Operator Assessment Exam

The wellhead is rated for 5,000#, but the well is flowing at 2,500# FTP. The wellhead panel should not be holding more pressure than the wellhead is rated for. Therefore, it is not okay to keep the pressure of 6,000# on the safety valve.

It is not okay to put a lower rated needle valve on a vessel, even if the pressure coming in won't exceed the needle valve's rating. This is because the needle valve may not be able to handle sudden pressure surges or fluctuations, which can lead to failure and potential safety hazards. It is important to always use a needle valve that is rated equal to or higher than the maximum pressure expected in the system.

All wells capable of natural flow need to have a SCSSV (Surface Controlled Subsurface Safety Valve) or SSCSSV (Surface Controlled Subsurface Safety Valve) installed in the tubing at least 100 feet below the mud line. These safety valves are crucial in preventing uncontrolled flow of fluids from the well, ensuring the safety and integrity of the wellbore.

According to 14-C regulations, all separators are required to have a certain number of TSE on them for fire detection.

False. This statement is incorrect because while some positive displacement pipeline pumps may be lubricated by the process fluid, not all of them are. Some positive displacement pumps do require external oiling devices for lubrication.

All Pressure Safety Valves (PSV) are to be properly sized to allow the maximum inlet flow anticipated which will protect the vessel from overpressure.

Based on the given information, the well has a history of making CO2 and now has holes in the tubing. The holes have been sealed with pack-offs, but the gas lift pressure is unable to maintain, causing gases to leak. Therefore, it is possible that the pack-offs are leaking, more holes have developed in the tubing above the liquid level, and there is a problem with one of the gas lift valves. Hence, the most likely scenario is that all of the above issues are occurring in this well.

The correct answer is "PSH can not be SAC'ed out". This means that the PSH (Pressure Safety High) on the discharge of a pump cannot be safely relieved if the MAWP (Maximum Allowable Working Pressure) of the pump does not exceed 100% of the discharge piping. In other words, the pump must have a MAWP that is equal to or higher than the pressure in the discharge piping in order to safely relieve the PSH. If the MAWP is lower than the pressure in the discharge piping, the PSH cannot be safely relieved and therefore cannot be SAC'ed (safely relieved by a safety relief device) out.

The correct answer is SDV. SDV stands for Shutdown Valve. It is required on all KAQ or incoming pipelines and must complete its task in 45 seconds or less after an upset or the Emergency Shutdown (ESD) is activated. The SDV is responsible for shutting off the flow of fluid in the pipeline in case of an emergency or abnormal condition. It plays a crucial role in preventing accidents and protecting the equipment and personnel.

Sometimes separators can have the LSL device SAC’ed out with a reference number A4e3, as long as the downstream components can safely handle the maximum gas rates. This statement is true because separators are used to separate different components in a system, and sometimes it may be necessary to bypass or isolate certain devices, such as the LSL device, for maintenance or other purposes. As long as the downstream components can handle the gas rates without any safety concerns, it is acceptable to SAC out the LSL device.

The correct answer is "Line must be purged, pickled and isolated from service before one year of the date it was OOS." This means that when a pipeline segment is out of service and approaching one year, it is necessary to remove any remaining product from the line (purging), treat the line with chemicals to prevent corrosion (pickling), and isolate it from the rest of the system. This is important to ensure the integrity and safety of the pipeline.

The correct answer is "Both 2 & 3". Both spill over plates and weirs as well as float assemblies are used to control fluid levels in vessels. Spill over plates and weirs are designed to allow excess fluid to spill over and maintain a constant level, while float assemblies use a float that rises or falls with the fluid level to control the flow of fluid in and out of the vessel.

The increased choke size caused an increase in pressure in the flowline, which exceeded the set point of the pilot. This caused the pilot to shut in the well. Additionally, the methanol injection rate was not increased, allowing hydrates to form in the line. Both factors, the increased pressure and the formation of hydrates, contributed to the shut-in of the well.

The maximum allowable BS&W (Basic Sediment and Water) entering an oil sales pipeline is 1%. This means that the oil being transported through the pipeline can contain up to 1% of sediment and water. Any percentage higher than this would not be acceptable as it could lead to issues such as increased corrosion, reduced flow efficiency, and potential damage to equipment and infrastructure. Therefore, it is crucial to ensure that the BS&W content is kept below 1% to maintain the integrity and efficiency of the oil sales pipeline.

Bubble caps are devices that are designed to keep a level of glycol above their rim slots so that gas has to travel through the glycol. This allows for efficient contact between the gas and the glycol, facilitating the absorption of contaminants by the glycol. The other options mentioned, such as retaining oil in the bottom of the contact tower or providing a bubble-tight connection on an external pump, are not accurate descriptions of bubble caps.

The MMS district supervisor may grant permission to lock out a SCSSV and install a SSCSV when the SCSSV is leaking and is a tubing retrievable safety valve. This indicates that there is a safety concern with the SCSSV, and replacing it with a SSCSV would ensure the safety and integrity of the well. The other two options, the well being depleted and hurricane season, do not directly relate to the need for replacing the SCSSV.

API 14-C, which is a standard for gas compressors, requires all gas compressor discharge stage cylinders to have a TSH (Temperature Safety High) to protect from high temperature. This safety measure is necessary to prevent overheating and potential damage to the compressor. The TSH acts as a safeguard by monitoring and controlling the temperature, ensuring that it does not exceed safe limits.

The optimum temperature of the final stage discharge of a reciprocating gas compressor is 250. This temperature is considered optimal because it strikes a balance between efficient compression and preventing overheating of the compressor. Higher temperatures can lead to increased wear and tear on the compressor components, while lower temperatures may result in less efficient compression. Therefore, 250 is the ideal temperature for the final stage discharge.

LACT units or Allocation Liquid Meters that measure 50 barrels or more of oil daily need to be proved on a monthly basis. This means that these units must undergo a verification process every month to ensure their accuracy in measuring the amount of oil being transported through the pipeline. This regular verification helps to maintain the integrity of the measurement system and ensures that accurate data is being collected for allocation purposes.

A TSE (Temporary Safety Eye) is required over each wellhead.

Choke nipples are installed in vessel liquid dump lines to protect downstream equipment in case of dump valve failure. This is because choke nipples help regulate the flow of liquid, allowing for a controlled release of pressure. By installing choke nipples, any potential sudden surge of liquid due to dump valve failure can be prevented, thus safeguarding the downstream equipment from damage.

An indication that the recycle valve trim may be over sized is when the valve opens and closes constantly and is unable to effectively control the suction pressure. This suggests that the valve is not properly sized to handle the flow and pressure requirements, leading to instability in the system.

The correct answer is 5 to 7 pounds of water per million standard cubic feet of gas. This means that under a dry gas contract, the maximum allowable amount of water that can enter a pipeline is between 5 and 7 pounds for every million standard cubic feet of gas.

If you have a separator that requires 2 PSV's, you cannot temporarily remove one and send it in for repair while still being in compliance with the other one. This means that the statement is false.

The purpose of Glycol systems is to remove water from the natural gas.

It is legal to take two water overboard samples and analyze one before you send the other to the lab for analysis. This allows for verification of the results and ensures accuracy in the analysis process. By comparing the results of both samples, any discrepancies or errors can be identified and addressed. This practice helps to maintain the integrity of the analysis and ensures that the water quality is accurately assessed.

The most probable cause of a well having abnormally low tubing pressure is the down hole valve being shut in. This means that the valve located down the wellbore, which controls the flow of fluids from the reservoir, is closed. As a result, the pressure in the tubing is reduced because the flow of fluids from the reservoir to the surface is restricted. This can happen due to various reasons such as equipment malfunction, maintenance work, or safety concerns.

Triethylene glycol is a chemical compound commonly used as a solvent and a dehydrating agent. The preferred pH level of triethylene glycol is 7, which is considered neutral. This means that it is neither acidic nor alkaline. Maintaining a neutral pH level is important for the stability and effectiveness of triethylene glycol in various applications.

Unmanned platforms with production equipment that have an approved waiver from MMS (Minerals Management Service) are not required to undergo a daily pollution check. This suggests that these platforms have met certain criteria or regulations set by MMS, which exempts them from the daily pollution check requirement. Therefore, the statement "True" indicates that these unmanned platforms with production equipment and an approved waiver do not need to perform a daily pollution check.

The correct answer is 3,600 MSCFPD. MSCFPD stands for thousand standard cubic feet per day, which is a unit used to measure the flow rate of gas. In this question, the total gas produced was given as 600 mmscf (million standard cubic feet), and the well was in test for 4 hours. To calculate the gas production rate in MSCFPD, we divide the total gas produced by the test duration in hours: 600 mmscf / 4 hours = 150 MSCFPD. However, none of the given options match this calculation. Therefore, it is likely that the correct answer is missing from the options provided.

When the pressure drop in the suction piping is greater than the liquid pressure head, a pump will vapor lock. This means that the pressure in the suction piping drops to a level where the liquid starts to boil and form vapor bubbles. These vapor bubbles can disrupt the flow of liquid and cause the pump to lose its ability to pump effectively.

The TSH-Exline temperature elements on gas compressor bottles need to be inspected every six months. This regular inspection ensures that the temperature elements are functioning properly and accurately measuring the temperature of the gas compressor bottles. By inspecting them every six months, any potential issues or malfunctions can be identified and addressed in a timely manner, helping to maintain the efficiency and performance of the compressors.

The correct answer is that the differential pen indicates flow rate and the static pen indicates valve operation. This means that the chart recorder measures the difference in pressure between the gas lift gas and the wellbore pressure, which is represented by the differential pen. This differential pressure is directly related to the flow rate of the gas. On the other hand, the static pen indicates the opening and closing of the gas lift valves, which affects the performance of the gas lift system. Therefore, by analyzing the chart, one can determine both the flow rate and the performance of the gas lift valves.

TSH's on compressor installations need to be inspected every 6 months if they are of the nondestructive type. This regular inspection ensures that the TSH's are functioning properly and any potential issues can be identified and addressed in a timely manner. Regular inspections help to maintain the efficiency and reliability of the compressor installation.

A well may be flowed with the SCSSV locked out or the SSCSV removed under both conditions 1 and 2. This means that during routine wireline operations or in the case of no flow wells, the well can still be flowed even if the SCSSV is locked out or the SSCSV is removed.

If a well flows into a down rated pipeline and there is no PSV (Pressure Safety Valve) on the header or flow line, a secondary PSH (Pressure Safety Head) is required on the flowing well. The PSH acts as a backup safety measure to prevent overpressure in the well and ensure the safe operation of the system. Without a PSV on the pipeline, the PSH becomes necessary to protect the well from potential damage or failure due to excessive pressure.

The most reasonable answer is that too much gas entering the contact tower is causing the glycol to be swept out of the vessel. This is because if there is an excessive amount of gas entering the tower, it can create turbulence and strong flow rates, which can result in the glycol being carried out of the vessel along with the gas.

The most probable cause of a well having abnormally high tubing pressure is when the valve downstream of the well has shut in. This means that the flow of fluid from the well is being blocked by the closed valve, causing pressure to build up in the tubing. The other options, such as a down hole valve shut in or a cut out choke body, may also cause high tubing pressure, but the most likely cause in this scenario is the shut-in valve downstream of the well.

The question states that the cylinder temperatures are running high and recycling does not help, indicating that there is an issue with the compressor. Since the compressor is not operating at its rated capacity and the suggested solution of adjusting the pockets of the compressor ends is not mentioned, it is advisable to call a mechanic for making the necessary modifications to correctly load the compressor.

Stripping or contact towers are used in glycol handling to allow gas to come into contact with glycol for the purpose of dehydrating. This process helps to separate the water in the gas from the oil. The stripping or contact towers also help in heating the gas before it is sent to sales. Therefore, the correct answer is "So Gas makes contact with Glycol for dehydrating."

The correct answer is 42 daily and 29 monthly. This means that in federal waters, the daily limit for oil and grease in produced water that can be disposed of overboard is 42 units, and the monthly limit is 29 units. It is important to adhere to these limits to ensure the proper handling and disposal of produced water to prevent environmental contamination.

The correct answer is the designed working pressure of the vessel. The PSV (Pressure Safety Valve) on a vessel should be set at the same pressure as the designed working pressure of the vessel. This ensures that the PSV will activate and release excess pressure when the vessel reaches its maximum safe operating pressure. Setting the PSV at a lower pressure could result in the valve not opening when needed, potentially leading to a dangerous overpressure situation.

The given answer indicates that the Maximum Allowable Working Pressure (MAWP) is 610 psi. The question states that the high pressure separator is going down on the pressure safety high pilot, suggesting that the pressure in the system is exceeding its safe limit. By running a new range chart, the operator can determine the maximum pressure that the equipment can safely handle, which in this case is determined to be 610 psi. The answer repeats this value in different formats for clarity.

The total water produced can be calculated by subtracting the total liquids produced from the total volume produced. In this case, the total liquids produced is given as 50 bbls. Therefore, the total water produced would be 600 mmscf - 50 bbls = 550 bbls. Since the question asks for the value in bbls per day, it can be assumed that the well was in test for 4 hours. Therefore, the total water produced per day would be 550 bbls / 4 hours * 24 hours = 90 bbls per day.

It is not okay to remove the wellhead after closing the SCSSV (Surface Controlled Subsurface Safety Valve) and bleeding the tubing to zero for a rig job. The wellhead is an important component that provides a secure connection between the surface equipment and the wellbore. Removing the wellhead without proper procedures and precautions can lead to safety hazards and potential damage to the well. Therefore, it is not recommended to remove the wellhead in this scenario.

A long radius elbow would be recommended to the client in order to reduce restrictions to the flow in a gas lifted well. This type of elbow has a larger radius, which allows for a smoother flow of gas and reduces the chances of turbulence or pressure drop. This helps to minimize any restrictions or blockages in the flow, resulting in improved efficiency and performance of the well.

When a positive displacement pump is shut down, it is not possible for the pump media to flow through the pump body and valves. This is because positive displacement pumps work by trapping and moving a fixed amount of fluid with each stroke or rotation, and when the pump is shut down, there is no movement or flow happening. Therefore, the statement that the pump media can flow through the pump body and valves when a positive displacement pump is shut down is false.

The maximum time allowed for the Subsurface Controlled Safety Valve (SCSSV) to close after the Emergency Shutdown (ESD) has been activated is 2 minutes and 45 seconds. This indicates that the SCSSV is designed to respond quickly in emergency situations to prevent any potential hazards or damage.

The correct answer suggests that the next step to troubleshoot the failure is to pull the discharge valves on the 1st stage compressor and check for damages. This is because the gas compressor has shut down on the 1st stage discharge and the Ex-Line has melted. By checking the discharge valves on the 1st stage compressor, one can determine if there are any damages that may have caused the failure. This step is important in identifying the cause of the shutdown and taking appropriate actions for troubleshooting.

The correct answer is "Decrease flowing tubing psi, increase water production, increase gas production." These three noticeable changes can indicate a potential issue with the positive choke that may require checking or replacement. A decrease in flowing tubing psi suggests a decrease in pressure, which could be caused by a problem with the choke. An increase in water production and gas production may also indicate a problem with the choke, as it may not be effectively controlling the flow of fluids and gases. Therefore, these changes serve as indicators for the operator to inspect the positive choke.

Foaming in the glycol system is most likely caused by too much contamination in the glycol. Contaminants such as oil, dirt, or other substances can lead to the formation of foam, which can disrupt the proper functioning of the system. This can result in reduced efficiency and potentially damage the equipment. Too much water in the gas, not enough heat on the system, or gas blowby may have other negative effects on the glycol system, but they are not specifically related to foaming.

To bring down the high pH level of the glycol, alkaline should be added to the system. Alkaline substances have a higher pH level and can neutralize the acidity of the glycol, thereby lowering its pH level. Adding glycol or finding acid would not be effective in reducing the pH level, as they would not counteract the high pH. Therefore, the correct solution is to add alkaline to the system.

The correct answer is "Atmospheric and pressure." This answer is correct because the question is asking about the types of production vessels referenced in API RP-14C. According to the information provided, there are two types of production vessels: atmospheric and pressure vessels.

The correct answer is "The quantity of water in the gas." Dew point refers to the temperature at which water vapor in a gas condenses into liquid water. It is a measure of the amount of water present in the gas.

When pressure is first observed on any of the casing strings, it is important to notify MMS. This is because pressure could indicate a potential issue or problem with the casing strings, and MMS needs to be informed so that appropriate actions can be taken to address the situation. Performing a diagnostic test and monitoring monthly may also be necessary, but the immediate action should be to notify MMS.

The given correct answer is 1440, 1,440, 1440 psi, 1,440 psi. This answer indicates that the Maximum Allowable Working Pressure (MAWP) is 1440 psi. The multiple variations of the answer provide different ways of expressing the same value, using both numerical and textual formats.

Tri-ethylene glycol should be subjected to a maximum temperature of 404 degrees.

SAC stands for "Supervisory Alarm Control". By "SAC out the PSL", it means to bypass or disable the PSL (Pump Start Logic) system. This would prevent the nuisance alarms and allow the pump to restart without the discharge bleeding down to zero pressure.

The total oil produced can be calculated by subtracting the total liquids produced (50 bbls) from the total volume produced (600 mmscf). However, since the question asks for the answer in barrels per day, we need to convert the gas volume to barrels. Without any conversion factor provided, it is not possible to accurately calculate the total oil production in barrels per day. Therefore, the correct answer cannot be determined based on the given information.

The statement is false because the water being discharged from a sump tank does not need to be tested monthly for oil and grease content. The testing requirements may vary depending on regulations and industry standards, but it is not a general requirement to test for oil and grease content along with the produced water.

The correct answer is 1368 psi, 1,368 psi. The range chart provided in the question is used to determine the maximum allowable working pressure (MAWP) of the high pressure separator. The chart shows that the MAWP is 1368 psi, which can be written as 1,368 psi.

The given range chart provides the information needed to determine the maximum allowable working pressure (MAWP) which is 1440. The numbers provided in the chart are 519, 519 psi, and 519 PSI. These numbers do not match the MAWP value, so they cannot be the correct answer. Therefore, the correct answer is 1440.