Diagnosis Of Street Sweeper : Failure Of Motor Shaft Seals

In this report, I will be explaining all the details regarding my equipment which is street sweeper. The main focus of my report is that I will be explaining about diagnosis and troubleshooting of street sweeper. With the help of my report, students will get a lot of knowledge about street sweeper problems and it’s solutions.

Included premium quality piston seals plus an internal magnetic filtration system working together to extend pump life. Both jacks featured the Rapid Pump dual parallel pump technology for lifting in far fewer strokes. The universal joint release providing a precise load control for smooth descent is a standard feature in both jacks. The heavy duty 3-ton and the super duty 3-ton jack were both precision welded constructed. eventually cost was and features was in which I based my purchased on. With both jacks being so similar in standard features. I couldn’t justify spending $199 on a jack when I could purchase a the $89 3-ton jack that was low enough to fit under my vehicles, which will get the job done just as well. I ended up buying the 3-ton heavy duty jack over the 3-ton Daytona super duty jack, mainly because of two reasons. One was the cost and having such similar features. Second was the capability to fit the heavy-duty jack under vehicles that are 2” of the ground. The Daytona wasn’t not low enough to allow me to fit it under a lowered vehicle lower than

The idea is to try a poor boy gas lift before installing a plunger lift. This may be a case where a plunger lift is not needed in conjunction with a poor boy gas lift.

"With continued treatment, including flushing the system with chlorine and rinsing it, as well as injecting sodium hydrochloride for safety, three of the four wells should be able to come back online

The crew then tried to manually start the pumps to fix the rig, but this made things worse. There were no manuals on board explaining the ballast control system so they did what they felt was right. Instead of emptying the ballast tank on the side where the rig was listing, they pumped in more water, to try and start the pumps working but, this just increased the list to about 15 degrees. If the crew had used the knowledge of hydraulics pumps they would have realized that it would not be possible to to get rid of a leak by pumping in more liguid. Doing so would cause a large overflow destroying the pump.

36). Halliburton also presented to BP that seven centralizer is very likely to create “severe gas flow problem” (p. 36). Subsequent days there was a pressure test conducted by oil rig owners and tool pusher Wyman Wheeler, who did not believe explanations received. Another negative test performed and during the new negative test, the pressure came down on a different pipe and not for the drill pipe and the crew moved on with the rest of the process. According to BP, tool pusher Jason Anderson justifies the anomalous reading as the “bladder effect and had been seen this before” (p.6). The negative test expectation is not necessarily the same since there is no pressure from the drill pipe. The drilling crew prepared for the cement plug top of the oil well by reopening the blowout preventer and “pumping seawater down the drill pipe to displace the mud and spacer from the riser” according to the United States (2011), Deep water, (p.7) and the crew began discharging the spacer. At 9.20 pm on the fatal day before the explosion, Anderson responded to another colleague, the negative test “went well”. Just after Anderson is discussing with BP representatives who praised the job, the explosion started with throwing mud. There will be check and balances on all levels for any well-designed process, but it is clear the communication did not happen at all levels. At the initial explosion, there was chaos, and no one knows the accurate count and evaluates

An unplanned flow of well fluids into the wellbore can be dangerous as it could cause a blowout which would then cause a fire. In order to prevent this, driller’s pump a drilling mud into the well, creating a barrier between the undersea oil and gas and the rig. The safety of the drilling crew relies on a piece of equipment placed on the top of the sea floor called the blowout preventer. This is essential for controlling the well and in an emergency situation preventing a disaster on the platform high above on the sea surface. The blowout preventer is connected to the rig by a large diameter pipe called a riser. If a blowout occurs the blowout preventer is designed to prevent flammable oil and gas travelling up the drilling rig.

April 17, 2010 – Deepwater Horizon completes its drilling and the well is being prepared to be cemented so that another rig will retrieve the oil. The blowout preventer is tested and found to be "functional."[8] Gagliano now reports that using only 6 centralizers "would likely produce channeling and a failure of the cement job.

The technology of Pneumatics deals with the application and uses of a compressible gas such as air or a suitable pure gas but hydraulics uses an incompressible liquid such as oil. The application started to grow due to a gradual shift towards automated machines and equipment. The introduction of pneumatics in manufacturing has introduced the cheaper mode of production in wide areas of application such as Packaging machinery, Bottle filling Industry, artificial heart, logic control systems and robotic materials handling devices etc. Due to several advantages, pneumatics is preferred over hydraulics. The coming future technology in this field is further improving the hydraulics in terms of cost and energy efficiency.

Annular pressure build up (APB) is an important problem in the areas of well design. Although different suggestions have been proposed to mitigate APB, including vacuum insulated tubing, silicate foam wellbore insulation techniques, and insulating completion (packer) fluids, consistent, robust APB mitigation solutions that include the optimized annular fluid rheology of the trapped drilling fluids in the outer annuli are needed to better handle this problem.

The lifetime of a nuclear power plant is planned to be 40 years. Recently there are trails to raise this life in new constructions as well as the old ones to 60 years (1-4). During this prolonged lifetime components are exposed to degradation that may affect safe operation of the plant. Such influences affect pressure retaining items of the plant including reactor pressure vessel, reactor piping, bolting and threaded fasteners, steam generator materials and several other items (5).

To achieving outstanding fuel economy, high torque output and to reduce the emission produced from the relatively small engine displacement an innovative injection technology has came in the early 1990’s. The use of hydraulic force to pressurize fuel for injection was innovative technology to advance the use of powerful, cleaner and

Once a gas kick enters the well, the conventional procedures to remove this hazard from the wellbore would be to shut-in the well and to use an adjustable choke at the surface, maintaining constant bottom hole pressure while remaining above or exceeding the formation pressures. Furthermore, if gas has entered into the marine risers offshore, the flow of gas through the slender choke lines could rapidly increase the migration of the gas to the rig and endanger personnel & equipment. Conventionally, the mud & gas solution has been diverted away from the rig in past scenarios in which potential blowouts could occur. In the past, operators have considered increasing the density of the mud to kill weight mud (KWM) and minimizing the shut-in time to be detrimental to the well due to increasing the chances of underground blowout. As will be seen, this is certainly not the case and the major point of focus, as will be focused on throughout this paper, should alternatively be to develop a proactive approach to mitigate gas kicks. Analyzing the bubble-rise velocity of the gas kick in the annulus, and the multiple parameters that affect it, could potentially result in successfully mitigating problems due to kicks in the annulus.

Size can also be a restriction. Typically, floor-mounted, this device sometimes stood 3-5 feet tall for general applications. Size and weight could prohibit the use of this device in areas that would be required for mounting a drive. HYDRAULIC MOTOR DRIVES SYSTEM: Hydraulic drives have been, and continue to be, the rock of many metals processing and manufacturing functions. The hydraulic motor’s small size makes it ideal for situations where high power is needed in very tight locations.

Here the value of force required to pull the lining is depend on the dimensions, diameter, properties, size and tool geometry. After some analysis, result shows that during leaving from the dying zone it tends to gain its original shape. As a result pipe is still under the pressure and that means lining is in partially plasticized in the die zone. Stresses and forces are shown in the figure 4. According to analysis, after the complete release of lining, there is lack of tension or condition in which