Patent Application
20170058662
Not applicable.
Not applicable.
The present invention relates generally to magnetically detecting equipment external to a downhole pipe prior to performing certain well operations, such as perforating a hydrocarbon well. More particularly, but not by way of limitation, embodiments of the present invention include one or more magnetic field generating entities installed at various distances along the downhole pipe and in close proximity to the pipe external equipment. An electromagnetic logging tool may be used to detect and locate the pipe external equipment from the resultant magnetic field disturbances to prevent damage to the pipe external equipment.
When completing a hydrocarbon well, operators typically run downhole equipment on the outside of downhole pipe within the wellbore to improve well completion effectiveness and profitably. For instance, operators may run pipe external equipment that include capillary tubing for downhole equipment operation or chemical injection, electric lines for various gauges or devices, and/or other external pipes, power cables, and/or fiber optic lines that improve the understanding of completion activities and production flexibility. However, upon subterranean installation, the end location of the pipe external equipment relative to the downhole pipe may be unknown. During certain well operations, such as perforating a well or cutting a “window,” determining the location and orientation relative to a reference, such as gravity, may be desirable in order to avoid damaging the pipe external equipment. Accurately sensing the location of the pipe external equipment, however, may present some challenges. Thus, implementing solutions that produce a relatively high degree of accuracy in locating pipe external equipment may avoid costs and problems associated with damaging the pipe external equipment within a wellbore.
The following presents a simplified summary of the disclosed subject matter in order to provide a basic understanding of some aspects of the subject matter disclosed herein. This summary is not an exhaustive overview of the technology disclosed herein. It is not intended to identify key or critical elements of the invention or to delineate the scope of the invention. Its sole purpose is to present some concepts in a simplified form as a prelude to the more detailed description that is discussed later.
In one embodiment, a method for providing a location of downhole equipment external to a downhole pipe within a wellbore. To determine the location of the downhole equipment, an electromagnetic logging tool generates an electromagnetic field within the downhole pipe and measures the electromagnetic field disturbances caused from one or more magnetic generating entities. The electromagnetic logging tool detects the position of the one or more magnetic generating entities from the electromagnetic field disturbances and determines the location of one or more pipe external equipment based upon the electromagnetic field disturbances caused from the one or more magnetic generating entities. Additionally, the one or more magnetic generating entities are installed in close proximity to the one or more pipe external equipment.
In another embodiment, a system for determining the locations of at least one pipe external equipment that comprises a downhole pipe running within a wellbore, at least one pipe external equipment running outside the downhole pipe within the wellbore, an electromagnetic logging tool running within the downhole pipe, and at least one magnetic field generating entities located relatively close to the at least one pipe external equipment. The electromagnetic logging tool may be configured to generate an electromagnetic field and detect one or more electromagnetic field disturbances that correspond to the one magnetic field generating entities.
In another embodiment, an apparatus that comprises a downhole pipe, at least one pipe external equipment coupled to the exterior of the downhole pipe within the wellbore, and at least one magnetic field generating entities coupled relatively close to the pipe external equipment. The magnetic field generating entities are coupled to the downhole pipe and the pipe external equipment using a fastening component.
For a more complete understanding of this disclosure, reference is now made to the following brief description, taken in connection with the accompanying drawings and detailed description, wherein like reference numerals represent like parts.
While certain embodiments will be described in connection with the preferred illustrative embodiments shown herein, it will be understood that it is not intended to limit the invention to those embodiments. On the contrary, it is intended to cover all alternatives, modifications, and equivalents, as may be included within the spirit and scope of the invention as defined by claims to be filed in a subsequent non-provisional patent application. In the drawing figures, which are not to scale, the same reference numerals are used throughout the description and in the drawing figures for components and elements having the same structure, and primed reference numerals are used for components and elements having a similar function and construction to those components and elements having the same unprimed reference numerals.
It should be understood that, although an illustrative implementation of one or more embodiments are provided below, the various specific embodiments may be implemented using any number of techniques known by persons of ordinary skill in the art. The disclosure should in no way be limited to the illustrative embodiments, drawings, and/or techniques illustrated below, including the exemplary designs and implementations illustrated and described herein. Furthermore, the disclosure may be modified within the scope of the appended claims along with their full scope of equivalents.
Disclosed herein are various example embodiments that include magnetic field generating entities that generate local magnetic fields used for detecting and locating pipe external equipment outside of a downhole pipe within a wellbore. In one embodiment, the magnetic field generating entities may be magnets or strips of magnets distributed along the length of the downhole pipe and within close proximity to the pipe external equipment. The pipe external equipment may be externally fastened to the downhole pipe using clamps, encapsulation, and/or any other fastening component configured to secure the pipe external equipment. Electromagnetic logging tools may be commonly configured to locate pits or voids in pipes by effectively locating variances in magnetic fields may be used to detect the magnetic field generating entities along the downhole pipe. The electromagnetic logging tool, which also may generate a magnetic field, may detect resultant magnetic field disturbances generated from the field generating entities and produce data that can be used to locate the pipe external equipment. Operations, such as operating a perforating gun within the downhole pipe, may subsequently proceed, without damaging pipe external equipment, once locating the pipe external equipment.
Magnetic field generating entities 112 may be installed in close proximity to the pipe external equipment 108. The magnetic field generating entities 112 may be any material or object configured to produce a local magnetic field and may not be radioactive materials used to tag the pipe external equipment 108. For instance, the magnetic field generating entities 112 may be permanent magnets, magnetized sections of the wireline, coils, and/or magnetic lines that run in close proximity to the pipe external equipment 108. In other words, the magnetic field generating entities 112 may be any component capable of generating a magnetic field downhole. Operators may install the magnetic field generating entities 112 by securing the magnetic field generating entities 112 to the downhole pipe 106, installing the magnetic field generating entities 112 along and/or within the pipe external equipment 108, and/or incorporating the magnetic field generating entities 112 into the downhole pipe 106, pipe collars, and/or specific mandrels that run within the downhole pipe 106. For example, in embodiments where the magnetic field generating entities 112 are permanent magnets, the permanent magnets may be located within and/or on clamps and/or other mechanisms that secure the pipe external equipment 108 to the downhole pipe 106. In another embodiment, the magnetic field generating entities 112 may be located on and/or within the pipe external equipment 108. When the magnetic field generating entities 112 are located on the clamps, operators may secure the magnetic field generating entities 112 to the downhole pipe 106 using encapsulation and/or other bonding material. In embodiments where the magnetic field generating entities 112 are magnetic lines, operators may install the magnetic lines along with at least some of the pipe external equipment 108, such as external capillary tubing, wiring, and/or casing external pipe. In yet another embodiment, the magnetic field generating entities may also be molded into encapsulation often known to those practicing the art to protect lines or wires.
A logging tool assembly 101 may be configured to detect distortions of a magnetic field caused from one or more magnetic field generating entities 112. Operators may typically use the logging tool assembly 101 to determine well integrity by running the logging tool assembly 101 within the downhole pipe 106. For instance, during the lifetime of the well, downhole pipe 106 may erode over time because of corrosion and/or mechanical defects. In order to prevent pipe-string failures, operators may regularly inspect the downhole pipe 106 to detect excessive wear or any other potential infrastructure problems. Operators may detect potential issues in the downhole pipe 106 by running a wireline 114 coupled to an electromagnetic logging tool assembly 101 to locate pits and/or voids in downhole pipe 106 by locating variances in the electromagnetic fields produced by the logging tools to ‘saturate’ the pipe with magnetic flux. From the distortions in the magnetic fields, the logging tool assembly 101 may be able to determine the location of the pipe external equipment relative to a reference, and thereby enable operators to perform other downhole operations in the downhole pipe 106 without damaging the pipe external equipment 108. Embodiments of the logging tool assembly 101 include any casing inspection logging tool that uses magnetic flux leakage to locate pits and/or voids in downhole pipe 106, such as the Baker Hughes Vertilog™ and the Spartek Casing Inspection Tool.
As illustrated in
The detecting unit 104, which may be housed within the logging tool assembly 101 and coupled to the electromagnetic/magnetic field generation unit 102, may comprise one or more electromagnetic/magnetic field sensors configured to detect the varying electromagnetic/magnetic fields by measuring one or more electromagnetic and/or magnetic properties that include induced voltages, eddy-currents, magnetic flux, and/or electromagnetic phase-shifts. In one embodiment, a motor may directionally rotate the detecting unit 104 to detect variations in the electromagnetic and/or magnetic field and simultaneously and/or successively transmit detected data to output, display, record, and/or store the detected data at equipment or devices located on the surface. In another embodiment, a plurality of electromagnetic and/or magnetic field sensors, such as hall-effect sensors may be constructed to form a ring. Other embodiments may employ other types of electromagnetic field sensors well-known in the art.
The detection unit 104 may implement a relatively high speed logging process that provides data to locate the external orientation of the pipe external equipment. During the logging process, when the pipe external equipment 108 and/or magnetic generating entities 112 are present, the detecting unit 104 may detect distorted magnetic fields. Without the pipe external equipment 108 and/or magnetic generating entities 112, the detecting unit 104 may output a constant electromagnetic and/or magnetic field within the downhole pipe 106. The detection unit 104 may not be configured for gamma ray logging that detects tagged pipe external equipment with radioactive materials. The output of the detecting unit 104 will be discussed in more detail in
As persons of ordinary skill in the art are aware, although
For purposes of this disclosure, the term “magnetic” and “electromagnetic” can be interchanged throughout this disclosure. Persons of ordinary skill in the art are aware that electromagnetic fields include electric fields, magnetic fields, and electromagnetic radiation that include light, radio waves, x-rays, and gamma rays. Electric fields are present around charged bodies and magnetic fields exist when electric current is moving. Magnetic files also exist in permanent magnets because of the spin of subatomic particles that are locked into alignment to form a fixed static-magnetic field.
In one embodiment, the clamping component 204 may be a cross coupling clamp that secures and protects the capillary tubing 208 and 210 to the downhole pipe 206. The clamping component 204 may include channels that shield cables and/or wires that traverse across the clamping component 204 to prevent damage. The clamping component 204 may also be adjustable such that the clamping component 204 may accommodate a variety of sizes for the downhole pipes 202 while securing the pipe external equipment 208 and 210. Using
As shown in
Additionally, in certain embodiments, the operators may install the magnetic field generating entities 206 along with the pipe external equipment 208 and 210. Recall, that the clamping component 204 may secure the pipe external equipment 208 and 210 to the downhole pipe 202. In this instance, the magnetic field generating entities 206 may be located in close proximity to the pipe external equipment 208 and held in place using a the clamping component 204. Prior to installing the clamping component 204, an operator may place magnetic field generating entities 206 relatively close to the pipe external equipment 208 and 210. After installing the clamping component 204, the magnetic field generating entities 206 may maintain the close proximity with the pipe external equipment 208 and 210, or at any desired distance in known configuration. Example of embodiments of magnetic field generating entities 206 that are installed along with the pipe external equipment 208 and 210 include permanent magnetized sections of wireline or magnetic wire that are located in close proximity to the pipe external equipment 208 and 210. The magnetic field generating entities 206 may also be placed any radial or longitudinal distance away from the pipe external equipment 208 and 210.
Persons of ordinary skill in the art are aware that distances for “close proximity” and/or “any desired distance in known configuration” are dependent on the type of pipe external equipment. In some instances, persons of ordinary skill in the art are aware that the magnetic field generating entities 206 will affect (e.g., noise) one or more sensors of the pipe external equipment 208 and 210. In these instances, close proximity” and/or “any desired distance in known configuration” will be the determined distance where the magnetic field generating entities 206 will not affect the readings from one or more sensors of the pipe external equipment 208 and 210. For example, if the magnetic field generating entities 206 are distorting the reading for the sensors of the pipe external equipment 208, the magnetic field generating entities 206 may be clamped to the pipe or installed on the opposite of the sensor. For applications where the magnetic field generating entities 206 (e.g., permanent magnet) do not affect the pipe external component 208 and 201, such as an hydraulic umbilical, the distance for close proximity” and/or “any desired distance in known configuration” may be relatively closer. Persons of ordinary skill in the art are aware that a variety of known geometric relationships may be used to determine “close proximity” and/or “any desired distance in known configuration” for the distances between the magnetic field generating entities 206 and pipe external equipment 208 and 210.
The array of the magnetic field generating entities may be distributed along the length of a downhole pipe as shown in the arrangement 402 in
Method 500 may start at step 502 with the install of the magnetic field generating entities in relatively close proximity or a known distance and direction from of the pipe external equipment. Recall that the magnetic field generating entities may be installed in and/or on fastening components that hold the pipe external equipment against the downhole pipe or along with the pipe external equipment (e.g., as a magnetic wire) in the downhole pipe and/or a mandrel or connector of the pipe. After method 500 completes step 502, method 500 moves to step 504 where the method runs the downhole pipe and pipe external equipment within the wellbore. The downhole pipe may or may not be cemented during construction of the hydrocarbon well. Method 500 may subsequently move to step 506 and run a logging tool within the downhole pipe.
Method 500 continues to step 508 to log the magnetic/electromagnetic fields using the logging tool. The logging tool may generate magnetic fields using direct current or permanent magnets, or electromagnetic fields using AC current, and/or RF power within the downhole pipe. Method 500 may then continue to step 510 to detect the generated magnetic and/or electromagnetic fields. Without the magnetic field generating entities, the generated magnetic and/or electromagnetic fields may be substantially symmetrical about the downhole pipe to produce about a constant electromagnetic field. However, method 500 may detect magnetic field generating entities based upon detecting the magnetic disturbances and produce an output similar to
Programming and/or loading executable instructions onto surface control equipment is well known in the art in order to transform surface equipment and/or components located on the logging tool that process data in part into a particular machine or apparatus, e.g., an logging tool system. Implementing instructions, real-time monitoring, and other functions by loading executable software into a computer can be converted to a hardware implementation by well-known design rules. For example, decisions between implementing a concept in software versus hardware may depend on a number of design choices that include stability of the design and numbers of units to be produced and issues involved in translating from the software domain to the hardware domain. Often a design may be developed and tested in a software form and subsequently transformed, by well-known design rules, to an equivalent hardware implementation in an ASIC or application specific hardware that hardwires the instructions of the software. In the same manner as a machine controlled by a new ASIC is a particular machine or apparatus, likewise a computer that has been programmed and/or loaded with executable instructions may be viewed as a particular machine or apparatus.
At least one embodiment is disclosed and variations, combinations, and/or modifications of the embodiment(s) and/or features of the embodiment(s) made by a person having ordinary skill in the art are within the scope of the disclosure. Alternative embodiments that result from combining, integrating, and/or omitting features of the embodiment(s) are also within the scope of the disclosure. Where numerical ranges or limitations are expressly stated, such express ranges or limitations may be understood to include iterative ranges or limitations of like magnitude falling within the expressly stated ranges or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). The use of the term “about” means ±10% of the subsequent number, unless otherwise stated.
Use of the term “optionally” with respect to any element of a claim means that the element is required, or alternatively, the element is not required, both alternatives being within the scope of the claim. Use of broader terms such as comprises, includes, and having may be understood to provide support for narrower terms such as consisting of, consisting essentially of, and comprised substantially of. Accordingly, the scope of protection is not limited by the description set out above but is defined by the claims that follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated as further disclosure into the specification and the claims are embodiment(s) of the present disclosure.
While several embodiments have been provided in the present disclosure, it may be understood that the disclosed embodiments might be embodied in many other specific forms without departing from the spirit or scope of the present disclosure. The present examples are to be considered as illustrative and not restrictive, and the intention is not to be limited to the details given herein. For example, the various elements or components may be combined or integrated in another system or certain features may be omitted, or not implemented.
In addition, the various embodiments described and illustrated in the various embodiments as discrete or separate may be combined or integrated with other systems, modules, techniques, or methods without departing from the scope of the present disclosure. Other items shown or discussed as coupled or directly coupled or communicating with each other may be indirectly coupled or communicating through some interface, device, or intermediate component whether electrically, mechanically, or otherwise. Other examples of changes, substitutions, and alterations are ascertainable by one skilled in the art and may be made without departing from the spirit and scope disclosed herein.
All of the references cited herein are expressly incorporated by reference. The discussion of any reference is not an admission that it is prior art to the present invention, especially any reference that may have a publication data after the priority date of this application.
