Operator Assessment Exam

1. Compressors

3. All hot surfaces in excess of 160 degrees F, are required to be insulated, have barriers around them, or marked as a hot surface to protect personnel.

True

False

All hot surfaces in excess of 160 degrees F need to be protected in order to ensure the safety of personnel. This can be done by insulating the surfaces, installing barriers around them, or clearly marking them as hot surfaces. By taking these precautions, the risk of burns or other injuries caused by contact with the hot surfaces can be minimized. Therefore, the statement that all hot surfaces in excess of 160 degrees F are required to be insulated, have barriers around them, or marked as a hot surface to protect personnel is true.

Explanation

All hot surfaces in excess of 160 degrees F need to be protected in order to ensure the safety of personnel. This can be done by insulating the surfaces, installing barriers around them, or clearly marking them as hot surfaces. By taking these precautions, the risk of burns or other injuries caused by contact with the hot surfaces can be minimized. Therefore, the statement that all hot surfaces in excess of 160 degrees F are required to be insulated, have barriers around them, or marked as a hot surface to protect personnel is true.

2. Pipeline

7. Before pipelines can be abandoned, a pigging, purge and abandonment procedure must by submitted and approved by the MMS.

True

False

Before pipelines can be abandoned, a pigging, purge, and abandonment procedure must be submitted and approved by the MMS. This means that there is a requirement for a specific procedure to be followed before pipelines can be abandoned. The procedure involves pigging, which is the process of using a device called a pig to clean the pipeline, purging, which is the removal of any remaining substances from the pipeline, and finally, the abandonment process itself. This procedure must be submitted to and approved by the MMS, indicating that there is a regulatory oversight in place for the abandonment of pipelines. Therefore, the correct answer is true.

Explanation

Before pipelines can be abandoned, a pigging, purge, and abandonment procedure must be submitted and approved by the MMS. This means that there is a requirement for a specific procedure to be followed before pipelines can be abandoned. The procedure involves pigging, which is the process of using a device called a pig to clean the pipeline, purging, which is the removal of any remaining substances from the pipeline, and finally, the abandonment process itself. This procedure must be submitted to and approved by the MMS, indicating that there is a regulatory oversight in place for the abandonment of pipelines. Therefore, the correct answer is true.

3. Glycol Handling

2. Glycol systems use Triethylene glycol as a medium for dehydrating gas.

True

False

Glycol systems use Triethylene glycol as a medium for dehydrating gas. This means that in glycol systems, Triethylene glycol is used to remove moisture from gas, making it a true statement.

Explanation

Glycol systems use Triethylene glycol as a medium for dehydrating gas. This means that in glycol systems, Triethylene glycol is used to remove moisture from gas, making it a true statement.

4. Pipeline

9. Before pipelines are brought back in service after they have developed a leak, they must pass a pressure test and a chart cut indicating the pipeline now hold pressure without bleeding off.

True

False

Before pipelines are brought back in service after they have developed a leak, they must pass a pressure test and a chart cut indicating the pipeline now holds pressure without bleeding off. This means that the statement is true. The pressure test ensures that the pipeline can withstand the required pressure without any leaks, while the chart cut confirms that the pressure is maintained over a specific period without any loss. Both these tests are necessary to ensure the pipeline's integrity and safety before it can be put back into operation.

Explanation

Before pipelines are brought back in service after they have developed a leak, they must pass a pressure test and a chart cut indicating the pipeline now holds pressure without bleeding off. This means that the statement is true. The pressure test ensures that the pipeline can withstand the required pressure without any leaks, while the chart cut confirms that the pressure is maintained over a specific period without any loss. Both these tests are necessary to ensure the pipeline's integrity and safety before it can be put back into operation.

5. Glycol Handling

9. Heat exchangers are used on glycol systems as a way to transfer heat.

True

False

Heat exchangers are commonly used in glycol systems to transfer heat. Glycol systems are often used in industrial processes to regulate temperature and prevent freezing. Heat exchangers facilitate the transfer of heat between the glycol and the fluid or gas being cooled or heated. This helps to maintain the desired temperature and improve energy efficiency. Therefore, it is true that heat exchangers are used on glycol systems as a way to transfer heat.

Explanation

Heat exchangers are commonly used in glycol systems to transfer heat. Glycol systems are often used in industrial processes to regulate temperature and prevent freezing. Heat exchangers facilitate the transfer of heat between the glycol and the fluid or gas being cooled or heated. This helps to maintain the desired temperature and improve energy efficiency. Therefore, it is true that heat exchangers are used on glycol systems as a way to transfer heat.

6. Glycol Handling

12. Wet gas refers to gas that has not had the water removed from it.

True

False

Wet gas refers to gas that has not had the water removed from it. This means that the gas still contains water vapor or liquid water. Therefore, the statement "Wet gas refers to gas that has not had the water removed from it" is true.

Explanation

Wet gas refers to gas that has not had the water removed from it. This means that the gas still contains water vapor or liquid water. Therefore, the statement "Wet gas refers to gas that has not had the water removed from it" is true.

7. Downhole Equipment

5. When a well will no longer flow on it’s own, gas lift gas is the most common source of lift available to continue production offshore.

True

False

Gas lift is a common method used to continue production offshore when a well can no longer flow on its own. It involves injecting gas into the wellbore to reduce the density of the fluid column and lift the reservoir fluids to the surface. This helps to maintain production and ensure the flow of hydrocarbons from the well. Therefore, the statement "True" is the correct answer.

Explanation

Gas lift is a common method used to continue production offshore when a well can no longer flow on its own. It involves injecting gas into the wellbore to reduce the density of the fluid column and lift the reservoir fluids to the surface. This helps to maintain production and ensure the flow of hydrocarbons from the well. Therefore, the statement "True" is the correct answer.

8. Separators

1. MMS sometimes check to see if the pressure vessels in use in federal waters are certified and are A.S.M.E. coded.

True

False

The explanation for the given correct answer is that MMS (Minerals Management Service) occasionally checks if the pressure vessels being used in federal waters are certified and coded according to the standards set by the American Society of Mechanical Engineers (A.S.M.E.). This suggests that there is a requirement for certification and coding for pressure vessels used in federal waters, and MMS is responsible for ensuring compliance with these standards. Therefore, the statement "True" indicates that MMS does check for certification and A.S.M.E. coding of pressure vessels in federal waters.

Explanation

The explanation for the given correct answer is that MMS (Minerals Management Service) occasionally checks if the pressure vessels being used in federal waters are certified and coded according to the standards set by the American Society of Mechanical Engineers (A.S.M.E.). This suggests that there is a requirement for certification and coding for pressure vessels used in federal waters, and MMS is responsible for ensuring compliance with these standards. Therefore, the statement "True" indicates that MMS does check for certification and A.S.M.E. coding of pressure vessels in federal waters.

9. Pumps

8. The component modifier for a pipeline pump as per API 14 C is PAX.

True

False

According to API 14 C, the component modifier for a pipeline pump is PAX. Therefore, the correct answer is True.

Explanation

According to API 14 C, the component modifier for a pipeline pump is PAX. Therefore, the correct answer is True.

10. Compressors

1. All natural gas compressors that have 1,000 horse power or greater are required to have a automatic BDV on the final stage to vent the pressure when the driver shuts down.

True

False

All natural gas compressors with a horsepower of 1,000 or more are mandated to have an automatic Blowdown Valve (BDV) on the final stage. This valve is essential as it releases the pressure when the compressor's driver shuts down. Therefore, the statement is true.

Explanation

All natural gas compressors with a horsepower of 1,000 or more are mandated to have an automatic Blowdown Valve (BDV) on the final stage. This valve is essential as it releases the pressure when the compressor's driver shuts down. Therefore, the statement is true.

11. Water Handling

3. Produced water overboard samples are to be collected monthly and sent to a lab for analysis.

True

False

The statement is true because it states that produced water overboard samples need to be collected monthly and sent to a lab for analysis. This indicates that there is a requirement for regular monitoring of the quality of produced water being discharged into the environment. By sending the samples to a lab for analysis, any potential contaminants or pollutants can be identified, allowing for appropriate measures to be taken to ensure compliance with environmental regulations and standards.

Explanation

The statement is true because it states that produced water overboard samples need to be collected monthly and sent to a lab for analysis. This indicates that there is a requirement for regular monitoring of the quality of produced water being discharged into the environment. By sending the samples to a lab for analysis, any potential contaminants or pollutants can be identified, allowing for appropriate measures to be taken to ensure compliance with environmental regulations and standards.

12. Water Handling

9. Can you face criminal charges for polishing a water sample prior to sending the sample in for testing on your monthly checks?

True

False

Polishing a water sample prior to sending it for testing on monthly checks can be considered as tampering with evidence. This act can be seen as an attempt to alter the results and hide any potential contamination or issues with the water. Tampering with evidence is a criminal offense and can result in criminal charges. Therefore, it is true that one can face criminal charges for polishing a water sample before sending it for testing.

Explanation

Polishing a water sample prior to sending it for testing on monthly checks can be considered as tampering with evidence. This act can be seen as an attempt to alter the results and hide any potential contamination or issues with the water. Tampering with evidence is a criminal offense and can result in criminal charges. Therefore, it is true that one can face criminal charges for polishing a water sample before sending it for testing.

13. Separators

5. Name the three types of gauges, which are commonly used on separators to monitor operations.

Level, pressure, temperature.

Voltage, amperage, frequency.

Oil filled, air filled, electronic.

Timing, strapping, heat.

The question asks for the three types of gauges commonly used on separators to monitor operations. The correct answer is "Level, pressure, temperature." These three types of gauges are essential for monitoring the operations of separators as they provide information about the level of liquid or gas inside the separator, the pressure exerted on the separator, and the temperature of the contents. By monitoring these parameters, operators can ensure that the separator is functioning properly and make any necessary adjustments or interventions if needed.

Explanation

The question asks for the three types of gauges commonly used on separators to monitor operations. The correct answer is "Level, pressure, temperature." These three types of gauges are essential for monitoring the operations of separators as they provide information about the level of liquid or gas inside the separator, the pressure exerted on the separator, and the temperature of the contents. By monitoring these parameters, operators can ensure that the separator is functioning properly and make any necessary adjustments or interventions if needed.

14. Water Handling

2. A permit is required from the EPA to dispose of produced water in federal waters.

True

False

The EPA (Environmental Protection Agency) is responsible for regulating the disposal of produced water, which is a byproduct of oil and gas extraction. Since federal waters fall under the jurisdiction of the EPA, a permit is required to dispose of produced water in these waters. Therefore, the statement that a permit is required from the EPA to dispose of produced water in federal waters is true.

Explanation

The EPA (Environmental Protection Agency) is responsible for regulating the disposal of produced water, which is a byproduct of oil and gas extraction. Since federal waters fall under the jurisdiction of the EPA, a permit is required to dispose of produced water in these waters. Therefore, the statement that a permit is required from the EPA to dispose of produced water in federal waters is true.

15. Pumps

3. All centrifugal pumps moving hydrocarbons are required to have a SDV on the suction side.

True

False

All centrifugal pumps moving hydrocarbons are required to have a SDV (Suction Discharge Valve) on the suction side. This is because hydrocarbons are often volatile and flammable substances, and having a SDV helps to control the flow and prevent any potential accidents or leaks. The SDV allows for easy shut-off and isolation of the pump, ensuring safety during maintenance or emergencies. Therefore, it is necessary for all centrifugal pumps moving hydrocarbons to have a SDV on the suction side.

Explanation

All centrifugal pumps moving hydrocarbons are required to have a SDV (Suction Discharge Valve) on the suction side. This is because hydrocarbons are often volatile and flammable substances, and having a SDV helps to control the flow and prevent any potential accidents or leaks. The SDV allows for easy shut-off and isolation of the pump, ensuring safety during maintenance or emergencies. Therefore, it is necessary for all centrifugal pumps moving hydrocarbons to have a SDV on the suction side.

16. Separators

14. An ice plug has formed in the production piping. Explain the procedure to get rid of the ice plug.

Bleed off the downstream side of the ice plug and pump chemicals to thaw.

Bleed off the upstream side of the ice plug and try to back flow the plug to break it up.

Isolate both sides of the ice plug, bleed off each side, let thaw and start pumping methanol.

To get rid of the ice plug in the production piping, the correct procedure is to isolate both sides of the ice plug, bleed off each side, allow it to thaw, and then start pumping methanol. This method ensures that both sides of the plug are properly addressed and allows for the gradual thawing of the ice. Once the ice has melted, pumping methanol can help prevent the formation of future ice plugs.

Explanation

To get rid of the ice plug in the production piping, the correct procedure is to isolate both sides of the ice plug, bleed off each side, allow it to thaw, and then start pumping methanol. This method ensures that both sides of the plug are properly addressed and allows for the gradual thawing of the ice. Once the ice has melted, pumping methanol can help prevent the formation of future ice plugs.

17. Pipeline

3. The MMS and DOT require operators to pshyically mark their pipeline segments in the OCS fields.

True

False

The MMS (Minerals Management Service) and DOT (Department of Transportation) have regulations in place that mandate operators to physically mark their pipeline segments in the OCS (Outer Continental Shelf) fields. This means that operators are required to physically label or mark their pipelines in these specific areas to ensure proper identification and safety measures. Therefore, the given statement is true.

Explanation

The MMS (Minerals Management Service) and DOT (Department of Transportation) have regulations in place that mandate operators to physically mark their pipeline segments in the OCS (Outer Continental Shelf) fields. This means that operators are required to physically label or mark their pipelines in these specific areas to ensure proper identification and safety measures. Therefore, the given statement is true.

18. Glycol Handling

8. The condition of the charcoal filters can be observed by a differential pressure gauge.

True

False

The condition of the charcoal filters can be observed by a differential pressure gauge because the pressure drop across the filters increases as they become clogged with contaminants. This increase in pressure drop can be measured by a differential pressure gauge, allowing operators to determine when the filters need to be replaced or cleaned.

Explanation

The condition of the charcoal filters can be observed by a differential pressure gauge because the pressure drop across the filters increases as they become clogged with contaminants. This increase in pressure drop can be measured by a differential pressure gauge, allowing operators to determine when the filters need to be replaced or cleaned.

19. WELLHEADS

7. When greasing tree valves only that valve manufacture’s recommended grease should be used.

True

False

It is important to use the recommended grease by the valve manufacturer when greasing tree valves. This is because different valves may require different types or grades of grease to ensure proper lubrication and functioning. Using the wrong grease can lead to inadequate lubrication, increased friction, and potential valve failure. Therefore, it is crucial to follow the manufacturer's guidelines and use the recommended grease for greasing tree valves.

Explanation

It is important to use the recommended grease by the valve manufacturer when greasing tree valves. This is because different valves may require different types or grades of grease to ensure proper lubrication and functioning. Using the wrong grease can lead to inadequate lubrication, increased friction, and potential valve failure. Therefore, it is crucial to follow the manufacturer's guidelines and use the recommended grease for greasing tree valves.

20. WELLHEADS

9. The bottom manual master valve should be used to isolate the flow only as a last resort due to any down stream failures.

True

False

The bottom manual master valve should only be used as a last resort to isolate the flow in case of downstream failures. This suggests that there are other methods or valves in place to control and isolate the flow, and the bottom manual master valve is only to be used in emergency situations. Therefore, the statement "The bottom manual master valve should be used to isolate the flow only as a last resort due to any down stream failures" is true.

Explanation

The bottom manual master valve should only be used as a last resort to isolate the flow in case of downstream failures. This suggests that there are other methods or valves in place to control and isolate the flow, and the bottom manual master valve is only to be used in emergency situations. Therefore, the statement "The bottom manual master valve should be used to isolate the flow only as a last resort due to any down stream failures" is true.

21. Pumps

6. Centrifugal pumps need a charge pump or to be gravity fed to perform at their maximum efficiency.

True

False

Centrifugal pumps require a charge pump or gravity feed in order to operate at their highest efficiency. This means that without a charge pump or gravity feed, the pump may not function optimally and may not be able to achieve its maximum efficiency. Therefore, the statement "Centrifugal pumps need a charge pump or to be gravity fed to perform at their maximum efficiency" is true.

Explanation

Centrifugal pumps require a charge pump or gravity feed in order to operate at their highest efficiency. This means that without a charge pump or gravity feed, the pump may not function optimally and may not be able to achieve its maximum efficiency. Therefore, the statement "Centrifugal pumps need a charge pump or to be gravity fed to perform at their maximum efficiency" is true.

22. Compressors

15. The compressor has shut down, oil well gas may be flared continuously for a maximum of _____ hours total without receiving prior approval from the M.M.S.

110

220

48

144

If the compressor shuts down, the oil well gas can be flared continuously for a maximum of 48 hours without needing prior approval from the M.M.S. This means that the operators can release the gas into the atmosphere for up to 48 hours before seeking permission to do so.

Explanation

If the compressor shuts down, the oil well gas can be flared continuously for a maximum of 48 hours without needing prior approval from the M.M.S. This means that the operators can release the gas into the atmosphere for up to 48 hours before seeking permission to do so.

23. Pipeline

11. All LACT prover loops must have a water draw calibration procedure performed every 5 years.

True

False

The statement is true because LACT (Lease Automatic Custody Transfer) prover loops are used to measure the amount of water drawn from a well. To ensure accurate measurements, a water draw calibration procedure must be performed every 5 years. This procedure helps to calibrate the equipment and maintain the accuracy of the measurements over time.

Explanation

The statement is true because LACT (Lease Automatic Custody Transfer) prover loops are used to measure the amount of water drawn from a well. To ensure accurate measurements, a water draw calibration procedure must be performed every 5 years. This procedure helps to calibrate the equipment and maintain the accuracy of the measurements over time.

24. Pumps

1. API RP-14 C requires positive displacement pumps with discharge pressure > than the MAWP of the discharge piping to be equipped with a ________device to protect downstream piping.

PSV

LSH

LSL

Recycle Line

API RP-14 C requires positive displacement pumps with discharge pressure greater than the MAWP of the discharge piping to be equipped with a PSV (Pressure Safety Valve) device to protect downstream piping. This valve will automatically open and relieve excess pressure in the system, preventing any potential damage or failure of the piping.

Explanation

API RP-14 C requires positive displacement pumps with discharge pressure greater than the MAWP of the discharge piping to be equipped with a PSV (Pressure Safety Valve) device to protect downstream piping. This valve will automatically open and relieve excess pressure in the system, preventing any potential damage or failure of the piping.

25. Pumps

2. What device shall be located above each rod packing pump-transferring flammables?

TSE

PSH

Fire Extinguisher

Flood lights

The correct answer is TSE. TSE stands for "Thermal Safety Element" which is a device that is typically located above each rod packing pump when transferring flammables. It is designed to detect excessive heat and activate a shutdown system to prevent any potential fire or explosion hazards.

Explanation

The correct answer is TSE. TSE stands for "Thermal Safety Element" which is a device that is typically located above each rod packing pump when transferring flammables. It is designed to detect excessive heat and activate a shutdown system to prevent any potential fire or explosion hazards.

26. Separators

11. It is permissible to permanently bypass and then remove the LSH device on separators without MMS approval.

True

False

Permanently bypassing and removing the LSH device on separators without MMS (Minerals Management Service) approval is not permissible.

Explanation

Permanently bypassing and removing the LSH device on separators without MMS (Minerals Management Service) approval is not permissible.

27. Separators

12. All wells not in service need to have their safety devices checked monthly or else have ________ .

Disconnected and blind flanged from the header.

Valves closed and tagged.

Valves closed and tied shut

Closed, disconnect control line to SCSSV and Lock close master valve to secure well from flow.

not-available-via-ai

Explanation

not-available-via-ai

28. Separators

13. Snap action should be used on a liquid level controller when measuring liquids through a haliburton meter?

True

False

Snap action should be used on a liquid level controller when measuring liquids through a haliburton meter because snap action refers to a fast and immediate response to changes in the liquid level. This is important in a haliburton meter as it ensures accurate and precise measurement of the liquid level. Snap action helps to quickly detect any fluctuations in the liquid level and make adjustments accordingly, resulting in more reliable and efficient control of the liquid level.

Explanation

Snap action should be used on a liquid level controller when measuring liquids through a haliburton meter because snap action refers to a fast and immediate response to changes in the liquid level. This is important in a haliburton meter as it ensures accurate and precise measurement of the liquid level. Snap action helps to quickly detect any fluctuations in the liquid level and make adjustments accordingly, resulting in more reliable and efficient control of the liquid level.

29. Compressors

16. A compressor that uses a sliding type of piston compressing on both sides of the stroke is called what type of compressor?

Rotary Screw.

Liquid type piston.

Spiral-lobe compressor.

Double Acting Reciprocating compressor.

A compressor that uses a sliding type of piston compressing on both sides of the stroke is called a double-acting reciprocating compressor. This type of compressor is able to compress gas on both the upstroke and the downstroke of the piston, resulting in higher efficiency and increased output. The other options mentioned, such as rotary screw, liquid type piston, and spiral-lobe compressor, do not describe compressors that use a sliding type of piston compressing on both sides of the stroke.

Explanation

A compressor that uses a sliding type of piston compressing on both sides of the stroke is called a double-acting reciprocating compressor. This type of compressor is able to compress gas on both the upstroke and the downstroke of the piston, resulting in higher efficiency and increased output. The other options mentioned, such as rotary screw, liquid type piston, and spiral-lobe compressor, do not describe compressors that use a sliding type of piston compressing on both sides of the stroke.

30. WELLHEADS

5. Wellheads are not required to have the OCS lease number on them.

True

False

Wellheads are required to have the OCS lease number on them. This is because the OCS lease number is a unique identifier for each lease and is used to track and monitor the production from that specific lease. By having the OCS lease number on the wellheads, it becomes easier for regulatory authorities and operators to manage and regulate the production activities on the offshore lease.

Explanation

Wellheads are required to have the OCS lease number on them. This is because the OCS lease number is a unique identifier for each lease and is used to track and monitor the production from that specific lease. By having the OCS lease number on the wellheads, it becomes easier for regulatory authorities and operators to manage and regulate the production activities on the offshore lease.

31. Pipeline

6. Pipeline Visual Leak inspections must be preformed monthly unless a letter from the District Supervisor has approved other adjustments.

True

False

The explanation for the correct answer is that according to the given statement, Pipeline Visual Leak inspections must be performed monthly unless a letter from the District Supervisor has approved other adjustments. This means that the inspections should be conducted every month unless there is a specific approval from the District Supervisor for different arrangements. Therefore, the statement is true.

Explanation

The explanation for the correct answer is that according to the given statement, Pipeline Visual Leak inspections must be performed monthly unless a letter from the District Supervisor has approved other adjustments. This means that the inspections should be conducted every month unless there is a specific approval from the District Supervisor for different arrangements. Therefore, the statement is true.

32. Downhole Equipment
14. Gas lift gas is used to do what?

Used to lift heavy equipment

Used to increase gas production.

Used to produce an oil well with low bottom hole pressure

Used to produce water on wells with high bottom hole pressures.

Gas lift is a technique used in oil wells to increase production by injecting gas into the wellbore. This gas helps to reduce the pressure at the bottom of the well, allowing the oil to flow more easily to the surface. By using gas lift, the bottom hole pressure is lowered, which helps to overcome the natural pressure decline in the well and maintain or increase oil production. Therefore, the correct answer is "Used to produce an oil well with low bottom hole pressure."

Explanation

Gas lift is a technique used in oil wells to increase production by injecting gas into the wellbore. This gas helps to reduce the pressure at the bottom of the well, allowing the oil to flow more easily to the surface. By using gas lift, the bottom hole pressure is lowered, which helps to overcome the natural pressure decline in the well and maintain or increase oil production. Therefore, the correct answer is "Used to produce an oil well with low bottom hole pressure."

33. Separators

7. O.S.H.A. does require an operator to have a cage around a fixed ladder 20’ or higher.

True

False

According to O.S.H.A. regulations, an operator is required to have a cage around a fixed ladder that is 20 feet or higher. This is done to ensure the safety of the operator and prevent any accidents or falls from occurring. The cage provides a protective barrier and helps to minimize the risk of injuries while using the ladder. Therefore, the correct answer is true.

Explanation

According to O.S.H.A. regulations, an operator is required to have a cage around a fixed ladder that is 20 feet or higher. This is done to ensure the safety of the operator and prevent any accidents or falls from occurring. The cage provides a protective barrier and helps to minimize the risk of injuries while using the ladder. Therefore, the correct answer is true.

34. Pumps

5. Positive displacement pumps are designed to;

Move large amounts of liquid

Pump liquids into high pressure.

Pump only H2O.

Positive displacement pumps are designed to pump liquids into high pressure. This means that these types of pumps are specifically designed to increase the pressure of the liquid being pumped. They do not necessarily move large amounts of liquid or pump only H2O. Instead, their main purpose is to increase the pressure of the liquid being pumped, regardless of the volume or type of liquid.

Explanation

Positive displacement pumps are designed to pump liquids into high pressure. This means that these types of pumps are specifically designed to increase the pressure of the liquid being pumped. They do not necessarily move large amounts of liquid or pump only H2O. Instead, their main purpose is to increase the pressure of the liquid being pumped, regardless of the volume or type of liquid.

35. WELLHEADS

6. Problem, you have a well on a satellite structure that can only be viewed during the day, yet it has cut out 2 flow lines and made a slick in the past. What device would you install in the flow line to help prevent the sand from cutting out another flow line in the future?

A PSH

A Sand Probe

A PSL

A titanium flow line

A sand probe would be installed in the flow line to help prevent the sand from cutting out another flow line in the future. Sand probes are designed to detect the presence of sand or solids in the flow line. When sand is detected, appropriate measures can be taken to mitigate the issue, such as adjusting flow rates or installing sand control equipment. By detecting and addressing the presence of sand early on, the sand probe helps to prevent further damage to the flow line caused by sand erosion.

Explanation

A sand probe would be installed in the flow line to help prevent the sand from cutting out another flow line in the future. Sand probes are designed to detect the presence of sand or solids in the flow line. When sand is detected, appropriate measures can be taken to mitigate the issue, such as adjusting flow rates or installing sand control equipment. By detecting and addressing the presence of sand early on, the sand probe helps to prevent further damage to the flow line caused by sand erosion.

36. Compressors

6. It is possible to rod load a reciprocating compressor if the suction pressure gets too low on the 1 st stage.

True

False

When the suction pressure in a reciprocating compressor's 1st stage gets too low, it can cause the compressor to rod load. Rod loading refers to the condition where the piston rod is subjected to excessive stress due to the reduced suction pressure. This can lead to mechanical failures and damage to the compressor. Therefore, it is true that a reciprocating compressor can be rod loaded if the suction pressure gets too low on the 1st stage.

Explanation

When the suction pressure in a reciprocating compressor's 1st stage gets too low, it can cause the compressor to rod load. Rod loading refers to the condition where the piston rod is subjected to excessive stress due to the reduced suction pressure. This can lead to mechanical failures and damage to the compressor. Therefore, it is true that a reciprocating compressor can be rod loaded if the suction pressure gets too low on the 1st stage.

37. Pipeline

2. Which of the following is true of a check valve?

Closes automatically

Ensures proper flow direction

May be installed vertically or horizontally, depending on the type of check valve

All of the above.

A check valve is a type of valve that allows fluid to flow in only one direction. It closes automatically to prevent backflow and ensure proper flow direction. Depending on the type of check valve, it can be installed vertically or horizontally. Therefore, all of the given statements are true about a check valve.

Explanation

A check valve is a type of valve that allows fluid to flow in only one direction. It closes automatically to prevent backflow and ensure proper flow direction. Depending on the type of check valve, it can be installed vertically or horizontally. Therefore, all of the given statements are true about a check valve.

38. Water Handling

5. Produced water can be polished before going to the lab for testing.

True

False

Produced water cannot be polished before going to the lab for testing. Polishing refers to the process of removing impurities or contaminants from water. In the case of produced water, it is the water that is extracted along with oil or gas from reservoirs. This water contains various impurities such as salts, solids, and chemicals, which cannot be easily removed through polishing. Therefore, produced water is typically sent directly to the lab for testing without undergoing any polishing treatment.

Explanation

Produced water cannot be polished before going to the lab for testing. Polishing refers to the process of removing impurities or contaminants from water. In the case of produced water, it is the water that is extracted along with oil or gas from reservoirs. This water contains various impurities such as salts, solids, and chemicals, which cannot be easily removed through polishing. Therefore, produced water is typically sent directly to the lab for testing without undergoing any polishing treatment.

39. WELLHEADS

8. Flow line-check valves are allowed to leakage rates of 5 standard cubic feet of gas or 200 c.c.’s of liquid per minute.

True

False

Flow line-check valves are allowed to have leakage rates of 5 standard cubic feet of gas or 200 c.c.'s of liquid per minute. This means that a small amount of gas or liquid is permitted to leak through the check valves without causing any significant issues or safety concerns. Therefore, the statement is true.

Explanation

Flow line-check valves are allowed to have leakage rates of 5 standard cubic feet of gas or 200 c.c.'s of liquid per minute. This means that a small amount of gas or liquid is permitted to leak through the check valves without causing any significant issues or safety concerns. Therefore, the statement is true.

40. Compressors

4. The LSL devices on the scrubbers may be SAC’d out with this reference A4e3 as per
API 14 C.

True

False

The statement is true because according to API 14 C, the LSL devices on the scrubbers can be shut off and isolated (SAC'd out) using the reference A4e3. This means that the devices can be deactivated or disconnected for maintenance or safety purposes.

Explanation

The statement is true because according to API 14 C, the LSL devices on the scrubbers can be shut off and isolated (SAC'd out) using the reference A4e3. This means that the devices can be deactivated or disconnected for maintenance or safety purposes.

41. Compressors

14. Gas well gas may be flared for a reasonable time it takes to eliminate an emergency without receiving permission from the M.M.S.

True

False

Gas well gas may be flared for a reasonable time it takes to eliminate an emergency without receiving permission from the M.M.S. This statement is true because in emergency situations, it is necessary to quickly eliminate the danger caused by the gas well gas. Waiting for permission from the M.M.S. may cause delays and further escalate the emergency. Therefore, it is reasonable to flare the gas for a limited time until the emergency is resolved.

Explanation

Gas well gas may be flared for a reasonable time it takes to eliminate an emergency without receiving permission from the M.M.S. This statement is true because in emergency situations, it is necessary to quickly eliminate the danger caused by the gas well gas. Waiting for permission from the M.M.S. may cause delays and further escalate the emergency. Therefore, it is reasonable to flare the gas for a limited time until the emergency is resolved.

42. Water Handling

8. When water samples come in at 50 ppm, you must take additional samples in order to reduce the overall monthly average of the overboard water ppm.

True

False

When water samples come in at 50 ppm, taking additional samples can help to reduce the overall monthly average of the overboard water ppm. By taking more samples, it allows for a more accurate representation of the water quality over time. This can help to identify any potential issues or fluctuations in the water quality and ensure that the overall average remains within acceptable limits. Therefore, the statement is true.

Explanation

When water samples come in at 50 ppm, taking additional samples can help to reduce the overall monthly average of the overboard water ppm. By taking more samples, it allows for a more accurate representation of the water quality over time. This can help to identify any potential issues or fluctuations in the water quality and ensure that the overall average remains within acceptable limits. Therefore, the statement is true.

43. Downhole Equipment

2. A SCSSV has an allowable leakage rate?

True

False

A SCSSV (Surface Controlled Subsurface Safety Valve) is a type of safety valve used in oil and gas wells to prevent the uncontrolled release of fluids. It is designed to close automatically in the event of an emergency, such as a blowout or equipment failure. The allowable leakage rate refers to the amount of fluid that is allowed to pass through the valve when it is closed. In order to ensure the valve is functioning properly, a small amount of leakage is permitted. Therefore, the statement "A SCSSV has an allowable leakage rate" is true.

Explanation

A SCSSV (Surface Controlled Subsurface Safety Valve) is a type of safety valve used in oil and gas wells to prevent the uncontrolled release of fluids. It is designed to close automatically in the event of an emergency, such as a blowout or equipment failure. The allowable leakage rate refers to the amount of fluid that is allowed to pass through the valve when it is closed. In order to ensure the valve is functioning properly, a small amount of leakage is permitted. Therefore, the statement "A SCSSV has an allowable leakage rate" is true.

44. Pumps

4. Centrifugal pumps are designed to;

Move large amounts of liquids usually at low pressure.

Pump liquids into high pressure.

Pump only oil.

Centrifugal pumps are designed to move large amounts of liquids usually at low pressure. This means that they are capable of transferring a significant volume of liquid, but not at a high pressure. They are commonly used in applications such as water supply, irrigation, and wastewater treatment, where a large volume of liquid needs to be moved efficiently. They are not designed specifically for pumping only oil, and they are not intended for pumping liquids into high pressure.

Explanation

Centrifugal pumps are designed to move large amounts of liquids usually at low pressure. This means that they are capable of transferring a significant volume of liquid, but not at a high pressure. They are commonly used in applications such as water supply, irrigation, and wastewater treatment, where a large volume of liquid needs to be moved efficiently. They are not designed specifically for pumping only oil, and they are not intended for pumping liquids into high pressure.

45. Compressors

13. Where would you find the minimum and maximum allowable RPM’s you could run your compressor at to be safe and well within the limits of the machine?

You don’t have to worry about the limits of the machine, run it at whatever speed you can.

This information can be found on the nameplate located on the engine.

Better call a mechanic for this.

This information is found on the Monthly MMS paperwork.

The correct answer is "This information can be found on the nameplate located on the engine." The nameplate on the engine typically provides important information about the machine, including the minimum and maximum allowable RPM's. By referring to the nameplate, one can ensure that the compressor is operated within safe limits and avoid any potential damage or malfunction.

Explanation

The correct answer is "This information can be found on the nameplate located on the engine." The nameplate on the engine typically provides important information about the machine, including the minimum and maximum allowable RPM's. By referring to the nameplate, one can ensure that the compressor is operated within safe limits and avoid any potential damage or malfunction.

46. Downhole Equipment
7. As wells age, their flowing characteristics change. When this happens oil and gas rates usually go down and water rates increase. Which of the following explains what causes good wells to become loaded up.

Water drive well, water increases.

BHP is unable to overcome the hydrostatic head when heavier fluids enter the well bore.

Good wells will always flow no matter how much water enters well bore.

Bottom hole pressure continues to increase as the well gets older.

As wells age, heavier fluids such as water enter the well bore. The bottom hole pressure (BHP) is the pressure at the bottom of the well, and it needs to overcome the hydrostatic head of the heavier fluids in order to continue flowing. However, as the well gets older, the BHP may not be able to overcome the hydrostatic head, causing the well to become loaded up and leading to a decrease in oil and gas rates and an increase in water rates.

Explanation

As wells age, heavier fluids such as water enter the well bore. The bottom hole pressure (BHP) is the pressure at the bottom of the well, and it needs to overcome the hydrostatic head of the heavier fluids in order to continue flowing. However, as the well gets older, the BHP may not be able to overcome the hydrostatic head, causing the well to become loaded up and leading to a decrease in oil and gas rates and an increase in water rates.

47. Pipeline

1. A _______ is required on all KAH or departing pipelines to minimize back flow. (choose one)

Block Valve

FSV

Controller

PSV

An FSV (Flow Sensing Valve) is required on all KAH or departing pipelines to minimize back flow. This valve helps to regulate the flow of fluid and prevent any reverse flow or backflow in the pipeline. It is designed to sense the direction of flow and close if there is any attempt of backflow, ensuring that the fluid only flows in the desired direction. This helps to maintain the integrity and efficiency of the pipeline system.

Explanation

An FSV (Flow Sensing Valve) is required on all KAH or departing pipelines to minimize back flow. This valve helps to regulate the flow of fluid and prevent any reverse flow or backflow in the pipeline. It is designed to sense the direction of flow and close if there is any attempt of backflow, ensuring that the fluid only flows in the desired direction. This helps to maintain the integrity and efficiency of the pipeline system.

48. Pipeline

13. Underground pipelines are continuously protected from external corrosion by what?

Their external coating

Annodes

Cathodic protection with induced voltage.

All of the above.

Underground pipelines are continuously protected from external corrosion by a combination of methods. The external coating acts as a physical barrier between the pipeline and the surrounding environment, preventing direct contact and corrosion. Anodes are used to provide sacrificial protection, where they corrode instead of the pipeline, further preventing corrosion damage. Cathodic protection with induced voltage is another method used, where an electric current is applied to the pipeline to create a protective electrochemical reaction. Therefore, all of the mentioned methods work together to protect underground pipelines from external corrosion.

Explanation

Underground pipelines are continuously protected from external corrosion by a combination of methods. The external coating acts as a physical barrier between the pipeline and the surrounding environment, preventing direct contact and corrosion. Anodes are used to provide sacrificial protection, where they corrode instead of the pipeline, further preventing corrosion damage. Cathodic protection with induced voltage is another method used, where an electric current is applied to the pipeline to create a protective electrochemical reaction. Therefore, all of the mentioned methods work together to protect underground pipelines from external corrosion.

49. Downhole Equipment

1. As per 30 CFR 250, what is the interval for testing SCSSV’s?

Not to exceed one month

Not to exceed 6 months

Not to exceed 1 year

According to 30 CFR 250, the interval for testing SCSSV's should not exceed 6 months. This means that the safety valve should be tested at least once every 6 months to ensure its proper functioning and to prevent any potential failures or malfunctions. Regular testing helps to maintain the integrity and reliability of the downhole equipment, ensuring the safety of the operations.

Explanation

According to 30 CFR 250, the interval for testing SCSSV's should not exceed 6 months. This means that the safety valve should be tested at least once every 6 months to ensure its proper functioning and to prevent any potential failures or malfunctions. Regular testing helps to maintain the integrity and reliability of the downhole equipment, ensuring the safety of the operations.

50. WELLHEADS

2. The upper master valve, (SSV) is the only safety valve on the tree the MMS requires to close within _______ seconds of ESD activation.

10 sec

30 sec

45 sec

90 sec

The upper master valve, also known as the SSV (Surface Safety Valve), is the only safety valve on the wellhead tree that needs to close within 45 seconds of Emergency Shut Down (ESD) activation. This quick closure is crucial in preventing any potential hazards or uncontrolled release of fluids from the wellhead. By closing within 45 seconds, the SSV helps to maintain the integrity and safety of the wellhead system.

Explanation

The upper master valve, also known as the SSV (Surface Safety Valve), is the only safety valve on the wellhead tree that needs to close within 45 seconds of Emergency Shut Down (ESD) activation. This quick closure is crucial in preventing any potential hazards or uncontrolled release of fluids from the wellhead. By closing within 45 seconds, the SSV helps to maintain the integrity and safety of the wellhead system.

51. WELLHEADS

3. If you have a wellhead rated for 5,000# and the well flows at 2,500# FTP, and you found 6,000# on the wellhead panel to hold the SCSSV open, it is ok to keep this pressure on the safety valve.

True

False

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.

Explanation

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.

52. Separators

8. It is OK to put a lower rated needle valve on a vessel as long as the pressure coming in won’t exceed the needle valve’s rating. (EX: 1440 psi vessel with 1000 psi needle valve)

True

False

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.

Explanation

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.

53. Downhole Equipment

4. All wells capable of natural flow need to have a ________ or ________installed in the tubing at least 100 feet below the mud line.

SCSSV or Plug

GLV or SSV

SCSSV or SSCSSV

All of the Above

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.

Explanation

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.

54. Separators

3. As per 14-C all separators need to have a certain number of _____ on them for fire detection.

TSH

TSE

ASH

ESD

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

Explanation

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

55. Pumps

7. All positive displacement pipeline pumps are lubricated by the process fluid and don’t require external oiling devices.

True

False

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.

Explanation

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.

56. Compressors

7. All ________ are to be properly sized to allow the maximum inlet flow anticipated which will protect the vessel from overpressure.

PSV

PSH

LSH

None of the above

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

Explanation

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

57. Pumps

9. The PSH on the discharge of a pump can be SAC’ed out if the MAWP of the pump does not exceed ________ % of the discharge piping.

70%

85%

100%

PSH can not be SAC'ed out

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.

Explanation

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.

58.

4. This device is required on all KAQ or incoming pipelines and must complete its task in 45 seconds or less after an upset or the ESD is activated.________________.

SCSSV

SDV

PSH

PSV

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.

Explanation

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.

59. Downhole Equipment

9. Problem, a gas lift well has had a history of making C O 2 and now has holes in the tubing. The holes have been sealed with pack-offs. You are unable to maintain gas lift pressure to lift the well, gases around. What do you believe has started to happen to this well?

Pack offs are leaking.

More holes have developed in the tubing above the liquid level

There is a problem with one of the gas lift valves.

More than likely, All of the above.

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.

Explanation

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.

60. Separators

10. 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.

True

False

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.

Explanation

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.

61. Pipeline

8. Your offshore and when you see a pipeline segment is out of service and approaching one year time frame, what must be done to this line?

Nothing because the MMS doesn’t care how long these lines aren’t used.

Must call MMS and let them know that nothing has been done on this line.

Line must be purged, pickled and isolated from service before one year of date it was OOS.

All of the above

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.

Explanation

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.

62. 9. Fluid levels in vessels are controlled by?

Back pressure valves.

Spill over plates and weirs.

Float assemblies.

Both 2 & 3

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.

Explanation

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.

63. Glycol Handling

4. What are bubble caps?

Devices that retains oil in the bottom of the contact tower.

Devices which keep a level of glycol above their rims slots so gas has to travel through glycol.

Devices which are designed to give a bubble tight connection on the external pump.

All of the above

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.

Explanation

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.

64. Downhole Equipment
11. Problem, you have a flowing gas well that flows cold enough in the winter to cause hydrates in the choke body. Methanol has been injected through the colder winter months to keep the choke body from freezing up. You have been asked to increase the size of the choke in this well. About an hour after increasing the choke size the well has shut in on a PSH on the flow line pilot. What could have caused the high pilot to shut in this well?

Increased choke size raised pressure in the flowline above the pilot set point.

Methanol injection rate was not increased and hydrates have formed in the line.

Both 1 and 2.

Neither 1 or 2.

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.

Explanation

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.

65. Pipeline

12. What is the maximum allowable BS&W entering an oil sales pipeline?

0%

10%

1%

.05%

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.

Explanation

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.

66. Downhole Equipment
10. Under what circumstances may the MMS district supervisor grant permission to lock out a SCSSV and install a SSCSV?

The SCSSV is leaking and is a tubing retrievable safety valve.

The well has been depleted and will no longer produce oil & gas.

During hurricane season.

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.

Explanation

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.

67. Compressors

2. API 14-C requires all gas compressor discharge stage cylinders to have a __________ to protect from high temperature.

TSE

TSH

LSL

ASH

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.

Explanation

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.

68. Compressors

10. As a general rule what is the optimum temperature of the final stage discharge of a reciprocating gas compressor?

90

250

500

950

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.

Explanation

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.

69. Pipeline

10. LACT units or Allocation Liquid Meters measuring 50 barrels or more of oil daily must be proved

Daily

Weekly

Annually

Monthly

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.

Explanation

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.

70. WELLHEADS

10. What device is required over each well head?

A light fixture

A TSE

A Deluge system

A pressure gauge

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

Explanation

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

71. Separators

2. Choke nipples are installed in vessel liquid dump lines to :

Protect downstream equipment in case of dump valve failure

Keep backpressure on vessel.

Keep backpressure on wells.

Everyone knows you don’t put chokes on liquid dump lines

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.

Explanation

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.

72. Compressors

11. It is necessary that the recycle valve trim be properly sized. What is one indication that the trim may be over sized?

Recycle valve is full open but compressor shuts down on suction PSL.

Recycle valve opens and closes constantly and cannot control suction pressure.

Recycle valve is steady and suction pressure is normal.

None of the above

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.

Explanation

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.

73. Glycol Handling

7. Generally, what is the maximum amount of water allowed to enter a pipeline under a dry gas contract?

5 to 7 pounds of water per million standard cubic feet of gas.

7 to 10 pounds of water per thousand standard cubic feet of gas.

10 to 15 pounds of water per hundred standard cubic feet of gas.

None of the above.

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.

Explanation

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.

74. Separators

4. If you have a separator that requires 2 PSV's; you can temporary remove one and send it in for repair but still be in compliance with the other one.

True

False

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.

Explanation

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.

75. Glycol Handling

1. What is the purpose of Glycol systems?

To clean up the oil so it can be sold.

To clean up the gas stream to remove impurities.

To remove water from the natural gas

All of the above.

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

Explanation

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

76. Water Handling

4. It is legal to take two water overboard samples and analyze one before you send the other to the lab for analysis

True

False

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.

Explanation

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.

77. Exercise #2: Please figure the following well test from the data you got after you pulled the numbers from the High Pressure test separator: Well was in test 4 hours. Recorded volumes you got were as follows: Total gas produced was 600 mmscf. Total liquids produced was 50 bbls. BS&W observed was 30% on the shakeout. Well is on a 24/64ths choke. FTP observed was 1230 PSI. Casing pressure observed was 0. Test Separator was running at 1120 PSAnswer the following:

Answer the following:
1. Total Gas Produced: _________MSCFPD

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.

Explanation

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.

Submit

78. WELLHEADS

11. What is the most probable cause of a well having abnormally Low tubing pressure?

Down hole valve shut in.

Valve downstream of the well has shut in.

High gas sales pressure.

Well has probably been gas lifted and no longer can flow.

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.

Explanation

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.

79. Compressors

8. TSH-Exline temperature elements on gas compressor bottles need to be inspected ________________.

Dailey

Monthly

Every six months

Annually

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.

Explanation

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.

80. Glycol Handling

10. What is the preferred PH level of Triethylene glycol?

10

9

7

5

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.

Explanation

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.

81. Water Handling

7. Unmanned platforms with production equipment and have approved waiver from MMS are not required to have a daily pollution check performed.

True

False

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.

Explanation

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.

82. Pumps

12. A pump will vapor lock when?

The flow going through it increases too much for it to handle it.

The suction pressure goes down and can’t increase.

The pressure drop in the suction piping is more than the liquid pressure head.

The flow to the pump is packed.

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.

Explanation

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.

83. Downhole Equipment
12. A gas flow chart recorder is used to measure the volume of gas lift gas and also indicates the performance of the gas lift valves. Describe how the chart can indicate gas lift valve performance.

Static pen indicates flow rate and differential pen indicates valve operation.

Differential pen indicates flow rate and static pen indicates valve operation.

Doesn’t matter which pen you use.

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.

Explanation

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.

84. Compressors

5. How often do TSH’s on compressor installations need to be inspected if they are of the nondestructive type?

Dailey

Monthly

Every 6 months

Annually

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.

Explanation

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.

85. Downhole Equipment
6. Under what conditions may a well be flowed with the SCSSV locked out or the SSCSV removed?

During routine wireline operations

No flow wells

Both 1 & 2

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.

Explanation

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.

86. Pipeline

5. If a well flows into a down rated pipeline and there is no PSV on the header or flow line, a secondary _______ is required on the flowing well.

LSH

PSH

Flowline

SDV

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.

Explanation

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.

87. Glycol Handling

14. What is the most reasonable answer that glycol is being lost in the system?

Too much gas entering the contact tower causing the glycol to be swept out of the vessel.

Someone is bleeding down the system.

Too much heat in the reboiler, need to cool it down.

Gas is way too wet for the system to handle.

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.

Explanation

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.

88. WELLHEADS

1. What is the most probable cause of a well having abnormally high tubing pressure?

Down hole valve shut in.

Valve downstream of the well has shut in

Choke body has been cut out.

Well is more than likely loaded up.

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.

Explanation

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.

89. Separators

15. The PSV on a vessel with a MAWP of 1440 psig should be set at what pressure?

The designed working pressure of the vessel.

Whatever the operator decides is the best set pressure he wants.

5% under the designed working pressure.

15% under the designed working pressure.

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.

Explanation

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.

90. Compressors

12. Your reciprocating gas compressor is rated at 15 MMCFD but you are only producing 2 MMCFD the cylinder temperatures are running high and recycling does not help. What field modification to the compressor cylinders can be done to correctly load the compressor?

Adjust the pockets of the compressor ends as far in as they can go.

Can’t make any field modifications.

Better call a mechanic for making this modification.

None of the above

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.

Explanation

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.

91. Glycol Handling

3. Explain the purpose of stripping or contact towers.

So Gas makes contact with Glycol for dehydrating.

To ensure the water in the gas is separated from the oil.

To heat the gas before it goes to sales.

All of the above.

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."

Explanation

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."

92. Water Handling

1. What is the daily allowable limit of oil and grease for produced water disposed of overboard in federal waters?

72 daily and 52 monthly

72 daily and 48 monthly

42 daily and 29 monthly

42 daily and 52 monthly

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.

Explanation

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.

93. Exercise #1. When you came on tower, you found the high pressure separator going down on the pressure safety high pilot. You realize that the new well your relief brought on is now producing at a much higher rate than before the new well was placed in service. You have to run a new range chart and this is what you have. Please figure the following from this chart: Give just the number

MAWP=1440

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.

Explanation

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.

Submit

94. Exercise #2: Please figure the following well test from the data you got after you pulled the numbers from the High Pressure test separator: Well was in test 4 hours. Recorded volumes you got were as follows: Total gas produced was 600 mmscf. Total liquids produced was 50 bbls. BS&W observed was 30% on the shakeout. Well is on a 24/64ths choke. FTP observed was 1230 PSI. Casing pressure observed was 0. Test Separator was running at 1120 PSI. Answer the following: 3. Total Water Produced: _________BBL’s Per Day

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.

Explanation

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.

Submit

95. WELLHEADS

4. It is OK to remove the well head after you close the SCSSV and bleed the tubing to zero for a rig job.

True

False

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.

Explanation

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.

96. WELLHEADS

12. You have a well that is gas lifted and the client wants to reduce restrictions to the flow, what type of elbow would you recommend to him?

45 degree elbow

90 degree elbow

Short radius elbow

Long radius elbow

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.

Explanation

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.

97. Pumps

10. Pressure on the suction side is 50 psi, pump discharges to 400 psi. When a positive displacement pump is shut down, it is possible for the pump media to flow through the pump body and valves.

True

False

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.

Explanation

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.

98. Downhole Equipment
13. What is the maximum time allowed as per 30 CFR for the SCSSV to close after the ESD has been activated?

2 min 45 sec

1 min 15 sec

2 min

1 min 45 sec

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.

Explanation

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.

99. Compressors

9. The gas compressor has shut down on TSH first stage discharge. Checking the Ex-Line, you find it has melted. What should you do next to troubleshoot the failure?

Pull all of the Ex-Lines on the compressor and check to see if they are burnt.

Pull the suction valves on the 1st stage compressor and check for damages.

Pull the suction valves on the 2nd stage compressor and check for damages.

Pull discharge valves on 1st stage compressore and check for damages.

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.

Explanation

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.

100. Downhole Equipment

8. Name three noticeable changes that can be seen to warrant an operator to check a positive choke that may be cut out?

Decrease flowing tubing psi, increase water production, increase gas production.

Decrease flowing tubing psi, lower gas production, lower total fluid production.

Increase flowing tubing psi, increase gas production, lower total fluid production.

Increase flowing tubing psi, increase BHP, increase casing pressure.

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.

Explanation

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.

101. Glycol Handling

11. What is the most reasonable answer that causes foaming in the glycol system?

Too much water in the gas

Too much contamination in the glycol.

Not enough heat on the system.

Gas Blowby

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.

Explanation

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.

102. Glycol Handling

13. Glycol that has a high PH level when you took the test. What should be added to the system to bring down the PH level?

Definitely need to add glycol to the system.

Need to find some acid to add to the system.

Need to find some alkaline to add to the system.

PH level should be high in a glycol system.

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.

Explanation

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.

103. Separators

6. Referencing API RP-14C; there are two types of production vessels,

Horizontal and vertical.

Two phase and three phase.

Atmospheric and pressure

Oil and Gas.

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.

Explanation

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.

104. Glycol Handling

6. Define dew point.

The quantity of water in the gas.

The amount wet gas.

The point at which water forms in gas.

All of the above.

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.

Explanation

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.

105. Exercise #1. When you came on tower, you found the high pressure separator going down on the pressure safety high pilot. You realize that the new well your relief brought on is now producing at a much higher rate than before the new well was placed in service. You have to run a new range chart and this is what you have. Please figure the following from this chart: Give the number only

MAWP = 1440

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.

Explanation

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.

Submit

106. Downhole Equipment
3. What must be done when pressure is first observed on any of the casing strings?

Notify MMS

Perform a diagnostic test

Monitor Monthly

All of the above

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.

Explanation

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.

Submit

108. Glycol Handling

5. What is the maximum temperature tri-ethylene glycol should be subjected to?

404

350

475

None of the above

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

Explanation

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

109. Pumps

11. It is very common for the discharge of a pump to bleed down to “O” pressure after it cycles tripping the PSL causing nuisance alarms and preventing a restart of the pump. What can be done to the PSL logic to prevent this from happening?

Install a check valve in the discharge piping.

Install an MMS approved startup time delay on the PSL pilot.

SAC out the PSL

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.

Explanation

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.

110. Exercise #2: Please figure the following well test from the data you got after you pulled the numbers from the High Pressure test separator: Well was in test 4 hours. Recorded volumes you got were as follows: Total gas produced was 600 mmscf. Total liquids produced was 50 bbls. BS&W observed was 30% on the shakeout. Well is on a 24/64ths choke. FTP observed was 1230 PSI. Casing pressure observed was 0. Test Separator was running at 1120 PSI. Answer the following: 2. Total Oil Produced: _________BBL’s Per Day

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.

Explanation

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.

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111. Water Handling

6. The water being discharged from a sump tank must be tested monthly for oil and grease content along with the produced water.

True

False

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.

Explanation

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.

112. Exercise #1. When you came on tower, you found the high pressure separator going down on the pressure safety high pilot. You realize that the new well your relief brought on is now producing at a much higher rate than before the new well was placed in service. You have to run a new range chart and this is what you have. Please figure the following from this chart: Give the number only

MAWP = 1440

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.

Explanation

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.

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113. Exercise #1. When you came on tower, you found the high pressure separator going down on the pressure safety high pilot. You realize that the new well your relief brought on is now producing at a much higher rate than before the new well was placed in service. You have to run a new range chart and this is what you have. Please figure the following from this chart: Give the number only

MAWP=1440

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.

Explanation

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.

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