Office Action 1: Non-Final Rejection (2025-01-29)
Rejection types: 102 - Lack of Novelty

CLAIMS:
WHAT IS CLAIMED IS:
1\. A method comprising: receiving time series data acquired during equipment operations at a plurality of natural resource sites; detecting operational events using the time series data based on comparing the time series data to a corresponding threshold, wherein at least one operational event of the operational events is a low frequency event corresponding to a pump; ranking the operational events based on an operational event score for each of the operational events, wherein the operational event score is increased for an increase in an amount of energy dissipated by the pump; associating each of the operational events with a corresponding operational action; and outputting at least a portion of the ranked operational events, each with its corresponding operational action.
2\. The method of claim 1 wherein the outputting comprises rendering graphics for the at least a portion of the ranked events to a graphical user interface, wherein the graphical user interface comprises graphical controls linked to the graphics that associate each of the at least a portion of the ranked events with its corresponding operational action.
3\. The method of claim 1 wherein the time series data comprise one or more of temperature time series data, pressure time series data, fluid flow time series data and electrical time series data.
4\. The method of claim 1 wherein the ranking of the operational events comprises computing the operational event score for each of the operational events.
5\. The method of claim 4 wherein the time series data comprise time series natural resource production data and wherein the computing the operational event score comprises utilizing at least a portion of the time series natural resource production data.
6\. The method of claim 5 wherein the equipment operations comprise pumping operations performed by pumps and wherein the time series natural resource production data comprise fluid flow time series data for a natural resource pumped from a reservoir by the pumps.
7\. The method of claim 4 wherein the equipment operations comprise pumping operations performed by pumps and wherein the time series natural resource production data comprise pressure time series data for a natural resource pumped from a reservoir by the pumps.
8\. The method of claim 1 comprising classifying each of the operational events as active or completed.
9\. The method of claim 1 comprising, for each of the operational events, determining one or more of a severity, a duration and a type.
10\. The method of claim 1 comprising, responsive to receipt of a mode indicator, organizing the at least a portion of the ranked operational events according to the mode indicator.
11\. The method of claim 10, wherein the mode indicator comprises a natural resource site mode or an equipment mode.
12\. The method of claim 10, wherein the mode indicator comprises a natural resource site mode wherein the natural resource sites comprise wells in fluid communication with a common reservoir and wherein the outputting the at least a portion of the ranked operational events comprises outputting a ranked list of at least a portion of the wells that correspond to the at least a portion of the ranked operational events.
13\. The method of claim 10, wherein the mode indicator comprises an equipment mode wherein the equipment operations are performed by pumps and wherein the outputting the at least a portion of the ranked operational events comprises outputting a ranked list of at least a portion of the pumps that correspond to the at least a portion of the ranked operational events.
14\. The method of claim 1 wherein the plurality of natural resource sites comprise wells in fluid communication with a common reservoir and wherein detecting operational events using the time series data comprises detecting an operational event that decreases sandface pressure in a wellbore of one of the wells in relationship to reservoir pressure of the common reservoir.
15\. The method of claim 1 wherein the time series data comprise natural resource site identifiers, channel identifiers, timestamps and values.
16\. The method of claim 1 comprising, responsive to receipt of a selection of one of the output ranked operational events, issuing a control instruction that instructs equipment to perform its corresponding operational action.
17\. The method of claim 16 comprising rendering a graphic to a graphical user interface for the selected one of the output ranked operational events, determining a control status of the selected one of the output ranked operational events, and dynamically updating the graphic responsive to the determined control status.
18\. A method comprising: receiving time series data acquired during equipment operations at a plurality of natural resource sites; detecting operational events using the time series data based on comparing the time series data to a corresponding threshold, wherein at least one operational event of the operational events is a low frequency event corresponding to a pump; comparing at least a portion of the time series natural resource production data to model data; ranking the operational events comprising computing an operational event score for each of the operational events, wherein the computing increases the operational event score for a decrease in natural resource production at one of the natural resource sites.
19\. A system comprising: a processor; memory accessible to the processor; processor-executable instructions stored in the memory and executable by the process to instruct the system to: receive time series data acquired during equipment operations at a plurality of natural resource sites; detect operational events using the time series data based on comparing the time series data to a corresponding threshold, wherein at least one operational event of the operational events is a low frequency event corresponding to a pump; rank the operational events based on an operational event score for each of the operational events, wherein the operational event score is increased for an increase amount of energy dissipated by the pump; associate each of the operational events with a corresponding operational action; and output at least a portion of the ranked operational events, each with its corresponding operational action.
20\. One or more computer-readable storage media comprising computer-executable instructions executable to instruct a computing system to: receive time series data acquired during equipment operations at a plurality of natural resource sites; detect operational events using the time series data based on comparing the time series data to a corresponding threshold, wherein at least one operational event of the operational events is a low frequency event corresponding to a pump; rank the operational events based on an operational event score for each of the operational events, wherein the operational event score is increased for an increase amount of energy dissipated by the pump; associate each of the operational events with a corresponding operational action; and output at least a portion of the ranked operational events, each with its corresponding operational action.

OFFICE ACTION:
DETAILED ACTION
Notice of Pre-AIA  or AIA  Status
The present application, filed on or after March 16, 2013, is being examined under the first inventor to file provisions of the AIA .
Claim Rejections - 35 USC § 102
In the event the determination of the status of the application as subject to AIA  35 U.S.C. 102 and 103 (or as subject to pre-AIA  35 U.S.C. 102 and 103) is incorrect, any correction of the statutory basis (i.e., changing from AIA  to pre-AIA ) for the rejection will not be considered a new ground of rejection if the prior art relied upon, and the rationale supporting the rejection, would be the same under either status.
The following is a quotation of the appropriate paragraphs of 35 U.S.C. 102 that form the basis for the rejections under this section made in this Office action:
A person shall be entitled to a patent unless –
(a)(1) the claimed invention was patented, described in a printed publication, or in public use, on sale, or otherwise available to the public before the effective filing date of the claimed invention.
Claims 1-11 and 18-20 are rejected under 35 U.S.C. 102(a)(1) as being anticipated by Vittal et al., U.S. 2015/0095100.
Regarding claim 1, Vittal et al. discloses receiving time series data ([0005]) acquired during equipment operations (fig 6; [0042]) at a plurality of natural resource sites (fig 3, pumping systems 100; [0024]); detecting operational events using the time series data (fig 4, 202; [0026]) )based on comparing the time series data to a corresponding threshold ([0003]), wherein at least one operational event of the operational events is a low frequency event ([0003]; any of the events related to failure) corresponding to a pump (100); ranking the operational events based on an operational event score (fig 4, 206; [0027]) for each of the operational events, wherein the operational event score is increased for an increase in an amount of energy dissipated by the pump ([0032]; analysis on well depth, gas-oil-ratio, water-oil-ratio, pump-intake-pressure, suction temperature, solid abrasives, corrosive elements, flowing bottom hole pressure, static bottom hole pressure, well productivity index and inlet performance relationship are related to energy allocation in the disclosed performance factors) associating each of the operational events with a corresponding operational action (fig 4, 212, 214; [0030]); and outputting at least a portion of the ranked operational events (206), each with its corresponding operational action (214).
As to claim 2, Vittal et al., discloses the outputting comprises rendering graphics (fig 2, interface 124; [0021], [0022]) for the at least a portion of the ranked events (206) to a graphical user interface (124), wherein the graphical user interface comprises graphical controls linked to the graphics that associate each of the at least a portion of the ranked events with its corresponding operational action (fig 4, 214).
As to claim 3, Vittal et al. discloses the time series data comprise one or more of temperature time series data, pressure time series data, fluid flow time series data and electrical time series data ([0026], claim 2).
As to claim 4, Vittal et al. disclose the ranking of the operational events (206) comprises computing the operational event score (H1 , H2  …..) for each of the operational events.
As to claim 5, Vittal et al. the time series data ([0005]) comprise time series natural resource production data ([0048]; last sentence) and wherein the computing the operational event score (206) comprises utilizing at least a portion of the time series natural resource production data ([0049]; data is used to optimize pump performance).
As to claim 6, Vittal et al. discloses the equipment operations comprise pumping operations performed by pumps (pumping system 100) and wherein the time series natural resource production data ([048]) comprise fluid flow time series data ([0049]) for a natural resource pumped from a reservoir by the pumps.
As to claim 7, Vittal et al. discloses pumping operations (100) performed by pumps and wherein the time series natural resource production data [(0049, 0048)} comprise pressure time series data for a natural resource pumped ([0026]) from a reservoir by the pumps.
As to claim 8, Vittal et al. discloses classifying each of the operational events as active ([0051]).
As to claim 9, Vittal et al. discloses for each of the operational events ([0003]; events related to failure), determining one or more of a severity and a type.
As to claim 10, Vittal et al. discloses responsive to receipt of a mode indicator ([0008]; operational characteristics indicate a mode), organizing the at least a portion of the ranked operational events (206) according to the mode indicator.
As to claim 11, Vittal et al. disclose the mode indicator (operational characteristics) comprises a natural resource site mode or an equipment mode (characteristics of the pumping system 100).
Regarding claim 18, Vittal et al. discloses detecting operational events (206) using the time series data based on comparing the time series data to a corresponding threshold ([0004]; out- of -range incidents), wherein at least one operational event of the operational events is a low frequency event ([0003]; any events leading to failure) corresponding to a pump (100); comparing at least a portion of the time series natural resource production data to model ([0032]; lines 1-6) data; ranking the operational events (206) comprising computing an operational event score (H1 , H2  …..) for each of the operational events, wherein the computing increases the operational event score for a decrease in natural resource production ([0049]) at one of the natural resource sites.
Regarding claim 19, Vittal et al. discloses  a processor; memory accessible to the processor; processor-executable instructions stored in the memory and executable by the process ([0023]) to instruct the system to: receive time series data (fig 4, 202) acquired during equipment operations at a plurality of natural resource sites (fig 3, pumping systems 100; [0024]); detect operational events using the time series data based on comparing the time series data to a corresponding threshold ([0004]; out- of -range incidents), wherein at least one operational event of the operational events is a low frequency event corresponding to a pump; rank the operational events based on an operational event score for each of the operational events, wherein the operational event score is increased for an increase amount of energy dissipated by the pump; associate each of the operational events with a corresponding operational action; and output at least a portion of the ranked operational events, each with its corresponding operational action (as noted above in the rejection to claim 1).
Regarding claim 20; Vittal discloses a computer-readable storage media comprising computer-executable instructions executable to instruct a computing system ([0023]) to: receive time series data acquired during equipment operations at a plurality of natural resource sites (fig 3, pumping systems 100; [0024]); detect operational events using the time series data based on comparing the time series data to a corresponding threshold ([0004]; out- of -range incidents), wherein at least one operational event of the operational events is a low frequency event corresponding to a pump; rank the operational events based on an operational event score for each of the operational events, wherein the operational event score is increased for an increase amount of energy dissipated by the pump; associate each of the operational events with a corresponding operational action; and output at least a portion of the ranked operational events, each with its corresponding operational action (as noted above in the rejection to claim 1).
Allowable Subject Matter
Claims 12-17 are objected to as being dependent upon a rejected base claim, but would be allowable if rewritten in independent form including all of the limitations of the base claim and any intervening claims.
Conclusion


NEXT OFFICE ACTION: DETAILED ACTION
Notice of Pre-AIA  or AIA  Status
The present application, filed on or after March 16, 2013, is being examined under the first inventor to file provisions of the AIA .
Allowable Subject Matter
Claims 1-9, 11 and 16-20 are allowed.
The following is an examiner’s statement of reasons for allowance:
The prior art of record having a filing date before the effective filing date of this application does not disclose nor suggest all the claimed subject matter including detecting operational events using the time series data based on comparing the time series data to a corresponding threshold, wherein at least one operational event of the operational events is a low frequency event corresponding to a pump; ranking the operational events with a corresponding operational action or decrease in sand face pressure according to a natural resource site mode, energy dissipated by the pump nor decrease in natural resource production.
Conclusion
Any comments considered necessary by applicant must be submitted no later than the payment of the issue fee and, to avoid processing delays, should preferably accompany the issue fee.  Such submissions should be clearly labeled “Comments on Statement of Reasons for Allowance.”

CITED REFERENCE SUMMARIES: Ref US10227859B2: Claims:
A method, comprising: receiving video of an effect of an event on well site equipment, the received video comprising one of a surface marker on a surface of the equipment or an upstanding marker supported to move with the equipment; and identifying the event using Eulerian video magnification of the received video.
receiving video of an effect of an event on well site equipment, the received video comprising one of a surface marker on a surface of the equipment or an upstanding marker supported to move with the equipment; and
identifying the event using Eulerian video magnification of the received video.
The method of claim 1 , where the event is obscured from view of the video.
The method of claim 1 , where the equipment is subterranean.
The method of claim 1 , where identifying the event comprises identifying and decoding communications.
The method of claim 4 , where the communications comprise fluid pulse telemetry signals from fluid from a well or acoustic telemetry signals carried as vibrations of the well site equipment.
The method of claim 1 , where identifying the event comprises identifying a fluid property of a fluid in surface equipment, the fluid obscured from view of the video.
The method of claim 6 , where the fluid property comprises flow rate.
The method of claim 1 , where identifying the event comprises identifying damage obscured from view of the video or wear obscured from view of the video.
The method of claim 1 , where identifying the event comprises identifying a blockage in a flow passage of the equipment, the blockage obscured from view of the video.
The method of claim 8 , where the equipment comprises a subterranean well screen.
The method of claim 1 , where identifying the event comprises identifying operation of a subterranean well tool.
The method of claim 1 , where receiving video comprises receiving video of an effect of an event on a surface pump at the well site; and where identifying the event comprises identifying operating speed, cavitation, vapor lock, wear or damage.
where identifying the event comprises identifying operating speed, cavitation, vapor lock, wear or damage.
The method of claim 12 , where the pump is a frac pump or a gas injection pump.
A system, comprising: a camera aimed to take video of an event on equipment at a well site; and a computing device in communication with the camera to receive the video and apply Eulerian video magnification to the received video to produce enhanced video, the received video comprising one of a surface marker on a surface of the equipment or an upstanding marker supported to move with the equipment; and a display to output the enhanced video.
a camera aimed to take video of an event on equipment at a well site; and
a computing device in communication with the camera to receive the video and apply Eulerian video magnification to the received video to produce enhanced video, the received video comprising one of a surface marker on a surface of the equipment or an upstanding marker supported to move with the equipment; and
a display to output the enhanced video.
The system of claim 14 , where the equipment comprises, in view of the camera, one or more of a flag, the marker or a color change coating that changes color in response to strain or temperature.
The system of claim 14 , where the camera is aimed to take video of drilling equipment or pumps at the well site.
The system of claim 14 , where the equipment comprises a housing at least partially underground and containing the camera and a target supported on a movement sensitive base, the target being in the view of the camera.
The system of claim 14 , where the camera comprises a thermal camera.
A method, comprising: receiving video of equipment at a well site, the received video comprising one of a surface marker on a surface of the equipment or an upstanding marker supported to move with the equipment; applying Eulerian video magnification to the received video to produce an enhanced video; and identifying an event that is obscured from view of the video using the enhanced video.
receiving video of equipment at a well site, the received video comprising one of a surface marker on a surface of the equipment or an upstanding marker supported to move with the equipment;
applying Eulerian video magnification to the received video to produce an enhanced video; and
identifying an event that is obscured from view of the video using the enhanced video.
The method of claim 19 , where applying Eulerian video magnification comprises applying Eulerian video magnification to magnify movement or color of a terranean surface or equipment associated with a well.
The method of claim 19 , where receiving video of equipment at a well site comprises receiving video of an effect produced by the event.
Ref US20170130712A1: Claims:
A system for managing a pump arrangement, comprising: at least one pressure sensor configured to generate a pressure signal indicative of a pump pressure of a targeted pump within the pump arrangement; and at least one controller in electrical communication with the pressure sensor, the controller being configured to receive the pressure signal from the pressure sensor, apply a band pass filter on the pressure signal to filter frequencies associated with untargeted pumps, isolate at least a base frequency of the filtered pressure signal, and detect at least the pump pressure of the targeted pump based on the base frequency.
at least one pressure sensor configured to generate a pressure signal indicative of a pump pressure of a targeted pump within the pump arrangement; and
at least one controller in electrical communication with the pressure sensor, the controller being configured to receive the pressure signal from the pressure sensor, apply a band pass filter on the pressure signal to filter frequencies associated with untargeted pumps, isolate at least a base frequency of the filtered pressure signal, and detect at least the pump pressure of the targeted pump based on the base frequency.
The system of claim 1 , wherein the pressure sensor is configured to generate pressure signals including pump pressure information measured in terms of pump speed.
The system of claim 1 , wherein the pressure sensor is configured to generate pressure signals including pump failure information measured in terms of vibrations in the pump.
The system of claim 1 , wherein the controller is configured to apply the band pass filter to isolate at least the base frequency of the targeted pump.
The system of claim 1 , wherein the controller is configured to apply the band pass filter to isolate a failure frequency of the targeted pump, and detect a pump failure of the targeted pump based on the failure frequency.
The system of claim 1 , wherein the controller is configured to detect when pump speeds of the targeted pump and one or more untargeted pumps are substantially the same, compare amplitudes of the detected base frequencies to a theoretical amplitude of the base frequency of the targeted pump at the given pump speed, and apply an adjustment factor to the pressure signal based on the amplitude comparison to exclude base frequencies of untargeted pumps.
A controller for managing a targeted pump in a pump arrangement, comprising: a receiver module configured to receive a pressure signal from a pressure sensor associated with the targeted pump; a filter module configured to apply a band pass filter on the pressure signal to filter frequencies associated with untargeted pumps and isolate at least a base frequency of the targeted pump; and a detection module configured to detect at least a pump pressure of the targeted pump based on the base frequency.
a receiver module configured to receive a pressure signal from a pressure sensor associated with the targeted pump;
a filter module configured to apply a band pass filter on the pressure signal to filter frequencies associated with untargeted pumps and isolate at least a base frequency of the targeted pump; and
a detection module configured to detect at least a pump pressure of the targeted pump based on the base frequency.
The controller of claim 7 , wherein the receiver module is configured to receive pressure signals including pump pressure information measured in terms of pump speed.
The controller of claim 7 , wherein the receiver module is configured to receive pressure signals including pump failure information measured in terms of vibrations in the pump.
The controller of claim 7 , wherein the filter module is configured to center the band pass filter on at least the base frequency of the targeted pump.
The controller of claim 7 , wherein the filter module is configured to apply the band pass filter to isolate a failure frequency of the targeted pump, and the detection module is configured to detect a pump failure of the targeted pump based on the failure frequency.
The controller of claim 7 , wherein the detection module is configured to detect when pump speeds of the targeted pump and one or more untargeted pumps are substantially the same.
The controller of claim 12 , further comprising: a comparison module configured to compare amplitudes of the detected base frequencies to a theoretical amplitude of the base frequency of the targeted pump at the given pump speed; and an adjustment module configured to apply an adjustment factor to the pressure signal based on the amplitude comparison to exclude base frequencies of untargeted pumps.
a comparison module configured to compare amplitudes of the detected base frequencies to a theoretical amplitude of the base frequency of the targeted pump at the given pump speed; and
an adjustment module configured to apply an adjustment factor to the pressure signal based on the amplitude comparison to exclude base frequencies of untargeted pumps.
A controller-implemented method for managing a pump arrangement having a targeted pump and one or more untargeted pumps, comprising: receiving a pressure signal from a pressure sensor associated with the targeted pump; applying a band pass filter on the pressure signal configured to filter frequencies associated with the untargeted pumps; isolating at least a base frequency of the targeted pump based on the filtered pressure signal; and detecting at least a pump pressure of the targeted pump based on the base frequency.
receiving a pressure signal from a pressure sensor associated with the targeted pump;
applying a band pass filter on the pressure signal configured to filter frequencies associated with the untargeted pumps;
isolating at least a base frequency of the targeted pump based on the filtered pressure signal; and
detecting at least a pump pressure of the targeted pump based on the base frequency.
The controller-implemented method of claim 14 , wherein the pressure signal includes at least pump pressure information measured in terms of pump speed.
The controller-implemented method of claim 14 , wherein the pressure signal includes pump failure information measured in terms of vibrations in the pump.
The controller-implemented method of claim 14 , wherein the band pass filter is centered on the base frequency and a failure frequency of the targeted pump.
The controller-implemented method of claim 17 , further comprising: isolating at least the failure frequency of the targeted pump based on the filtered pressure signal; and detecting at least a pump failure of the targeted pump based on the failure frequency.
isolating at least the failure frequency of the targeted pump based on the filtered pressure signal; and
detecting at least a pump failure of the targeted pump based on the failure frequency.
The controller-implemented method of claim 14 , further comprising: detecting when pump speeds of the targeted pump and one or more untargeted pumps are substantially the same; comparing amplitudes of the detected base frequencies to a theoretical amplitude of the base frequency of the targeted pump at a given pump speed; and applying an adjustment factor to the pressure signal based on the amplitude comparison to exclude base frequencies of untargeted pumps.
detecting when pump speeds of the targeted pump and one or more untargeted pumps are substantially the same;
comparing amplitudes of the detected base frequencies to a theoretical amplitude of the base frequency of the targeted pump at a given pump speed; and
applying an adjustment factor to the pressure signal based on the amplitude comparison to exclude base frequencies of untargeted pumps.
The controller-implemented method of claim 19 , wherein detected failure frequencies caused by interactions with pressure sensors associated with one or more untargeted pumps are also excluded based on amplitude comparisons and adjustment factors.
Ref US9534473B2: Claims:
A method for providing mobile electric power, the method comprising: converting a mobile source of electricity that comprises a power generation trailer and an inlet and exhaust trailer from a transportation mode to an operational mode, wherein the power generation trailer and the inlet and exhaust trailer are separate trailers that travel independently in the transportation mode, wherein an air inlet filter housing and an exhaust stack are both mounted to a single trailer frame of the inlet and exhaust trailer, wherein the exhaust stack is rotated from a horizontal position in the transportation mode to a vertical position in the operational mode, wherein an inlet plenum and an exhaust collector are mounted to a single trailer frame of the power generation trailer and the inlet plenum and exhaust collector are each aligned along a length of the power generation trailer; coupling at least one vertical side of the power generation trailer with a corresponding vertical side of the inlet and exhaust trailer using one or more expansion connections, wherein the at least one vertical side of the power generation trailer is parallel to the length of the power generation trailer; providing combustion air from the air inlet filter housing of the inlet and exhaust trailer to the inlet plenum of the power generation trailer at the at least one vertical side of the power generation trailer; and directing exhaust air out of the exhaust collector of the power generation trailer with the exhaust stack of the inlet and exhaust trailer at the at least one vertical side of the power generation trailer.
converting a mobile source of electricity that comprises a power generation trailer and an inlet and exhaust trailer from a transportation mode to an operational mode,
wherein the power generation trailer and the inlet and exhaust trailer are separate trailers that travel independently in the transportation mode,
wherein an air inlet filter housing and an exhaust stack are both mounted to a single trailer frame of the inlet and exhaust trailer,
wherein the exhaust stack is rotated from a horizontal position in the transportation mode to a vertical position in the operational mode,
wherein an inlet plenum and an exhaust collector are mounted to a single trailer frame of the power generation trailer and the inlet plenum and exhaust collector are each aligned along a length of the power generation trailer;
coupling at least one vertical side of the power generation trailer with a corresponding vertical side of the inlet and exhaust trailer using one or more expansion connections, wherein the at least one vertical side of the power generation trailer is parallel to the length of the power generation trailer;
providing combustion air from the air inlet filter housing of the inlet and exhaust trailer to the inlet plenum of the power generation trailer at the at least one vertical side of the power generation trailer; and
directing exhaust air out of the exhaust collector of the power generation trailer with the exhaust stack of the inlet and exhaust trailer at the at least one vertical side of the power generation trailer.
The method of claim 1 , wherein coupling the at least one vertical side of the power generation trailer with the corresponding vertical side of the inlet and exhaust trailer comprises: coupling the air inlet filter housing to the at least one vertical side of the power generation trailer using a first expansion connection of the one or more expansion connections, wherein the first expansion connection provides combustion air flow to a gas turbine of the power generation transport trailer; and coupling the exhaust stack to the at least one vertical side of the power generation trailer using a second expansion connection of the one or more expansion connections, wherein the second expansion connection collects the exhaust air directed out of the exhaust collector of the power generation trailer, and wherein the at least one vertical side of the power generation trailer transport faces the corresponding vertical side of the inlet and exhaust trailer when the power generation trailer and the inlet and exhaust trailer are positioned side-by-side.
coupling the air inlet filter housing to the at least one vertical side of the power generation trailer using a first expansion connection of the one or more expansion connections, wherein the first expansion connection provides combustion air flow to a gas turbine of the power generation transport trailer; and
coupling the exhaust stack to the at least one vertical side of the power generation trailer using a second expansion connection of the one or more expansion connections,
wherein the second expansion connection collects the exhaust air directed out of the exhaust collector of the power generation trailer, and
wherein the at least one vertical side of the power generation trailer transport faces the corresponding vertical side of the inlet and exhaust trailer when the power generation trailer and the inlet and exhaust trailer are positioned side-by-side.
The method of claim 1 , wherein coupling the at least one vertical side of the power generation trailer with the corresponding vertical side of the inlet and exhaust trailer further comprises: coupling the air inlet filter housing to the at least one vertical side of the power generation trailer using a respective expansion connection of the one or more expansion connections, and wherein the respective expansion connection supplies ventilation air flow to the inlet plenum of the power generation trailer.
coupling the air inlet filter housing to the at least one vertical side of the power generation trailer using a respective expansion connection of the one or more expansion connections, and
wherein the respective expansion connection supplies ventilation air flow to the inlet plenum of the power generation trailer.
A system for providing mobile electric power, the system comprising: a gas turbine generator trailer comprising: an inlet plenum for collecting air flow directed into the gas turbine generator trailer; an exhaust collector for moving exhaust air out of the gas turbine generator trailer; and a single gas turbine generator trailer frame mounting both the inlet plenum and the exhaust collector in alignment with a length of the gas turbine generator trailer; an inlet and exhaust trailer comprising: an air inlet filter housing for supplying the air flow to the gas turbine generator trailer; an exhaust stack for collecting the exhaust air discharged from the gas turbine generator trailer, wherein the exhaust stack is configured to be rotated between a horizontal position and a vertical position; and a single inlet and exhaust trailer frame mounting both the air inlet filter housing and the exhaust stack, wherein the gas turbine generator trailer and the inlet and exhaust trailer are separate and independently movable, wherein the gas turbine generator trailer and the inlet and exhaust trailer are both configured to be positioned parallel to each other along the length of the gas turbine generator trailer in an operational mode, and
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