Patent Publication Number: US-2022213787-A1

Title: Method and device for improving wireline logging rate

Description:
TECHNICAL FIELD 
     This application is directed, in general, to monitoring of hydrocarbon wellbores and, more specifically, to a system and method for improving logging rate and logging duration. 
     BACKGROUND 
     In wireline logging, the conventional mode of operation is to transmit downhole logging data to the surface system in real time via digital cable telemetry. The fundamental limitation of this method is the transmission rate of the digital telemetry. The transmission rate can impose limits on such factors as the logging speed, measurement bandwidth, data resolution, a number of sensors used, a number of measurements taken. Overcoming these limitations can require multiple logging passes in order to acquire a sufficient number of data measurements with different assortments of logging tools thereby greatly extending onsite durations. 
    
    
     
       BRIEF DESCRIPTION 
       Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which: 
         FIG. 1  illustrates a diagram of an example of a wellbore logging system that accumulates downhole data measurements from a wellbore according to the principles of the disclosure; 
         FIG. 2  illustrates a diagram of an example of a downhole measurement environment constructed according to the principles of the disclosure; 
         FIG. 3  illustrates a more detailed example of a wellbore logging system constructed according to the principles of the disclosure; 
         FIG. 4  illustrates a diagram of another example of a wellbore logging system constructed according to the principles of the disclosure; 
         FIG. 5  illustrates a diagram of yet another example of a wellbore logging system constructed according to the principles of the disclosure; and 
         FIG. 6  illustrates a flow diagram of an example method of logging a wellbore carried out according to the principles of the disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     The disclosure addresses an alternative approach to capturing downhole data measurements in logging operations. Instead of limiting a wireline tool string performance with the restrictions of the wireline telemetry rate, the disclosed approach proposes to send a data compressed version of downhole tool data to a surface system and store the difference between the compressed data and the full resolution data (i.e., the residual data) in downhole mass storage. The compressed data rate can be subject to the wireline telemetry rate available, while the deployment time of logging tools in a wellbore is increased by storing only the residual data. 
     The disclosure enables wireline data logging at rates much higher than cable telemetry data rates, thereby providing higher resolution, higher bandwidth, more sensor channels, more data measurements, higher logging rates and more tool combinations than with cable telemetry alone. Data quality is monitored at the surface by viewing and analyzing the compressed version of the downhole wireline data, while only the residual difference between full resolution and compressed data is stored downhole, thereby increasing the deployment time. 
     For purposes of the disclosure, data compression is defined as a process of modifying, encoding or converting the bit-structure of data in such a way that it consumes less bandwidth for transmission and less space in memory, thereby reducing its transmission footprint or the storage size of one or more data instances or elements. Data compression can be either lossy or lossless. Lossless compression reduces bits by identifying and eliminating statistical redundancy. No information is lost in lossless compression. Lossy compression reduces bits by removing unnecessary or less important information. 
       FIG. 1  illustrates an example of a wellbore logging system, generally designated  100 , that accumulates downhole data measurements from a wellbore. During drilling of a wellbore  101  from a surface location  102 , it is usually desirable to know additional details about types of downhole formations or formation fluids and their associated characteristics through data collection employing formation logging. To accomplish this goal, the wellbore logging system  100  includes a derrick  130  that supports a traveling block  131  and a downhole logging device  110  employing a sonde or probe that is lowered by a retrievable logging cable  133  into the wellbore  101 . The retrievable logging cable  133  is usually a wireline, but may be a coiled tubing, an optical cable or other cable or conveyance suitable for a logging operation. Generally, any retrievable electrical cable conveyance that allows for the operation of a logging tool and provides depth control may be employed. 
     The downhole logging device  110  of the wellbore logging system  100  includes a depth determination unit (not shown) that forms part of a logging operation that can be used for accurate depth control. The depth determination unit in the downhole logging device  110  provides current depth data from the wellbore  101  through the retrievable logging cable  133 . The depth determination unit can include, for example, a gamma ray logging sensor unit or a casing collar locator. Furthermore, a load sensor attached to the retrievable logging cable  133  between an interface  115  and the downhole logging device  110  may be present to further aid in determination of the depth profile along the retrievable logging cable  133 . 
     The downhole logging device  110  may be lowered to a region of interest in the wellbore  101  using the depth data and pulled upward at a substantially constant speed to gain logging information for wellbore structures such as subterranean formations  125 ,  126  and  127 . Additionally, the downhole logging device  110  may have its wellbore speed modified or be held stationary within the wellbore  101  to gather wellbore information at one or more subterranean formations, such as the subterranean formations  125 ,  126  and  127 . 
     In the illustrated example of  FIG. 1 , the downhole logging device  110  includes a set or collection of downhole tools and shared downhole modules that are generally configured to gather wellbore and formation data and information and convey these to surface equipment  105  via the retrievable logging cable  133  or to a logging unit  140  (i.e., a surface logging facility) on return of the downhole logging device  110  to the surface  102 . The logging unit  140  is provided with all necessary equipment (e.g., processors, data storage, logging monitor) to accomplish downhole data storage, processing, analysis or monitoring. 
     The downhole logging device  110  includes one or more downhole tools having at least one data sensor each that captures downhole data measurements from the wellbore  101 . Additionally, the downhole logging device  110  also includes a data compression unit that provides a data compression portion and a residual data portion of the downhole data measurements, wherein the data compression portion of the downhole data measurements is provided for transmission to the surface equipment  105  for display on a logging monitor via the retrievable logging cable  133 , and the residual data portion is stored downhole. 
       FIG. 2  illustrates a diagram of an example of a downhole measurement environment, generally designated  200 , constructed according to the principles of the disclosure. The downhole measurement environment  200  includes a wellbore  205  containing a wellbore fluid  212 , a subterranean formation  207  containing a formation fluid  210 , and a retrievable logging cable  216  connected to a downhole logging device  220  as may be employed in the wellbore logging system  100  of  FIG. 1 . 
     The downhole logging device  220  includes a set or random collection of modules including a modem  224  connected to the retrievable logging cable  216 , a data compression unit  226 , a common mass storage memory  228 , and logging tools  235   1 ,  235   2 , . . . ,  235   X-1 ,  235   X , (referred to collectively as logging tools  235   1 - 235   X ), as shown. The downhole logging device  220  also includes module interconnections  237  that represent interconnections configured to convey measurement data and control instructions between modules. Each of the logging tools  235   1 - 235   X  has at least one sensor that provides downhole data measurements of interest to this logging operation. 
     The modem  224  provides an interface between the retrievable logging cable  216  and the module interconnections  237 . In this role, the modem  224  receives control directions for downhole modules from up-hole surface equipment and formats a part of the downhole data measurements for transmission to the up-hole surface equipment. This part of the downhole data measurements is processed in substantially real time for transmission up the retrievable logging cable  216  to the up-hole surface equipment (e.g., the surface equipment  105  of  FIG. 1 ) for data monitoring. 
     Correspondingly, the data compression unit  226  provides a data compression portion of the downhole data measurements from the logging tools  235   1 - 235   X . The data compression corresponding to this data compression portion may be tailored to separate or individual data requirements generated by each of the logging tools  235   1 - 235   X . Additionally, the data compression unit  226  provides a residual data portion of the downhole data measurements for storage downhole and later use. In one example, the residual data portions from the logging tools  235   1 - 235   X  are stored within each of the respective logging tools  235   1 - 235   X . In another example, all residual data portions are stored in the common mass storage memory  228 . Of course, some residual data portions may be stored in each location as operating conditions may dictate. 
       FIG. 3  illustrates a more detailed example of a wellbore logging system, generally designated  300 , within the environment of the system  100  of  FIG. 1 . The wellbore logging system  300  includes the surface equipment  105  having a data decompression unit  306 , a logging monitor and data storage unit  307  and a data compression controller  308 . The wellbore logging system  300  also includes the retractable logging cable  133 , a modem  315  and a downhole logging device  320  having a set of downhole tools (logging tool  1 -logging tool X), wherein at least one logging tool (e.g., Logging Tool  322 ) includes an individual mass storage memory (IMSM) and an IMSM 1   324  of the logging tool  1  is typical of all included IMSMs. The downhole logging device  320  of the wellbore logging system  300  additionally includes a data compression unit  325  having a data compression section  327 , a data decompression section  329 , and a subtraction section  331 . The wellbore logging system  300  further includes a common mass storage memory  335 . 
     Generally, a data compression portion of downhole data measurements is collected from a wellbore, such as the wellbore  101  of  FIG. 1 , for transmission to the surface equipment  105  in substantially real time (including real time), via the retractable logging cable  133 . The data decompression unit  306  provides a decompression of each data compression portion of these downhole data measurements for data monitoring and storage at the surface by the logging monitor and data storage unit  307 . This data monitoring assures that the data compression (and data decompression) provides data of sufficient quality to assure that downhole data acquisition is progressing along an acceptable path. Additionally, transmitting only the data compression portion of the downhole data measurements allows a maximum bandwidth utilization of the retractable logging cable  133 . 
     Downhole storage of a residual data portion of each downhole data measurement allows it to be recovered up-hole and recombined up-hole with its corresponding decompression of each data compression portion. For the case of lossless data compression of the data compression portion in recombination with its residual data portion, uncompressed data quality can be achieved while employing data compression to maximize logging cable transmission rates. In many cases, “lossy” data compression of the data compression portion can be selected to improve data logging cable transmission rates and provide acceptable recombination data quality. 
     The data compression controller  308  may be employed in concert with the retrievable logging cable  133  and the modem  315  to select and direct data compression characteristics or compression techniques tailored for optimization of different downhole logging tools. The data compression controller  308  may be employed to structure data compressions for a collection of downhole tools designed to operate at different sampling rates, a set of downhole tools designed to operate at about the same sampling rate or a combination of both. The primary role of the data compression controller  308  is to maintain downhole data quality at a specified minimum while maximizing transmission data speed of the retractable logging cable  133 . 
     The downhole logging device  320  includes logging tools ( 1 -X) wherein at least one logging tool of the downhole logging device  320  includes an individual mass storage memory (IMSM). In the illustrated example of  FIG. 3 , each downhole tool of the downhole logging device  320  includes an individual mass storage memory (IMSM) and at least one sensor configured to collect downhole data. Each of these sensors is typically a different type of sensor selected to cover a type or range of downhole data measurements applicable to the characteristics of and formations associated with each wellbore. 
     As noted earlier, the data compression unit  325  includes a data compression section  327 , a data decompression section  329  and a subtraction section  331 . Here the data compression unit  325  is in communication with the data compression controller  308  via the retractable logging cable  133  and a data path  326 , as shown, to select a type of data compression that corresponds to each of the downhole logging tools employed in the downhole logging device  320 . Each corresponding downhole data measurement is data compressed by the data compression section  327  for transmission up-hole via the retractable logging cable  133  and decompressed up-hole (data decompression  306 ) to provide logging data monitoring and storage by the up-hole logging monitor and data storage unit  307 . 
     The data compression unit  325  can vary its compression time and compression type depending on the type of data being compressed. The tailoring of compression times to meet data type and sampling requirements allows a more diverse set of downhole tools to be employed. Additionally, the data compression unit  325  can vary its sampling rate of each downhole tool as required by different downhole tools. Correspondingly, the sampling rate may be selected during logging operations to meet downhole tool or wellbore traversing situations or requirements. That is, some downhole tools may need to be sampled often, while others may require less sampling to meet data quality requirements. The data compression unit  325  can vary its type of data compression for each of the set of downhole tools employed and adapt its sampling rate to modify and improve data quality for each of the set of downhole tools or select just part of the set of downhole tools for data quality improvement. These settings can be selected at the start of a logging run or be modified during logging operations to focus on one or more specific downhole tools of interest. 
     Additionally, each downhole data compression undergoes a downhole data decompression by the data decompression section  329 . Generally, this downhole data decompression is subtracted from its corresponding downhole data measurement (data path  328 ) to provide a corresponding residual data portion for downhole storage. This downhole storage is normally provided by the common mass storage memory  335 . However, the downhole storage may be provided by an individual mass storage memory (IMSM) associated with the logging tool providing the downhole data measurement. This IMSM storage may be a temporary storage before being transferred (via the data path  333 ) to the common mass storage memory  335 , or it may be a more permanent storage that is not transferred to the common mass storage memory  335 . The residual data portions, so stored, are recombined up-hole, at the surface, with corresponding previously decompressed downhole data measurements to provide reconstructed downhole data measurements of enhanced fidelity. 
       FIG. 4  illustrates a diagram of an example of another wellbore logging system  400  constructed according to the principles of the disclosure. The wellbore logging system  400  extends the capability of the wellbore logging system  300  by including a downhole memory data path  410  to the modem  315 . This downhole memory data path  410  allows the downhole mass storage memories (e.g., the individual mass storage memories (IMSMs) and the common mass storage memory  335 ) to provide stored residual data portions to the modem  315  for transmission over the retrievable logging cable  133  to the surface equipment  105  during non-logging operating times and normally while a downhole tool is still within the wellbore. (Also, note that up-hole data decompression  306  is not required for processing the stored residual data portions.) Additionally, this feature may be employed to provide or test for full downhole data precision while still within the wellbore. This feature provides for proving various downhole tool combinations or arrangements prior to the start of logging operations. 
       FIG. 5  illustrates a diagram of an example of another wellbore logging system  500  constructed according to the principles of the disclosure. The wellbore logging system  500  extends the capability of the wellbore logging system  400  by including a residual data compression unit  505  before mass storage of residual data portions that have been data compressed. In addition to the added features discussed with respect to  FIG. 4 , this approach provides for additional downhole logging time by effectively extending existing downhole mass storage memory capability. 
       FIG. 6  illustrates a flow diagram of an example of a method of logging a wellbore, generally designated  600 , carried out according to the principles of the disclosure. The method  600  starts in a step  605 . 
     In a step  610 , downhole data measurements are received from one or more downhole tools in the wellbore. The one or more downhole tools each have at least one data sensor. A data compression portion and a residual data portion of the downhole data measurements are created downhole in a step  615 . The data compression portion of the downhole data measurements are transmitted to surface equipment in a step  620 . The data compression portion can be used at the surface for downhole data monitoring. In one example, the data compression portion of the downhole data measurements is transmitted to the surface equipment in real time. In a step  625 , the residual data portion of the downhole data measurements are stored downhole. The residual data portion can be compressed before being stored downhole. In one example, the downhole data measurements can be converted to a lossless data compression of the residual data portion before being stored downhole. 
     The data compression portion and a surface-recovered residual data portion are recombined up-hole in a step  630 . In one example, the residual data portion of the downhole data measurements is stored downhole, retrieved at the surface at the end of a logging run, and reunited with a decompression of the data compression portion of the downhole data measurements. In yet another example, the residual data portion is stored downhole and transmitted, or a portion thereof is transmitted, to the surface equipment between logging operations. The combined portions can then be recorded. The method  600  ends in a step  635 . 
     While the method disclosed herein has been described and shown with reference to particular steps performed in a particular order, it will be understood that these steps may be combined, subdivided, or reordered to form an equivalent method without departing from the teachings of the disclosure. Accordingly, unless specifically indicated herein, the order or the grouping of the steps are not limitations of the disclosure. 
     The description and drawings included herein serve to illustrate the principles of the disclosure. It will thus be appreciated that those skilled in the art will be able to devise various arrangements that, although not explicitly described or shown herein, embody the principles of the disclosure and are included within its scope. Furthermore, all examples recited herein are principally intended expressly to be for pedagogical purposes to aid the reader in understanding the principles of the disclosure and concepts contributed to furthering the art, and are to be construed as being without limitation to such specifically recited examples and conditions. Moreover, all statements herein reciting principles and aspects of the disclosure, as well as specific examples thereof, are intended to encompass equivalents thereof. Additionally, the term, “or,” as used herein, refers to a non-exclusive OR, unless otherwise indicated. Furthermore, directional terms, such as “above”, “below”, “upper”, “lower”, etc., are used only for convenience in referring to the accompanying drawings. Additionally, it is to be understood that the different embodiments of the disclosure may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., and in various configurations, without departing from the principles of the disclosure. Those skilled in the art to which this disclosure relates will appreciate that other and further additions, deletions, substitutions and modifications may be made to the described examples. 
     A portion of the above-described apparatus, systems or methods may be embodied in or performed by various digital data processors, wherein the processors are programmed or store executable programs of sequences of software instructions to perform one or more of the steps of the methods. The software instructions of such programs may represent algorithms and be encoded in machine-executable form on non-transitory digital data storage media, e.g., magnetic or optical disks, random-access memory (RAM), magnetic hard disks, flash memories, and/or read-only memory (ROM), to enable various types of digital data processors or computers to perform one, multiple or all of the steps of one or more of the above-described methods, or functions, systems or apparatuses described herein. 
     Portions of disclosed examples or embodiments may relate to computer storage products with a non-transitory computer-readable medium that have program code thereon for performing various computer-implemented operations that embody a part of an apparatus, device or carry out the steps of a method set forth herein. Non-transitory used herein refers to all computer-readable media except for transitory, propagating signals. Examples of non-transitory computer-readable media include, but are not limited to: magnetic media such as hard disks, floppy disks, and magnetic tape; optical media such as CD-ROM disks; magneto-optical media such as floppy disks; and hardware devices that are specially configured to store and execute program code, such as ROM and RAM devices. Examples of program code include both machine code, such as produced by a compiler, and files containing higher level code that may be executed by the computer using an interpreter. 
     Various aspects of the disclosure can be claimed including the apparatuses, systems and method as disclosed herein. Aspects disclosed herein include: 
     A. A downhole logging device, including (1) one or more downhole tools having at least one data sensor each and configured to capture downhole data measurements from a wellbore, and (2) a data compression unit configured to provide a data compression portion and a residual data portion of the downhole data measurements, wherein the data compression portion of the data measurements is provided for transmission to surface equipment, and the residual data portion is stored downhole. 
     B. A method of logging a wellbore, including (1) receiving downhole data measurements from one or more downhole tools having at least one data sensor; (2) creating, downhole, a data compression portion and a residual data portion of the downhole data measurements; (3) transmitting the data compression portion of the downhole data measurements to surface equipment, and (4) storing, downhole, the residual data portion of the downhole data measurements. 
     C A wellbore logging system, including: (1) surface equipment operable for monitoring logging operations in a wellbore based on downhole data measurements; and (2) a downhole logging device, coupled to the surface equipment through the downhole communications link, having (a) one or more downhole tools having at least one data sensor each that captures the downhole data measurements from the wellbore, and (b) a data compression unit that provides a data compression portion and a residual data portion of the downhole data measurements, wherein the data compression portion is provided, via the downhole communications link, to the surface equipment for the monitoring, and the residual data portion is stored downhole. 
     Each of aspects A, B, and C can have one or more of the following additional elements in combination: 
     Element 1: wherein the data compression portion of the data measurements is provided for transmission to the surface equipment in substantially real time. Element 2: wherein the residual data portion of the downhole data measurements stored downhole is retrieved when the one or more downhole tools is returned to the surface. Element 3: wherein a corresponding residual data portion is recombined with a decompression of a data compression of the downhole data measurements. Element 4: wherein the residual data portion of the downhole data measurements is provided for transmission to the surface equipment while stored downhole. Element 5: wherein the residual data portion of the downhole data measurements is data compressed before being stored downhole. Element 6: wherein the residual data portion is data compressed using a lossless data compression. Element 7: further comprising a data compression controller configured to select downhole data compression characteristics tailored to match a specific downhole data measurement requirement for at least one type of the downhole data measurements. Element 8: wherein the transmitting is performed in substantially real time. Element 9: further comprising retrieving at the surface the residual data portion of the downhole data measurements stored downhole at the end of a logging run. Element 10: further comprising combining the residual data portion of the downhole data measurements at the surface with a decompression of the corresponding data compression portions of the downhole data measurements. Element 11: wherein the transmitting the data compression portion is at a first time and the method further comprises transmitting at least a part of the residual data portion to the surface equipment at a different second time before the end of a logging run. Element 12: further comprising converting the residual data portion to a lossless residual data compression before being stored downhole. Element 13: wherein the surface equipment retrieves the residual data portion at the end of a logging run and recombines the residual data portion at the surface with a decompression of the data compression portion. Element 14: wherein the downhole logging device further includes a modem that is coupled to the downhole communications link and that transmits the residual data portion of the downhole data measurements to the surface equipment while stored downhole. Element 15: further comprising a residual data compression unit that data compresses the residual data portion before it is stored downhole. Element 16: further comprising a residual data compression unit that data compresses the residual data portion before it is stored downhole. Element 17: wherein the surface equipment includes a surface data compression controller that selects downhole data compression characteristics tailored to match a specific downhole data measurement requirement for at least one type of the downhole data measurements.