OIL FIELD SYSTEM DATA RECORDER FOR FAILURE RECONSTRUCTION

Abstract

A plurality of inputs from an oil field system is monitored. It is determined that a failure in the oil field system has occurred. In response, a mechanical release mechanism to release an apparatus is triggered. A remote signal is provided to report a subset of the inputs to a remote location as the processor is monitoring the signal inputs. A memory stores the inputs. An output is provided through which the stored inputs can be extracted to analyze the failure in the oil field system.

Description

BACKGROUND

Oil field system failures are sometimes catastrophic and result in the complete destruction of the system. In addition, the personnel working on such an oil field system when such a failure occurs are sometimes killed or injured so that they are unavailable afterwards to help reconstruct the events that led to the failure. In addition, the intense scrutiny that sometimes follows such a failure may cause such personnel, either intentionally or unintentionally, to remember events differently than they actually occurred. Reconstruction such failures is important to avoid making the same mistakes in the use of future oil field systems.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a block diagram of a black box.

FIG. 2 illustrates a plan for an oil field system.

FIG. 3 is a flow chart.

DETAILED DESCRIPTION

For the purposes of this application, an oil field system is defined to be a drilling rig (on shore or off shore), a production rig, a workover rig (wireline, coiled tubing (wired or unwired)), or any other similar system. While many of the examples described in this application relate to offshore rigs, it will be understood that the techniques and apparatuses described herein could be used on any oil field system.

In one embodiment, an oil field system data recorder (or “black box” or “apparatus”) is a secure repository that records detailed activity in the oil field system in the form of data generated by sensors, cameras, microphones (including those recording discussions taking place during decision-making meetings), and data considered useful in evaluating the health status of the oil field system and associated systems. In particular, in one embodiment, the black box records sufficient information to reconstruct or reenact catastrophic failures, fires, blow outs, etc. that the oil field system might experience.

In one embodiment, illustrated in FIG. 1, the black box is a self-contained apparatus 100 that is engineered to survive fire, heat, explosion, and water submersion. In one embodiment, the black box is an enclosure that satisfies one or more of the standards set by The Association of Electrical and Medical Imaging Equipment Manufacturers (“NEMA”) for enclosures.

In one embodiment, the black box 100 includes a primary power source 105, such as a standard power supply. In one embodiment, the primary power source 105 receives power from the oil field system 110 in the form of line voltage, such as 110 VAC 60 Hz power. In one embodiment, the primary power source 105 receives power from another source, such as a solar panel, a wind mill, a power source using power generated by the motion of waves, or a similar source.

In one embodiment, the black box 100 includes a battery backup system 115. In one embodiment, the battery backup system 115 is charged by the primary power source 105 using techniques necessary to prolong the life of any battery included in the battery backup system 115. In one embodiment, the battery-life-prolonging techniques are practiced by the battery backup system 115 in addition to, or instead of, the primary power source 105. In one embodiment, the battery backup system 115 includes circuitry to recognize a failure in the primary power source 105 and transition the load of the black box 100 to the battery backup system 115.

In one embodiment, the black box 100 includes a processor 120. The processor 120 can be a microprocessor, a microcontroller, a programmable logic array, or any other similar device that is capable of controlling the other components in the black box 100.

In one embodiment, the black box 100 includes a memory 125. In one embodiment, the memory includes random access memory (“RAM”), programmable read only memory (“PROM”), erasable programmable read only memory (“EPROM”), flash memory, volatile memory, nonvolatile memory, or any other type of memory. In one embodiment, the memory includes a digital recorder, a flash memory, a dynamic memory, and/or a mag memory (e.g., magnetic tape).

In one embodiment, the processor 120 communicates with the memory 125 and with other components in the black box 100 through a bus or busses 130 that allows the processor to selectively communicate with components in the black box 100.

In one embodiment, the black box 100 includes a global positioning system antenna, receiver, and decoder (“GPS”) 135 that receives signals from the Global Positioning System satellites and uses those signals to locate the black box on the earth's surface. In one embodiment, the processor 120 receives position reports from the GPS 135 via the bus 130 and records those reports, thereby maintaining a “track” of the location of the black box over a period of time.

In one embodiment, an input device 140 conditions input signals received from the oil field system for presentation to the processor 120. In one embodiment, the input device 140 has a connection to the processor 120 that is separate from the bus 130. In one embodiment (not shown), the input device 140 communicates with the processor 120 through the bus 130.

In one embodiment, the input device 140 accepts signals not limited to the following formats:

• • Wellsite Information Transfer Specification (“WITS”) (levels 0 through 4), including the option to accept encrypted data;
  • Controller-area network (“CAN” or “CAN-bus”);
  • The formats associated with other standard rig busses, such as Profibus, Modbus, and OPC;
  • IEEE 802.11 (wireless);
  • video (digital and/or analog);
  • audio (digital and/or analog);
  • telephone calls, and
  • other similar formats.

In one embodiment, the input device 140 converts the signal or signals, which can be received via a wire, fiber, wirelessly, via radio, via a telephone connection, or via a connection to a cellular network, into data that can be accepted by the processor 120 and provides the results to the processor either directly as shown in FIG. 1, or by way of the bus 130. In one embodiment, the input device 140 transmits all data that it receives from the oil field system 110 to the processor 120. In one embodiment, the input device 140 selects some data for transmission to the processor 120. In one embodiment, the input device 140 summarizes data before transmitting it to the processor 120. In one embodiment, the input device 140 passes raw data to the processor 120 and any summarization is performed by the processor 120.

In one embodiment, the input device 140 samples the signals from the oil field system 110 with the sample rate for each signal being set by the processor 120. In one embodiment, the processor 120 recognizes stages, including “failure stages” of the oil field system 110 based on the data provided by the input device 140. For example, in one embodiment, the processor recognizes four stages of operation, although additional stages of operation are envisioned:

• • “Normal operation”—the sampled data indicates that the systems being monitored are operating within their normal operating parameters;
  • “Non-critical failure”—a failure not critical to the operation of the oil field system 100, such as a failure in a mud analysis system, has occurred;
  • “Critical failure”—a failure critical to the operation of the oil field system 110, such as failure of the mud circulation system, has occurred; and
  • “Total failure”—a failure that threatens the health of the rig, such as an explosion that destroys the control room, has occurred.

In one embodiment, the processor controls the rate the input device 140 samples the signals from the oil field system depending, at least in part, on the stage of operation the oil field system 110 is currently in. For example, in normal operation, in one embodiment the processor 120 only records audio from the control room when a voice or voices can be detected on the audio. In the critical failure mode, in one embodiment the processor records the audio continuously. Similarly, in the normal mode of operation, in one embodiment the processor samples downhole pressure once every 10 seconds. In the critical failure mode of operation, in one embodiment the processor samples downhole pressure once every second.

In one embodiment, the black box 100 includes software that is stored on the memory 125 and executed by the processor 120. In one embodiment, the software includes a process that prevents the original format of the sampled form of one of the inputs that is stored in memory from being modified. In one embodiment, this process operates similarly to a configuration management tool, in that it maintains a record of the format of data as it is received and prevents the modification of the format of that data by anyone other than a person with the proper privileges. This process also maintains a record of the people that have made such modifications or have attempted such modifications.

In one embodiment, the software includes a voice recognition process that accepts an audio signal containing a voice signal and executes an algorithm to identify the speaker from a set of known speakers. In one embodiment, the memory contains a set of speaker voice recognition profiles created as personnel arrive at the oil field system 110. In one embodiment, a newly arriving person is asked to speak into a microphone when he or she first arrives at the oil field system and the voice recognition profile is created based on that interaction.

In one embodiment, one audio input to the input device 140 is from a microphone or microphones through which personnel can comment on the procedures being followed on the oil field system, other personnel, other companies, vendors, or any other topic the speaker feels is worthy of comment. The processor 120 stores a digitized version of these comments along with the identity of the speaker, which in one embodiment is determined by the voice recognition process, in the memory 125.

In one embodiment, an audio input to the input device 140 is from the public address system that personnel use in the oil field system 110 to make announcements regarding the status of operations on the oil field system 110 or to give directions to accomplish oil field system 110 tasks. The processor 120 stores a digitized version of these communications along with the identity of each speaker, which in one embodiment is determined by the voice recognition process, in the memory 125.

In one embodiment, microphones and cameras are distributed around the oil field system 110 work areas. Signals from these microphones and cameras are inputs to the input device 140. The processor 120 stores a digitized version of these signals, along with the identity of speakers where they can be determined by the voice recognition process, in the memory 125.

In one embodiment, the input device receives data from:

• • voice/sound recordings, such as from the public exchange (“PBX”) public address system on a rig or voice memo records from a rig control room or other location on the rig, such as:
    • voice conversations between a company man (i.e., a representative of an operating or exploration company on the rig), one of the rig contractors, and any vendors, regarding a decision concerning the operation of the rig;
    • morning reports or other similar reports;
  • video from feeds on the rig;
  • status checks against a plan (i.e., an indication, such as a check list, of progress against a plan);
  • drilling data from sensors on the rig, such as:
    • drilling parameters;
    • mud systems;
    • mud properties;
    • drilling systems;
    • alarm status on the rig;
    • gas detection devices;
    • Kelly height and depth of drill string;
    • drill string configuration;
    • blow out preventer (“BOP”) status and BOP status in a series;
    • formation properties;
    • riser information;
    • well position information; and
    • information regarding rotating machinery;
  • streaming BOP data (i.e., information gathered directly from the BOP or downhole systems);
  • Sensors mounted on well casing, tubular, drill sting, and any other down hole sensor, connected to the surface through wires, fiber, or through wireless transmissions;
  • riser positioning data;
  • information, for example from a radar system, regarding the positions of boats, ships, or other vessels in the vicinity of the rig and especially in an exclusion zone around the rig; and
  • data regarding mechanical machinery or rotating data from engines, turbines, tensioning leg information, and data and information from a control room.

For example, in one embodiment used on a drilling rig, the processor 120 has access to and can execute the MAXACTIVITY™ rig floor activity monitoring software available from the assignee of this application, or other similar software. The MAXACTIVITY software tracks and times rig floor activities such as trips in and out of the rig's bore hole, circulating, drilling, and connection operations based on rig floor sensor information collected through the input device 140. In one embodiment, the MAXACTIVITY software can be run on real-time or historical data, can export data to a spreadsheet program, allows users to override or edit data, produces reports concerning rig operations, and can export data to, for example, the remote system 155 through the remote system interface 160.

In one embodiment, MAXACTIVITY collects the following sensor data:

• • Drlg Rotary (on bottom drilling and rotating);
  • Drlg Sliding (on bottom drilling with a motor, not rotating drill string);
  • TIH String (tripping in hole);
  • POH String (pulling out of hole);
  • TIH in Casing (tripping in hole with casing);
  • POH in Casing (pulling out of hole with casing);
  • TIH Connection (tripping in hole with connection);
  • POH Connection (pulling out of hole with connection);
  • TIH BHA Conn (tripping in hole with bottom hole assembly);
  • POH BHA Conn (pulling out of hole with bottom hole assembly);
  • TIH in CSG Conn (tripping in hole with casing connection);
  • POH in CSG Conn (pulling out of hole with casing connection);
  • TIH Wash Down (tripping in hole while washing down);
  • POH Ream Up (pulling out of hole with reaming);
  • POH Ream Down Up (pulling out of hole and reaming up and down);
  • TIH Wash Down (tripping in hole while washing down);
  • TIH Ream Up (tripping in hole while reaming up);
  • TIH Ream Down (tripping in hole while reaming down);
  • POH Wash Up (pulling out of hole while washing up);
  • POH (pulling out of hole);
  • TIH BHA (tripping in hole with bottom hole assembly);
  • POH BHA (pulling out of hole with bottom hole assembly);
  • Drlg Ream Up (drilling and reaming up);
  • Drlg Ream Down (drilling and reaming down);
  • Drlg Connection (drilling but stopped to make a connection);
  • Deviation Survey (pulsing data from a survey instrument in the BHA);
  • Drlg Circ Post Conn (drilling with circulation after a connection);
  • TIH Circ (tripping in hole while circulating);
  • POH Circ (pulling out of how while circulating);
  • Drlg Circ (drilling while circulating);
  • Unknown
  • Rig Repair (any condition in which the rig is stopped for repair);
  • Service Rig (rig repair under way);
  • Cut Slip Drill Line (drilling string being lifted and lowered to use new cable on draw works);
  • Cementing (well is being cemented); Nipple up BOP's (connecting blow out preventer at well head);
  • Testing BOP's (testing blow out preventer);
  • Press Integrity TST (casing pressure test);
  • Drill Stem Test (test drill string after penetrating a plug; checking to see if a well zone will produce);
  • Fishing (fishing equipment from the well);
  • Measure After Drilling (running measurement while drilling).

In one embodiment, health monitoring systems of a drilling rig, such as systems monitoring well string vibration, weight on bit (“WOB”), rate of penetration (“ROP”), pressure, and the like, are given priority and are sampled and processed at higher priorities than other inputs to the input device 140.

In one embodiment, the processor 120 selects portions of the data it receives from the input device 140, processes it, and stores it in the memory 125. In one embodiment, the stored data provides a record of the data received. In one embodiment, the stored data is sufficient to reconstruct faults that occur on the oil field system 110.

In one embodiment, the data stored in the memory 125 is periodically overwritten on a first-in-first-out (“FIFO”). In one embodiment, a plan is being monitored as discussed below. In one embodiment, as each planned milestone is accomplished, the data associated with that milestone is decimated, leaving enough data that essential data can be gathered and interrogated to evaluate primary conditions, i.e., conditions that are sufficient to understand the state of the well.

In one embodiment, some or all of the data collected regarding critical operations, such as pressure tests, and the like, are encrypted.

In one embodiment, the processor provides data sufficient to reconstruct faults through an analysis interface 145 to a failure analysis system 150. In one embodiment, the failure analysis system 50 is able to select the data to receive by interacting with the processor 120 through the analysis interface 145. In one embodiment, the failure analysis system 150 is outside the black box 100.

In one embodiment, data collected through the input device 140 is forwarded to a remote system 155 through a remote system interface 160. In one embodiment, data is forwarded to the remote system 155 during normal operations, which allows the remote system to replicate the processing being performed by the processor 120.

In one embodiment, a dashboard interface 165 provides a real-time view of the data being collected to the oil field system 110. In one embodiment, the oil field system 110 includes a screen that illustrates the current status of the oil field system 110 according to the black box 100. In one embodiment, the real-time view of the data that is provided through dashboard interface 165 includes an identification of problems that the black box 100 perceives.

In one embodiment, the black box 100 is mechanically coupled to the oil field system in normal operations. In one embodiment, the black box 100 includes a mechanical release mechanism 170 that releases the black box 100 from the oil field system 110. In one embodiment, the purpose of the release caused by the mechanical release mechanism is to allow the black box 100 to move a distance away from the oil field system 110 in the event that the oil field system 110 is undergoing a catastrophic failure that might destroy the black box 100 if it is left in its attached position.

In one embodiment, the mechanical release mechanism 170 is a simple release that simply drops the black box 100 from the oil field system 110 into, for example, the sea. In one embodiment, the mechanical release mechanism 170 is a launching device that launches the black box 100 away from the oil field system using an explosive device, a rocket, or a large spring.

In one embodiment, the black box 100 continues to record data until the mechanical release mechanism 170 is activated or the black box 100 is otherwise released from the oil field system 110. In one embodiment, even after the black box 100 is released it maintains a connection to the oil field system 110 through a tether, such as a wire, fiber, or wireless connection. In one embodiment, the tether is on a spool that is attached to the black box 100 or to the oil field system 110 and pays out as the black box 100 moves away from the oil field system. In one embodiment, the black box 100 has a way to sever or otherwise release the tether if the black box 100 is no longer receiving data from the oil field system 110, the tether is fully extended, or some other similar event occurs.

In one embodiment, the processor 120 uses the data stored in the memory to detect such catastrophic events and, when they occur, actuates the mechanical release mechanism 170. In one embodiment, the mechanical release mechanism can be activated in one of the following ways:

• • manual activation:
    • a selector, such as a push-button switch, is provided in a control room or in the vicinity of the black box 100, that overrides the processor 120 and causes the black box 100 to be released or jettisoned from the oil field system 110;
    • a mechanical apparatus for overriding the mechanical release mechanism 170 to cause the black box 100 to be released or jettisoned from the oil field system 110;
  • water activation:
    • a detector (not shown) on the black box 100 detects that the detector (and therefore the black box 100) is submerged and activates the mechanical release mechanism;
  • jettison activation:
    • the processor 120 detects problems with water, gas, heat, fire, severe shock or vibration by monitoring signals through the input device 140 and triggers the mechanical release mechanism 170;
  • gas activation:
    • the processor 170 detects a gas event, such as a sudden surge in pressure in the well bore, and triggers the mechanical release on that basis.

In one embodiment, the black box 100 includes a beacon 175, such as a radio transmitter, that transmits a beacon signal that allows the black box 100 to be located by searchers, for example, after the mechanical release mechanism has been activated and it has been released from the oil field system 110. In one embodiment, the beacon signal includes a status message conveying information concerning the event that caused the black box 100 to be released. In one embodiment, the beacon 175 is automatically activated upon the occurrence of one of the activation events described above.

In one embodiment, the beacon 175 and memory 125 are part of a separate module 180 within the black box 100. In one embodiment, the battery backup system 115 is included in the module 180. In one embodiment, the beacon 175 has its own battery. In one embodiment, the beacon's battery is charged by the primary power source 105 or by the battery backup system 115. In one embodiment, module 180 is the only part of the black box 100 that is jettisoned from the oil field system when the mechanical release mechanism 170 is activated.

In one embodiment, upon detecting a condition that either will or might cause the black box to be released from the oil field system, the processor 120 initiates a power decay tree, in which the processor automatically, for example through the dashboard interface 165, turns off successively less important sensors. In one embodiment, for example, a set of high importance sensors (i.e., last to be turned off) includes public address system sensors, microphone sensors, BOP status sensors, riser sensors, and well position sensors. In one embodiment, for example, a set of medium importance sensors (i.e., turned off after the low importance sensors but before the high importance sensors) includes standpipe pressure sensors, sensors monitoring the flow of mud in and out of the well, engine sensors, and temperature sensors. In one embodiment, for example, a set of low importance sensors (i.e., the first set of sensors to be turned off), includes gamma ray resistivity sensors, survey sensors, and drilling parameter sensors. In one embodiment, the battery backup system 115 performs some or all of the power decay tree functionality.

In one embodiment, the location of the black box 100 on the oil field system 110 is chosen to enhance its survivability. For example, in one embodiment, the black box 100 is mounted on the oil field system's life rafts. In one embodiment, the black box 100 is located a sufficient distance away from the oil field system 110 that it is unlikely to be affected by any failures of the oil field system 110 while still being connected to the oil field system 110 either wirelessly or through a tether, as described above.

In one embodiment, illustrated in FIG. 2, the black box 100 maintains a plan for the oil field system 110 to follow, tracks actual progress against the plan, and reports deviations from the plan to the oil field system 110 through the dashboard interface and, in one embodiment, to the remote system 155 through the remote system interface 160. In FIG. 2, the plan is shown on the left side of the page and the actual is shown on the right side of the page.

In one embodiment, the plan includes milestones, labeled Milestone 1 through Milestone M, although only Milestone N−1, Milestone N, and Milestone N+1 are shown. The milestones are represented in FIG. 2 by diamond-shaped symbols. Each milestone is broken down into tasks. For example, in FIG. 2 Milestone N includes 4 tasks: Task N:1, Task N:2, Task N:3, and Task N:4. Milestone N+1 includes 3 tasks: Task N+1:1, Task N+1:2, and Task N+1:3. Milestone N+2 (not shown) includes at least task N+2:1. Other Milestone N+2 tasks are not shown because they are outside the timeframe shown in FIG. 2. Similarly, the task or tasks included in Milestone N−1 are outside the timeframe shown in FIG. 2.

In one embodiment, milestones that have not yet been completed are represented on the “plan” side of FIG. 2 by black diamond-shaped symbols. Completed milestones are indicated on the “actual” side of FIG. 2 by circles around the black diamond-shaped symbols. In the example shown in FIG. 2, Milestones N−1 and Milestone N have been completed.

In one embodiment, uncompleted tasks are represented on both sides of FIG. 2 by dashed boxes and completed tasks are shown on the “actual” side of FIG. 2 by solid-lined boxes. Thus, in the example shown in FIG. 2, Task N:1, Task N:2, Task N:3, and Task N:4 are completed and Task N+1:1 is incomplete and presumably underway.

In one embodiment, data collected during each task is associated with each task. This is represented in FIG. 2 by solid-lined boxes to the left of each task. For example, Data N:1 is associated with Task N:1, Data N:2 is associated with Task N:2, Data N:3 is associated with Task N:3, and Data N+1:1 is associated with Task N+1:1, etc. Similarly, each task has associated with it “expected data” represented on the “plan” by a solid box to the left of the task box. Thus, Task N:1 has an associated Expected Data N:1, etc. In one embodiment, not all tasks have expected data and not all tasks have collected data.

It will be understood that tasks can be divided into sub-tasks, for example, and into even finer levels of detail. It will also be understood that milestones can be grouped into super-milestones, for example and even greater levels of summary.

Further, in the example shown in FIG. 2, the tasks and milestones are all shown occurring serially for simplicity. It will be understood that some tasks and milestones can run in parallel.

In the example shown in FIG. 2, it can be seen that Task N+1:1 has not completed in the planned time. That is, the dashed box for Task N+1:1 on the “actual” side of FIG. 2 extends beyond the end of the dashed box for Task N+1:1 on the “plan” side of FIG. 2. In one embodiment, the processor 120 detects this deviation and reports it to the oil field system 110 through the dashboard interface 165. In one embodiment, the processor 120 reports the deviation to the remote system 165 through the remote system interface 160.

Further, in one embodiment, the processor 120 compares some or all of the data collected during each task to data that was expected during that task. In one embodiment, the processor 120 compares the data collected during a task (e.g., Data N:1) to the data that was expected to be collected when the plan was created (e.g., Expected Data N:1). In one embodiment, the processor reports significant deviations of the collected data from the expected data to the oil field system 110 through the dashboard interface 165. In one embodiment, the processor reports such data deviations to the remote system 165 through the remote system interface 160. In one embodiment, the significance of the deviation necessary to report the deviation to the oil field system 110 and/or to the remote system 165 is included in the definition of the expected data. For example, the plan may specify that the rate of penetration (“ROP”) during Task N:3 should be 1 meter per minute and that deviations away from this number by more than one half meter per minute should be reported.

In one embodiment, the information shown in FIG. 2 is, in whole or in part, shown in the dashboard view provided through the dashboard interface 165 (FIG. 1). In one embodiment, the dashboard view is color coordinated. In one embodiment, for example, parts of the plan that are on schedule or that are being performed according to plan are shown in green. In one embodiment, for example, parts of the plan that are not on schedule or that are not being performed according to plan but that are still within threshold limits of deviation from the plan are shown in yellow. In one embodiment, for example, parts of the plan that are not on schedule or that are not being performed according to plan and that are outside threshold limits of deviation from the plan are shown in red.

In one embodiment of use, illustrated in FIG. 3, the black box (or “releasable apparatus”) 100, which is attached to the oil field system, receives an oil field system signal (block 305). In one embodiment, the black box 100 digitizes the oil field system signal to produce a digitized signal (block 310). In one embodiment, the black box 100 stores the digitized signal in a memory (e.g., memory 125) in the black box 100 (block 315). In one embodiment, the black box 100 forwards the digitized signal to a location remote (e.g., remote system 155) from the oil field system 110 (block 320). In one embodiment, the black box 100 determines from the digitized signal that a failure in the oil field system 110 has occurred and, in response, is released (or releases itself) from the oil field system 110 (block 325). In one embodiment, the black box 100 is retrieved (block 330). In one embodiment, the digitized signal is extracted from the memory in the black box 100 (block 335). In one embodiment, the digitized signal is used to analyze the failure in the oil field system (block 340).

The text above describes one or more specific embodiments of a broader invention. The invention also is carried out in a variety of alternate embodiments and thus is not limited to those described here. The foregoing description of the preferred embodiment of the invention has been presented for the purposes of illustration and description. It is not intended to be exhaustive or to limit the invention to the precise form disclosed. Many modifications and variations are possible in light of the above teaching. It is intended that the scope of the invention be limited not by this detailed description, but rather by the claims appended hereto.

Claims

1. An apparatus comprising: a plurality of inputs to receive signals from an oil field system that the apparatus is monitoring;a processor to: monitor the inputs;determine that a failure in the oil field system has occurred and, in response,trigger a mechanical release mechanism to release the apparatus;a remote signal output to report a subset of the inputs to a remote location as the processor is monitoring the signal inputs;a memory to store the inputs; andan output through which the stored inputs can be extracted to analyze the failure in the oil field system.

2. The apparatus of claim 1 further comprising: a primary power source; anda battery backup system which is charged by the primary power source.

3. The apparatus of claim 1 wherein: the processor to sample the inputs;the processor to recognize a plurality of stages of failure of the oil field system based on the inputs; andthe processor to sample the signal inputs at rates associated with each of the plurality of stages of failure.

4. The apparatus of claim 1 further comprising: a data protection system to prevent an original format of the one of the inputs stored in the memory from being modified.

5. The apparatus of claim 1 further comprising: the memory to store a plan that is to be followed with respect to the oil field system;the plan comprising a milestone, the accomplishment of which can be identified by the processor using a milestone subset of the stored inputs;the processor, upon determining that the milestone has been met, to decimate a subset of the stored inputs, to leave enough data in the decimated data from which a primary set of conditions of the oil field system can be evaluated.

6. The apparatus of claim 1 further comprising: the memory to store a plan that is to be followed by the oil field system;the plan comprising a milestone, the accomplishment of which can be identified by the processor using a milestone subset of the stored inputs;the milestone subset of the stored inputs comprising: a voice input through which a speaker's comment regarding progress toward completion of the milestone can be: accepted;digitized;stored in the memory; andvoice recognized to identify the speaker.

7. The apparatus of claim 1 further comprising: the memory to store a plan that is to be followed by the oil field system;the plan comprising a milestone, the accomplishment of which can be identified by the processor using a milestone subset of the stored inputs;the milestone subset of the stored inputs comprising: a voice input through which a public address system can be accepted, digitized, and stored in the memory.

8. The apparatus of claim 1 further comprising: the memory to store a plan that is to be followed by the oil field system;the plan comprising: a milestone;a task, the accomplishment of which can be identified using a milestone subset of the stored inputs, to be accomplished to achieve the milestone;a deadline by which the task is to be accomplished;the processor to monitor the milestone subset of stored inputs to determine that the task has not been accomplished by the deadline and, in response, to provide an alert through an alert output of the apparatus.

9. The apparatus of claim 1 wherein: one of the plurality of inputs to receive real-time voice signals from a person entering a work area in the oil field system;the processor to voice recognize the voice signal to identify the person; andthe processor to log the person's entry into the work area and a current date and time in a log in the memory.

10. The apparatus of claim 1 further comprising: an extendable tether to maintain a signal connection between the apparatus and the oil field system after the mechanical release mechanism has been triggered.

11. A method comprising: receiving an oil field system signal by a releasable apparatus attached to an oil field system;digitizing the oil field system signal by the releasable apparatus to produce a digitized signal;storing the digitized signal in a memory in the releasable apparatus;forwarding the digitized signal to a location remote from the oil field system by the releasable apparatus;determining from the digitized signal that a failure in the oil field system has occurred and, in response: releasing the releasable apparatus from the oil field system;retrieving the releasable apparatus;extracting the digitized signal from the memory in the releasable apparatus;using the digitized signal to analyze the failure in the oil field system.

12. The method of claim 11 further comprising: determining based on the digitized signal that a milestone in a plan stored in the memory has been met and, in response: decimating data regarding the oil field system stored in the memory but leaving enough data in the decimated data from which a primary set of conditions of the oil field system can be evaluated.

13. The method of claim 11 further comprising: storing a plan to be followed by the oil field system in the memory, the plan comprising a milestone, the accomplishment of which can be identified using a milestone set of digitized signals;the milestone set of digitized signals comprising a voice input through which a public address system can be accepted, digitized, and stored in the memory.

14. The method of claim 11 further comprising: storing a plan to be followed by the oil field system in the memory, the plan comprising: a milestone;a task, the accomplishment of which can be identified using a milestone subset of the stored inputs, to be accomplished to achieve the milestone;a deadline by which the task is to be accomplished;monitoring the milestone subset of stored inputs to determine that the task has not been accomplished by the deadline and, in response, to provide an alert through an alert output of the apparatus.

15. The method of claim 11 further comprising: receiving by the releasable apparatus real-time voice signals from a person entering a work area in the oil field system;voice recognizing the voice signal to identify the person; andlogging the person's entry into the work area and a current date and time in a log in the memory.

16. A computer program, stored in a computer-readable tangible medium, the program comprising executable instructions that cause a computer to: receive an oil field system signal by a releasable apparatus attached to the oil field system;digitize the oil field system signal by the releasable apparatus to produce a digitized signal;store the digitized signal in a memory in the releasable apparatus;forward the digitized signal to a location remote from the oil field system by the releasable apparatus;determine from the digitized signal that a failure in the oil field system has occurred and, in response: release the releasable apparatus from the oil field system;retrieve the releasable apparatus;extract the digitized signal from the memory in the releasable apparatus;use the digitized signal to analyze the failure in the oil field system.

17. The computer program of claim 16 further comprising executable instructions that cause the computer to: determine based on the digitized signal that a milestone in a plan stored in the memory has been met and, in response: decimate data regarding the oil field system stored in the memory but leaving enough data in the decimated data from which a primary set of conditions of the oil field system can be evaluated.

18. The computer program of claim 16 further comprising executable instructions that cause the computer to: store a plan to be followed by the oil field system in the memory, the plan comprising a milestone, the accomplishment of which can be identified using a milestone set of digitized signals;the milestone set of digitized signals comprising a voice input through which a public address system can be accepted, digitized, and stored in the memory.

19. The computer program of claim 16 further comprising executable instructions that cause the computer to: store a plan to be followed by the oil field system in the memory, the plan comprising: a milestone;a task, the accomplishment of which can be identified using a milestone subset of the stored inputs, to be accomplished to achieve the milestone;a deadline by which the task is to be accomplished;monitor the milestone subset of stored inputs to determine that the task has not been accomplished by the deadline and, in response, to provide an alert through an alert output of the apparatus.

20. The computer program of claim 16 further comprising executable instructions that cause the computer to: receive by the releasable apparatus real-time voice signals from a person entering a work area in the oil field system;voice recognize the voice signal to identify the person; andlog the person's entry into the work area and a current date and time in a log in the memory.