placement of the SSTT and BOP Thereafter, logging assembly 10 may be further deployed downhole to perform other logging operations such as, for example, logging one or more characteristics of the geological formation. After all logging operations have concluded, logging assembly 10 is retrieved back uphole to the surface.

In the alternative, the SSTT assembly may simply be made up based upon the logged positions, thus requiring no adjusting of the hanger. Moreover, the SSTT may be made up or adjusted in real-time as the logged data is transmitted from logging assembly 10 , thus saving even more time. Thereafter, DST operations may be conducted as understood in the art.

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