Patent Publication Number: US-2012026002-A1

Title: System and Method for Remote Well Monitoring

Description:
BACKGROUND OF THE INVENTION 
     The present disclosure relates generally to the field of telemetry systems for transmitting information through a flowing fluid. More particularly, the disclosure relates to the field of signal detection in such a system. 
     Drilling and home office personnel are being asked to remotely monitor multiple wells at a time. While online, real time monitoring is available in the office/home environment, the continuous nature of the drilling operational process makes remote well monitoring using personal mobile devices would allow substantially continuous access to well site data. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       A better understanding of the present invention can be obtained when the following detailed description of example embodiments are considered in conjunction with the following drawings, in which: 
         FIG. 1  is a network diagram of an example system for monitoring wellsite data; 
         FIG. 2  illustrates an example IHS  33  that may be used for acquiring and monitoring wellsite data; 
         FIG. 3  shows the architecture of one example of a personal mobile device; 
         FIG. 4  shows an example of a wellsite drilling system; 
         FIG. 5A  shows an example of a wellsite wireline logging system; 
         FIG. 5B  shows an example of a wellsite completion system; 
         FIG. 6  shows an example of a wellsite production system; 
         FIG. 7  shows another example of a system for remote monitoring and control of a wellsite system; 
         FIG. 8  is an example flow diagram for monitoring of wellsite data; 
         FIG. 9  shows an example of a graphical user interface (GUI) screenshot of operational drilling and logging wellsite data; 
         FIG. 10  illustrates an example GUI screenshot on a personal mobile device (PMD) for user login; 
         FIG. 11  illustrates a GUI screenshot showing an expanded tree structure for an interactive selection of operational screens and well logging plots on a PMD; 
         FIG. 12  illustrates a GUI screenshot of an operational screen with operating data and an interactive menu bar on a PMD; 
         FIG. 13  illustrates a GUI screenshot of a well log displayed on a PMD; 
         FIG. 14  illustrates a GUI screenshot of a command screen displayed on a PMD; and 
         FIG. 15  shows one example of a flow chart for one embodiment of a method according to the present disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     A system  100  comprises a network  102  that couples together at least one personal mobile device (PMD)  106 A- 106 N to at least one wellsite  104 A- 104 N. The wellsites  104 A- 104 N may comprise information handling systems (IHS)  33 A- 33 N that may collect, process, store, and display various wellsite data and real time operating parameters. For example, IHS  33  may receive wellsite data from various sensors at the wellsite (including downhole and surface sensors), as described below. Network  102  may comprise multiple communication networks working in conjunction with multiple servers. 
     For purposes of this disclosure, an information handling system may comprise any instrumentality or aggregate of instrumentalities operable to compute, classify, process, transmit, receive, retrieve, originate, switch, store, display, manifest, detect, record, reproduce, handle, or utilize any form of information, intelligence, or data for scientific, control, or other purposes. 
     The wellsite data may be replicated at one or more remote locations relative to the wellsite. For example, IHS  33  may transmit the wellsite data to one or more of the non-volatile machine-readable media  108 . In addition IHS  33  may transmit data via network  102  and radio frequency transceiver  118  to PMD&#39;s  106 A-N. In some embodiments, the non-volatile machine-readable media  108  may be representative of servers for storing the wellsite data therein. The network communication may be any combination of wired and wireless communication. In one example, at least a portion of the communication is transferred across the internet using TCP/IP internet protocol. In some embodiments, the network communication may be based on one or more communication protocols (e.g., HyperText Transfer Protocol (HTTP), HTTP Secured (HTTPS), Application Data Interface (ADI), Well Information Transfer Standard Markup Language (WITSML), etc.). A particular non-volatile machine-readable medium  108  may store data from one or more wellsites and may be stored and retrieved based on various communication protocols. The non-volatile machine-readable media  108  may include disparate data sources (such as ADI, Javi Application Data Interface (JADI), Well Information Transfer Standard Markup Language (WISTML), Log ASCII Standard (LAS), Log Information Standard (LIS), Digital Log Interchange Standard (DLIS), Well Information Transfer Standard (WITS), American Standard Code for Information Interchange (ASCII), OpenWorks, SiesWorks, Petrel, Engineers Data Model (EDM), Real Time Data (RTD), Profibus, Modbus, OLE Process Control (OPC), various RF wireless communication protocols (such as Code Division Multiple Access (CDMA), Global System for Mobile Communications (GSM), etc.), Video/Audio, chat, etc.). While the system  100  shown in  FIG. 1  employs a client-server architecture, embodiments are not limited to such an architecture, and could equally well find application in a distributed, or peer-to-peer, architecture system. 
       FIG. 2  illustrates an example IHS  33  that may be used for acquiring and monitoring wellsite data, according to some embodiments. In the example shown IHS  33  comprises processor(s)  302 . IHS  33  may also comprise a memory unit  330 , processor bus  322 , and Input/Output controller hub (ICH)  324 . The processor(s)  302 , memory unit  330 , and ICH  324  are coupled to the processor bus  322 . The processor(s)  302  may comprise any suitable processor architecture. IHS  33  may comprise one, or more, processors, any of which may execute a set of instructions in accordance with embodiments of the invention. 
     The memory unit  330  may store data and/or instructions, and may comprise any suitable memory, such as a dynamic random access memory (DRAM). IHS  33  also comprises hard drives such as IDE/ATA drive(s)  308  and/or other suitable computer readable media storage and retrieval devices. A graphics controller  304  controls the display of information on a display device  306 , according to some embodiments of the invention. 
     The input/output controller hub (ICH)  324  provides an interface to I/O devices or peripheral components for IHS  33 . The ICH  324  may comprise any suitable interface controller to provide for any suitable communication link to the processor(s)  302 , memory unit  330  and/or to any suitable device or component in communication with the ICH  324 . In one embodiment of the invention, the ICH  324  provides suitable arbitration and buffering for each interface. In one embodiment a wellsite monitoring application  335  and a mobile wellsite monitoring application  336  are stored in memory unit  330 . Mobile wellsite monitoring application  336  interfaces with wellsite monitoring application  335  and enables PMD  106  to access, over network  102 , the data collected and processed by wellsite monitoring application  335 . 
     ICH  324  may also interface with downhole logging tools  360  (described below), through interface electronics  350 . Interface electronics  350  may contain analog and/or digital circuitry to at least receive signals from logging tools  360 , convert them to data suitable for input to processor  302 . Such circuits are known to those skilled in the art, and are not described in detail here. 
     For some embodiments of the invention, the ICH  324  provides an interface to one or more suitable integrated drive electronics (IDE) drives  308 , such as a hard disk drive (HDD) or compact disc read only memory (CD ROM) drive, or to suitable universal serial bus (USB) devices through one or more USB ports  310 . In one embodiment, the ICH  324  also provides an interface to a keyboard  312 , a mouse  314 , a CD-ROM drive  318 , one or more suitable devices through one or more firewire ports  316 . For one embodiment of the invention, the ICH  324  also provides a network interface  320  though which IHS  33  can communicate with other computers and/or devices. 
       FIG. 3  shows the architecture of one example of PMD  106 . As shown, PMD  106  comprises a processor  400  in data communication with a memory  405  suitable for storing an operating system (OS)  406 . Processor  400  is connected by an interface bus  410  to various components comprising: a radio frequency transceiver  412  that may comprise a wireless local area network (WLAN) transceiver  415 ; a cellular transceiver  420 ; or both. Other components comprise an input/output device  425 ; and a graphical display  435 . In one example, WLAN transceiver  415  is a Wi-Fi device. Cellular transceiver  420  may transmit and receive signals in any suitable cellular protocol including, but not limited to CDMA and GSM. 
     Input/output device  425  may comprise a keyboard  430 . Keyboard  430  may comprise physical keys, or alternatively, keyboard  430  may be implemented as a touchscreen keyboard. Input/output device  425  may also comprise a microphone for inputting voice commands using voice recognition applications known in the art. In one example, graphic display  435  comprises a suitable graphic display having a pixel resolution of at least 160 by 160 pixels. In one embodiment, personal mobile device  106  weighs no more than about one pound. In one example, OS 406 is able to run an internet/intranet web browser  408  enabling HTML. In another example, OS 406 may also be able to run an object oriented scripting language (OOSL)  409 , for example the Javascript brand object oriented scripting language developed by Sun Microsystems, Inc. 
     In one embodiment, PMD  106  described above may comprise a smartphone. Such a smartphone may include, but are not limited to: the Iphone by Apple Inc.; various Blackberry models by Research in Motion, Inc.; the Palm Treo by Palm Inc.; and any other suitable smartphone now known or developed in the future that has the characteristics described above. Each of the phones described above has a suitable OS for executing the actions and instructions described above. Alternatively, PMD  106  may comprise a personal digital assistant (PDA) device. PDA&#39;s have many of the functional attributes of the smartphone described but may not have voice communication commonly associated with the smartphone. Examples include, but are not limited to, Apple&#39;s IPOD Touch brand and Hewlett Packard&#39;s IPAQ brand of PDA&#39;s. In addition, any satellite phone having the characteristics described herein may be used. 
     Described below are operational examples of wellsite systems, for example, a drilling and logging system, and a production system, where data may be acquired, processed, and transmitted over the internet/intranet to such a PMD as described above. Referring to  FIG. 4 , a drilling system  104  is illustrated which includes a drilling derrick  10 , constructed at the surface  12  of the well, supporting a drill string  14 . The drill string  14  extends through a rotary table  16  and into a borehole  18  that is being drilled through earth formations  20 . The drill string  14  may include a kelly  22  at its upper end, drill pipe  24  coupled to the kelly  22 , and a bottom hole assembly  26  (BHA) coupled to the lower end of the drill pipe  24 . The BHA  26  may include drill collars  28 , an MWD tool  30 , and a drill bit  32  for penetrating through earth formations to create the borehole  18 . In operation, the kelly  22 , the drill pipe  24  and the BHA  26  may be rotated by the rotary table  16 . Alternatively, or in addition to the rotation of the drill pipe  24  by the rotary table  16 , the BHA  26  may also be rotated, as will be understood by one skilled in the art, by a downhole motor (not shown). The drill collars add weight to the drill bit  32  and stiffen the BHA  26 , thereby enabling the BHA  26  to transmit weight to the drill bit  32  without buckling. The weight applied through the drill collars to the bit  32  permits the drill bit to crush the underground formations. 
     As shown in  FIG. 4 , BHA  26  may comprise an MWD tool  30 , which may be part of the drill collar section  28 . As the drill bit  32  operates, drilling fluid (commonly referred to as “drilling mud”) may be pumped from a mud pit  34  at the surface by pump  15  through standpipe  11  and kelly hose  37 , through drill string  14 , indicated by arrow  5 , to the drill bit  32 . The drilling mud is discharged from the drill bit  32  and functions to cool and lubricate the drill bit, and to carry away earth cuttings made by the bit. After flowing through the drill bit  32 , the drilling fluid flows back to the surface, indicated by arrow  6 , through the annular area between the drill string  14  and the borehole wall  19 , or casing wall  29 . At the surface, it is collected and returned to the mud pit  34  for filtering. In one example, the circulating column of drilling mud flowing through the drill string may also function as a medium for transmitting pressure signals  21  carrying information from the MWD tool  30  to the surface. 
     MWD tool  30  may comprise sensors  39  and  41 , which may be coupled to appropriate data encoding circuitry, such as an encoder  38 , which sequentially produces encoded digital data electrical signals representative of the measurements obtained by sensors  39  and  41 . While two sensors are shown, one skilled in the art will understand that a smaller or larger number of sensors may be used without departing from the scope of the present invention. The sensors  39  and  41  may be selected to measure downhole parameters including, but not limited to, environmental parameters, directional drilling parameters, and formation evaluation parameters. Such parameters may comprise downhole pressure, downhole temperature, the resistivity or conductivity of the drilling mud and earth formations, the density and porosity of the earth formations, as well as the orientation of the wellbore. Sensor examples include, but are not limited to: a resistivity sensor, a nuclear porosity sensor, a nuclear density sensor, a magnetic resonance sensor, and a directional sensor package. In addition, formation fluid samples and/or core samples may be extracted from the formation using formation tester. Such sensors and tools are known to those skilled in the art. 
     In one example, data representing sensor measurements of the parameters discussed above may be generated and stored in the MWD tool  30 . Some or all of the data may be transmitted by data signaling unit  35 , through the drilling fluid in drill string  14 . A pressure signal travelling in the column of drilling fluid may be detected at the surface by a signal detector unit  36  employing a pressure detector  80  in fluid communication with the drilling fluid. The detected signal may be decoded in IHS  33 . In one embodiment, a downhole data signaling unit  35  is provided as part of MWD tool  30 . Data signaling unit  35  may include a pressure signal transmitter  100  for generating the pressure signals transmitted to the surface. The pressure signals may comprise encoded digital representations of measurement data indicative of the downhole drilling parameters and formation characteristics measured by sensors  39  and  41 . Alternatively, other types of telemetry signals may be used for transmitting data from downhole to the surface. These include, but are not limited to, electromagnetic waves through the earth and acoustic signals using the drill string as a transmission medium. In yet another alternative, drill string  14  may comprise wired pipe enabling electric and/or optical signals to be transmitted between downhole and the surface. In one example, IHS  33  may be located proximate the rig floor. Alternatively, IHS  33  may be located away from the rig floor. In one embodiment, IHS  33  may be incorporated as part of a logging unit. In one embodiment, a surface transmitter  50  may transmit commands and information from the surface to the downhole MWD/LWD system. For example, surface transmitter  50  may generate pressure pulses into the flow line that propagate down the fluid in drill string  14 , and may be detected by pressure sensors in MWD tool  30 . The information and commands, may be used, for example, to request additional downhole measurements, to change directional target parameters, to request additional formation samples, and to change downhole operating parameters. 
     In addition to downhole measurements, various surface parameters may be measured using sensors  17 ,  18  located at the surface. Such parameters may comprise rotary torque, rotary RPM, well depth, hook load, standpipe pressure, and any other suitable parameter of interest. 
     The surface and downhole parameters may be processed by IHS  33  using software for the operation and management of drilling, completion, production, and servicing of onshore and offshore oil and gas wells, for example the Insite® brand of software owned by Halliburton, Inc. In one embodiment, the software produces data that may be presented to the driller and operational personnel in a variety of visual display presentations, for example, on display  40 . Alternatively, any suitable processing application package may be used. 
     The processed information may be transmitted by IHS  33  via communication link  76  to network  102  that couples one or more wellsites to one or more PMD&#39;s  106  via a radio frequency transceiver  108 , for example, a cellular link, a WiFi link, and a satellite link. In one embodiment, PMD  106  may be used to transmit commands back to IHS  33 , via the RF and network path. Such commands may be used, for example, to request additional downhole measurements, to change directional target parameters, to request additional formation samples, and to change downhole operating parameters 
       FIG. 5A  illustrates an example of a wireline logging system  500 . A derrick  516  supports a pulley  590 . Drilling of oil and gas wells is commonly carried out by a string of drill pipes connected together so as to form a drilling string that is lowered through a rotary table  510  into a wellbore or borehole  512 . Here it is assumed that the drilling string has been temporarily removed from the borehole  512  to allow a wireline logging tool  570 , such as a probe or sonde, to be lowered by wireline or logging cable  574  into the borehole  512 . The wireline logging cable  574  may have one or more electrical and/or optical conductors for communicating power and signals between the surface and the logging tool  570 . Typically, the tool  570  is lowered to the bottom of the region of interest and subsequently pulled upward. During the upward trip, sensors  505  located in the tool  570  may be used to perform measurements on the subsurface formations  514  adjacent the borehole  512  as they pass by. Measurements may comprise those described above with respect to MWD/LWD operations. 
     The measurement data can be communicated to an IHS  533  in logging unit  592  for storage, processing, and analysis. The logging facility  592  may be provided with electronic equipment for various types of signal processing. Similar log data may be gathered and analyzed during drilling operations (e.g., during Logging While Drilling, or LWD operations). The log data may also be displayed at the rig site for use in the drilling and/or completion operation on display  540 . In one example, measured wellsite data may be processed by a wellsite monitoring application resident in IHS  533  as described above. The processed information may be transmitted by IHS  533  via communication link  76  to network  102  that couples one or more wellsites to one or more PMD&#39;s  106  via a radio frequency transceiver  108 , for example, a cellular link or a WiFi link. In one embodiment, PMD  106  may be used to transmit commands back to IHS  533 , via the RF and network path. Such commands may comprise, for example, requests for additional downhole measurements, changes in measurement parameters, and requests for additional formation samples. 
       FIG. 5B  shows an example wireline completion system using deployment equipment similar to that of  FIG. 5A . In this example, a perforating tool  590  is connected to wireline  574  and is deployed in casing  597 . Perforating tool  590  may have electronic circuits for interfacing with surface IHS  533 . In addition, perforating tool  590  may have sensors (not shown) for detecting each casing joint so that the location of the perforating tool  590  may be accurately determined at the surface. Perorating tool comprises shaped explosive charges  596  that may be triggered from the surface to create perforations  591  through casing  597  and into formation  514 . Such penetrations provide a flow path for fluids in the formation to the production tubing. In one example, information, for example the location of the perforating tool  590  and the logging information for the formation  514  proximate the perforating tool may be transmitted may be transmitted by IHS  533  via communication link  76  to network  102  that couples one or more wellsites to one or more PMD&#39;s  106  via a radio frequency transceiver  108 , for example, a cellular link or a WiFi link. In one embodiment, PMD  106  may be used to transmit commands back to IHS  533 , via the RF and network path. Such commands may comprise, for example, commands to perforate at an indicated downhole location. 
       FIG. 6  shows an example of a production well system  600 . A production tubing string  606  is disposed in a well  608 . One or more interval control valves  610  are disposed in tubing string  606  and provide an annulus to tubing flow path  602 . Sensors  630  may be incorporated in interval control valves  610  detecting reservoir data. Interval control valve  610  may include a choking device that isolate the reservoir from the production tubing  606 . It will be understood by those skilled in the art that there may be an interrelationship between one control valve and another. For example, as one valve is directed to open, another control valve may be directed to close. A production packer  660  provides a tubing-to-casing seal and pressure barrier, isolates zones and/or laterals from the well bore  608  and allows passage of an electro-hydraulic umbilical  620 . Packer  660  may be a hydraulically set packer that may be set using the system data communications and hydraulic power components. The system may also include other components well known in the industry including safety valve  631 , control line  632 , gas lift device  634 , and disconnect device  636 . It will be understood by those skilled in the art that the well bore may be cased partially having an open hole completion or may be cased entirely. 
     A surface IHS  633  may act according to programmed instructions to operate the downhole interval control valves  610  in response to sensed reservoir parameters. In one example, measured reservoir data may be processed by a wellsite production monitoring application resident in IHS  633 . The processed information may be transmitted by IHS  633  via communication link  76  to network  102  that couples one or more wellsites to one or more PMD&#39;s  106  via a radio frequency transceiver  108 , for example, a cellular link or a WiFi link. In one embodiment, PMD  106  may be used to transmit commands back to IHS  633 , via the RF and network path. Such commands may comprise, for example, requests for additional reservoir measurements, and commands to open or close various interval control valves  610 . In one embodiment, data from multiple wells in a production field may be processed and transmitted. 
       FIG. 7  shows an example of a system  700  for remote monitoring and control of a wellsite system. Well system  701  may be at least one of drilling system, a logging system, a completion system, a production system and combinations thereof, as previously described. IHS  733  acquires downhole measurement data from sensors  710  in well  702 . IHS  733  may process this data as described previously using an application program resident in IHS  733 . In one example IHS  733  may display portions of the data on display  740 . In one example, the processed data may be transmitted using a suitable protocol across a network  703  to IHS  734  at a host facility. Network  703  may be an intranet, the internet, or a combination thereof. IHS  734  may have additional application programs resident therein to further process the wellsite data and display information on display  760 . IHS  734  is in data communication with IHS  735 . IHS  735  may act as a network server. IHS  735  has a template generation application program  736  in a memory of IHS  735 . Template generation program  736  provides predetermined format templates, T 1 -T n  that present at least portions of the data from wellsite  701  in a suitable visual format, also called a virtual terminal herein, that facilitates client interpretation of wellsite status. Templates are available based on the user authentication privileges during login. Each template provides a screenshot of at least one operational and/or logging process. As used herein, a screenshot is an image of the visible items displayed on a display, for example the data displayed on displays  740  and  760 . In one example, the data is presented in substantially real time (allowing for network transmission delays). In one embodiment, the visual presentation template T may be captured and transmitted, on demand, over network  704 , and via an RF link  108  to a user&#39;s PMD  106 . In addition, predetermined commands, as described previously, may be returned from PMD  106  across the system  700  to effect changes in operation at wellsite  701 . 
       FIG. 8  is a flow diagram for monitoring of wellsite data, according to some embodiments. The flow diagram  900  is described with reference to the system of  FIG. 7 . The flow diagram commences at block  901 . 
     At block  901 , the user invokes the client virtual terminal on PMD  106 , in some embodiments this could comprise internet browser. 
     At block  902 , the user supplies authentication credentials which are conveyed to the Template Server application running on IHS  735  via an appropriate communication protocol. The communication protocol could be HTTP or HTTPS or any number of internet protocols. 
     At block  904 , template server reviews authentication credential, and if successful, execution continues to block  905 . 
     At block  905 , a virtual Well/Template selection page is created and conveyed via the communication protocol back to the client. 
     At block  906 , the virtual Well/Template selection page is rendered to the local physical display. 
     At block  907 , the user selects which template application to run. That information is then conveyed to Template Server  735  via the communication protocol. 
     At block  908 , the Template Server invokes an instance of the selected template. 
     At block  909 , the application retrieves data and builds the resulting display and returns that image to the client. This initiation of the execution may or may not be in response to receiving real time wellsite data updates. For example, the wellsite data may be stored for subsequent monitoring. In some embodiments, the processor may retrieve the wellsite monitoring application and initiate execution. The processor may retrieve the wellsite monitoring application from a local or remote machine-readable media. For example, the processor may retrieve the wellsite monitoring application from the non-volatile machine-readable memory. The monitoring application is designed, built and tested to run on the operating system of the application server. The hardware and operating system of the client machine does not have to support the monitoring application only the virtual terminal software, for example a web browser. 
     At block  910 , the client renders the virtual display to the specific screen hardware to which it is attached. Execution continues to block  911 . 
     At block  911 , user input devices are sampled, the resulting values are then conveyed to the application via the communication protocol. 
     At block  912 , the user inputs from the client are evaluated by the monitoring application and applied appropriately. These user inputs could include commands which are forwarded to the IHS at the well site being monitored, and in turn forwarded to either surface or downhole equipment. 
     At block  917 , execution continues and the user input is evaluate to determine if it is a local application command or a command intended to be forwarded to the wellsite. If the command is a wellsite destined command it is forwarded to the IHS at the well site being monitored, via the Communication protocol  918 . The Communication protocol would forward the command to IHS  735 . IHS  735  would forward the command to IHS  734 , which would in turn forwarded the command to the wellsite IHS  733  for and either surface or downhole equipment. 
     At block  914 , execution continues and if the user selected something other than exit of the application, execution continues at block  909 , and processes this loop continuously until the user selects exit. If the user selects exit, execution continues at block  916  and a message is conveyed back to the client. At block  913  the server evaluates if the user has selected exit. If no, execution continues to block  910  and continues in this loop until the user does select exit. 
     At block  916  the monitoring application terminates and an application termination message is sent via the communication protocol to the client. The client evaluates the termination message at block  913  and execution flow in the application returns to block  904  awaiting a login request. 
       FIG. 9  shows an example of a graphical user interface (GUI) screenshot  920 , also called a dashboard shot, of operational drilling and logging wellsite data displayed by the wellsite monitoring application  335 . In one embodiment, mobile wellsite monitoring application  336  captures at least a portion of the data shown in screenshot  920 , according to a predetermined template, as an image and transmits the image over network  102  via an RF link  108  to PMD  106 . Various information may be shown in different predetermined selectable screenshots. In one embodiment, data from different wells may be selected by an expandable and contractible tree structure. 
       FIGS. 10-13  show different GUI screenshots for monitoring wellsite data on PMD  106 .  FIG. 10  illustrates an example GUI screenshot on PMD  106  for user login  1001 , via cellular/WiFi communication, over network  102  to the mobile wellsite monitoring application  336 , or to template server  735 .  FIG. 11  illustrates a GUI screenshot showing an expanded tree structure for an interactive selection of operational screenshot screens  1105  and well logging plots  1110 . The expandable/contractible tree structure is enabled by the use of object oriented scripting language, for example Javascript. 
       FIG. 12  illustrates a GUI screenshot of an operational dashboard with operating data  1205  and an interactive menu bar  1202 . Interactive menu bar allows the user to select updates of the operational dashboard data using a manual refresh button or by selecting an automatic refresh at predetermined time intervals. An object oriented scripting language, for example Javascript, enables just the images on the display page to be updated and not the rest of the content of the page. It should be noted that, while shown in black and white in the attached figures, color features may be added to the screens to indicate out of range parameters. 
       FIG. 13  illustrates a GUI screenshot of a well log  1300  displayed on PMD  106 . While described above as simply reviewing wellsite data, PMD  106  may also be used to input changes to well site parameters. For example, changes in alarm ranges, directional targets, weight on bit, etc. may be dictated by remote evaluation of the data viewed on PMD  106 . 
       FIG. 14  illustrates a GUI screenshot of a command screen displayed on PMD  106 . The commands displayed are examples of the commands discussed above and may be invoked and transmitted back to the wellsite via the network  102  for execution at the wellsite. 
       FIG. 15  shows one example of a flow chart for one embodiment of a method according to the present disclosure. In logic box  1505 , a wellsite parameter of interest is measured. In logic box  1510 , a predetermined screenshot related to the parameter of interest is generated. In logic box  1515 , the predetermined screenshot is transmitted via a radio frequency transceiver to a personal mobile device. In logic box  1520 , the predetermined screenshot is displayed on the personal mobile device. In logic box  1525 , interactive selections are displayed on the personal mobile device to a user. In logic box  1530 , the user&#39;s interactive selections are transmitted via a radio frequency transceiver to the wellsite and the operational parameter is changed. 
     The methods described above may also be embodied as a set of instructions on a computer readable medium comprising ROM, RAM, CD ROM, DVD, FLASH or any other computer readable medium, now known or unknown, that when executed causes a computer such as, for example, a processor in IHS  33 ,  533 ,  633 ,  733 ,  734 ,  735  to implement the methods of the present invention. 
     The discussion above has been primarily directed to the drilling and logging operation. One skilled in the art will appreciate that similar data review and control will also be advantageous to production systems, for example, as described in  FIG. 6 . 
     Numerous variations and modifications will become apparent to those skilled in the art. It is intended that the following claims be interpreted to embrace all such variations and modifications.