Patent ID: 12215557

To facilitate understanding, identical reference numerals have been used, where possible, to designate identical elements that are common to the figures (“FIGS”). It is contemplated that elements disclosed in one embodiment may be beneficially utilized on other embodiments without specific recitation.

DETAILED DESCRIPTION

In the following, reference is made to embodiments of the disclosure. It should be understood, however, that the disclosure is not limited to specific described embodiments. Instead, any combination of the following features and elements, whether related to different embodiments or not, is contemplated to implement and practice the disclosure. Furthermore, although embodiments of the disclosure may achieve advantages over other possible solutions and/or over the prior art, whether or not a particular advantage is achieved by a given embodiment is not limiting of the disclosure. Thus, the following aspects, features, embodiments and advantages are merely illustrative and are not considered elements or limitations of the claims except where explicitly recited in a claim. Likewise, reference to “the disclosure” shall not be construed as a generalization of inventive subject matter disclosed herein and shall not be considered to be an element or limitation of the claims except where explicitly recited in a claim.

Although the terms first, second, third, etc., may be used herein to describe various elements, components, regions, layers and/or sections, these elements, components, regions, layers and/or sections should not be limited by these terms. These terms may be only used to distinguish one element, component, region, layer or section from another region, layer or section. Terms such as “first”, “second” and other numerical terms, when used herein, do not imply a sequence or order unless clearly indicated by the context. Thus, a first element, component, region, layer or section discussed herein could be termed a second element, component, region, layer or section without departing from the teachings of the example embodiments.

When an element or layer is referred to as being “on,” “engaged to,” “connected to,” or “coupled to” another element or layer, it may be directly on, engaged, connected, coupled to the other element or layer, or interleaving elements or layers may be present. In contrast, when an element is referred to as being “directly on,” “directly engaged to,” “directly connected to,” or “directly coupled to” another element or layer, there may be no interleaving elements or layers present. Other words used to describe the relationship between elements should be interpreted in a like fashion. As used herein, the term “and/or” includes any and all combinations of one or more of the associated listed terms.

Some embodiments will now be described with reference to the figures. Like elements in the various figures will be referenced with like numbers for consistency. In the following description, numerous details are set forth to provide an understanding of various embodiments and/or features. It will be understood, however, by those skilled in the art, that some embodiments may be practiced without many of these details, and that numerous variations or modifications from the described embodiments are possible. As used herein, the terms “above” and “below”, “up” and “down”, “upper” and “lower”, “upwardly” and “downwardly”, and other like terms indicating relative positions above or below a given point are used in this description to more clearly describe certain embodiments.

Referring toFIG.1, a drilling rig1is illustrated. The purpose of the drilling rig1is to drill into Earth's geological strata for the purpose of obtaining hydrocarbons from beneath the surface2. Different stratum4may be encountered during the creation of a wellbore10. InFIG.1, as will be understood, multiple layers of stratum4may be encountered. Stratum4may be varied in composition, and may include rock, sand, clay and silt and/or combinations of these. Operators, therefore, need to assess the composition of the stratum4in order to ascertain a maximum penetration depth used in the drilling process. The wellbore10is formed within the stratum4by a drill bit6. In embodiments, the drill bit6is rotated such that contact between the drill bit6and the stratum4cuts the stratum4at the bottom of the wellbore10. Differing types of drill bits6may be used to penetrate different types of stratum4. The types of stratum4encountered, therefore, is an important characteristic for operators. The types of drill bits6may vary widely. Non-limiting embodiments of drill bits6may include polycrystalline diamond compact (“PDC”) drill bits, roller cone bits, diamond impregnated, and hammer bits.

As the wellbore10progresses in depth, operators may add portions of drill pipe11to form a drill string12that extends from the surface to the bottom of the wellbore10. As illustrated inFIG.1, the drill string12may vertically extend into the stratum4. In other embodiments, the drill string12and the wellbore10may deviate from a vertical orientation, such as having sections that are inclined from the vertical.

The drill bit6is larger in diameter than the drill string12such that when the drill bit6produces the wellbore10, an annular space3is created between the drill string12and the inside face of the wellbore10. This annular space3may be used during the drilling process to remove cuttings from the wellbore10. The removal of cuttings may be accomplished by flushing drilling fluids down the drill string12, through the drill bit6, and then up the annular space3between the drill string12and the wellbore10. Drilling fluids include water and specialty chemicals to aid in the formation of the wellbore10.

The drilling fluids is stored in a tank13located at the drill site. A pump14pressurizes and transfers the drilling fluid to the drilling rig1by means of a series of pipes5and a high-pressure flexible hose9. The high-pressure flexible hose9is attached to a top drive device18which hangs from the derrick20and controls the position of and rotates the drill sting12. The drilling fluid progresses from the top drive device18through the drill string12and down to the drill bit6. The drilling fluid helps the drill bit6cut the strata and then travels up the annular space3. As the drilling fluid travels up the annular space3it carries the cut strata4to the surface2. The drilling fluid makes it way from the annular space3to a shaker device19by means of a recirculating tube21. The shaker device19processes and removes solids from the drilling fluid and transfers it back to the tank14. Although the drill string12is illustrated as being rotated by a top drive device18, other configurations are possible.

During the process of the wellbore10being drilled, operators may desire to obtain a core from the wellbore10at specific points. In the aspects disclosed, a drill string12is placed within the wellbore10. The drill string12has an MWD device8within the drill pipe that is taking measurements of wellbore10characteristics during a coring of the wellbore10. A coring apparatus40is also conveyed in the wellbore10and connected below the drill pipe11to provide the capability of obtaining a core.

In the current embodiment, the core15is to be taken from the bottom of the wellbore10. During operations, an MWD device8is configured to take data from the environment within the coring apparatus40and transmit the data to the operator on the surface2, as seen inFIG.1. A non-limiting example of data obtained by the MWD device8is inner tube pressure, drill pipe pressure, temperature, shock, revolutions per minute, vibration and gamma.

Referring toFIG.2, a cross sectional view of a coring apparatus40and an MWD device8is illustrated. The coring apparatus40is configured with an outer tube42that extends along the length of the coring apparatus40. A bearing assembly44is provided so that the outer tube42may freely rotate around an inner tube46and the core15being drilled. The inner tube46is connected to a bearing assembly44by means of a flow diverter48. Drilling fluid that is passing within a space50between the inside of the coring apparatus40and the outside of the MWD device8is transferred to a space52between the outer tube42and the inner tube46by the flow diverter48. The bottom of the MWD device8protrudes through a center opening in the flow diverter48to the empty space within the inner tube46.

As the core15is drilled, the inner tube46accepts the core15and protects the core15from the high pressure drilling fluid. As the coring bit6bores deeper, the core15rises upwards within the inner tube46. The bearing assembly44allows the inner tube46to be stationary relative to the core15so that rotational motion of the outer tube42does not break the core15which can result in the core15jamming within the inner tube46.

Changing Inner tube46pressure may be sensed by a pressure sensor28within the MWD device8. Data from the pressure sensor28may be sent to an operator on surface2by the MWD device8.

In order to maintain pressures differences between the inner tube46and outer tube42, a seal30is provided between the MWD device8and the center opening of the flow diverter48. The seal30allows for any axial or rotational motion between the flow diverter48and the MWD device8.

The MWD device8is configured to provide real time data to an operator on surface2to allow the operator to understand the current down hole conditions at the bottom of the wellbore10. Degraded operations due to downhole characteristics being out of specification are avoided, however, with the aspects described. The MWD device8is configured to measure different characteristics of pressure, shock, revolutions per minute, vibration, and gamma as non-limiting embodiments. The operator can use the real time data to minimize costly down time due to cores breaking and or jamming within the inner tube46.

In embodiments, an arrangement80is provided to monitor the revolutions per unit time between the outer tube42and the inner tube46. To this end, embodiments provide for a sensor configured to measure revolutions per minute. This arrangement80may be located in the measurement while drilling part of the coring apparatus40.

In embodiments, pressure relief valves82are provided to allow for pressure to be removed within the inner tube46. As will be understood, at least one pressure relief valve82is provided. Other configurations provide for more than one valve. As will be understood, at least three pressure relief assemblies are provided. Conventional systems do not provide for this configuration or capability.

In embodiments, the build-up of pressure in the empty space86within the inner tube46may be released into the pumped drilling fluid within the empty space50of the flow diverter.

In further embodiments, a pressure sealed plug84is provided. The pressure sealed plug84is placed in the empty space86within the inner tube46. As the inner tube46moves over the core15, the pressure plug83is in contact with the top of the core15and allowed to move freely through the inner tube46as it is pushed by the core15. The movement of the pressure sealed plug84increases the pressure with the inner tube46to a point greater than the pumped drilling fluid within the empty space50of the flow diverter48until the pressure relief valves82actuate.

Referring toFIG.3, a method500for recovering a core15from a downhole environment is illustrated. The method includes, at502, providing an measure while coring or an MWD device8and a coring apparatus40within a wellbore10. The method further includes, at504, lowering the measure while coring or MWD device8and coring apparatus40to a selected position in the wellbore10where a core is desired to be obtained. The method500also includes, at506, starting the coring apparatus40. At508, the method progresses to conducting coring operations. At510, the method progresses with taking at least one measurement with the measure while coring or MWD device8within the coring apparatus40during an operational period of the coring apparatus40. At510, the method progresses with the MWD or measure while coring device8transmitting the at least one measurement to the operator on the surface2. As will be understood, during core recovery operations, a measurement may be taken by the measure while coring or MWD device8and compared to a threshold value. In embodiments, the threshold value may be a pressure measurement limit, a shock measurement limit, revolutions per minute, a vibration measurement limit and a gamma measurement limit. During that time, if measured values exceed a threshold value, coring operations may be terminated. Such termination may be automatic or a signal may be sent to an operator at the surface2, notifying the operator of an exceeded value.

As will be understood, the taking of the at least one measurement may be accomplished within the coring apparatus40by the measure while coring or MWD device8. A step of transmitting the data from the taking of the at least one measurement to the surface2may be accomplished. Transmission of the data to the surface2from the measure while coring or MWD device8may be done through mud pulse telemetry or EM telemetry as non-limiting embodiments. The measurement may be obtained within an inner tube area of the coring apparatus, as described above. Aspects of the disclosure provide for the device8to be moved independently from the remainder of the coring apparatus40, not seen by conventional apparatus.

Referring toFIG.4, a side view of one example embodiment of the disclosure is presented. An arrangement101, hereinafter UBHO, is illustrated at one end of an example embodiment of the disclosure. A pulser102is located within the arrangement101to create a pulsing action within the arrangement101. The pulser102acts in consort with a measurement while coring device8A, that is located within the tool. Unlike conventional apparatus, the measurement while coring device8A make take various measurements of the downhole environment and then transmit that data, through the pulser102to the uphole environment. In embodiments, the measurement while coring device8A may be independently retrievable from the remainder of the tool. A dynamic rotating seal30is provided that allows for sealing of internal components during operations. The dynamic rotating seal30provides superior sealing compared to diverter ball applications of conventional applications. For example, diverter ball systems use a ball like structure to divert materials, such as fluids from a first channel to a second channel, thus sealing a portion of the structure in certain cases. The dynamic rotation seal, however, allows for sealing capabilities of a relief valve housing109. Flow pressure within the tool may be measured, in embodiments, through a flow pressure sensor103located upstream of a bearing assembly44positioned to allow rotation, as needed, within portions of the tool. A separate flow diverter48is positioned within the tool for controlling flow of fluid. The flow diverter may be actuated, as necessary, by operators, thereby changing modes of operation of components within the tool. Referring toFIG.5, an expanded view ofFIG.4is illustrated. The relief valve housing109is illustrated in greater detail. A pressure relief valve82is located to allow pressure to be maintained up to a preset limit. The relief valve82may have a spring to allow for pressing the ball into a ball seat, thereby closing the pressure relief valve82. Such a pressure relief valve82is not found in conventional apparatus. In one embodiment, the flow pressure sensor103may be a component within the remainder of the tool, apart from the retrievable measurement while coring device. In this embodiment, the pressure sensor28may be isolated from other sections of the tool through the use of the dynamic rotating seal30. The seal30is located within the seal assembly housing111.

In one embodiment, a method for recovering a core from a downhole environment is disclosed. The method may include providing a measurements while drilling device and a coring apparatus within a wellbore. The method may also include positioning the coring apparatus and measurements while drilling device to an elevation of the wellbore where a core is to be taken and starting the coring apparatus. The method may also include starting coring operations. The method may also include taking at least one measurement in an inner tube of the coring apparatus during the coring operations.

In another embodiment, the method may further comprise a measurements while drilling device transmitting the at least one measurement to the surface where an operator can analyze the at least one measurement.

In another embodiment, the method may further comprise stopping the coring apparatus when the at least one measurement exceeds a threshold.

In another embodiment, the method may be performed wherein the at least one measurement is a pressure measurement.

In another embodiment, the method may be performed wherein the at least one measurement is a shock measurement.

In another embodiment, the method may be performed wherein the at least one measurement is a vibration measurement.

In another embodiment, the method may be performed wherein the at least one measurement is a gamma measurement.

In another embodiment, the method may be performed wherein the at least one measurement is a revolutions per time measurement.

In another example embodiment, the coring apparatus may comprise an outer tube and an inner tube placed within the outer tube. The coring apparatus may further comprise a bearing assembly configured to allow rotation of the outer tube around the inner tube. The coring apparatus may also comprise at least one arrangement wherein a measurements while drilling device positioned within the coring apparatus is configured to take at least one measurement during coring operations.

In another example, the measurements while drilling device may be configured wherein at least one arrangement is a pressure sensor configured to read a pressure within the coring apparatus.

In another example embodiment, the coring apparatus may be configured wherein the measurements while drilling device is configured to transmit data to a surface environment.

In another example embodiment, a method for recovering a core from a downhole environment is disclosed. The method may include providing a measurements while drilling device and a coring apparatus within a wellbore. The method may also include positioning the coring apparatus and measurements while drilling device to the bottom of the wellbore and starting the coring apparatus. The method may also provide for taking a pressure measurement within an inner tube of the coring apparatus during coring operations and transmitting the pressure measurement to an operator at a surface elevation.

In another example embodiment, the method may be performed wherein the taking of the at least one measurement within the inner tube of the coring apparatus during coring operations is with a sensor within the measurements while drilling device.

In another example embodiment, the method may be performed wherein the pressure measurement is made above the core within the inner tube.

In another example embodiment, the method may be performed wherein the pressure measurement is analyzed on surface by an operator.

The foregoing description of the embodiments has been provided for purposes of illustration and description. It is not intended to be exhaustive or to limit the disclosure. Individual elements or features of a particular embodiment are generally not limited to that particular embodiment, but, where applicable, are interchangeable and can be used in a selected embodiment, even if not specifically shown or described. The same may be varied in many ways. Such variations are not to be regarded as a departure from the disclosure, and all such modifications are intended to be included within the scope of the disclosure.

While embodiments have been described herein, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments are envisioned that do not depart from the inventive scope. Accordingly, the scope of the present claims or any subsequent claims shall not be unduly limited by the description of the embodiments described herein.