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IWCF WIPC Level 2 study materials
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IWCF WIPC Level 2 practice questions

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Question 1Completion Operations (compulsory)

During a completion operation, what is the primary purpose of the completion fluid placed in the wellbore before running the upper completion?

  1. To permanently cement the production casing to the formation
  2. To act as a lubricant for the drill string during milling operations
  3. To dissolve the filter cake and stimulate production before perforating
  4. To provide a clean, density-controlled column that controls formation pressure without damaging the reservoir Correct answer.

Explanation

A completion fluid is selected to give a hydrostatic overbalance against the formation pressure while remaining solids-free or solids-controlled to minimise formation damage. It is not a cementing or stimulation fluid, and its density is engineered to the reservoir pressure window.

Question 2Completion Operations (compulsory)

A packer is run as part of the upper completion. What is the main function of the production packer?

  1. To measure the tubing pressure and transmit it to surface
  2. To centralise the casing during cementing
  3. To provide a flow path for annular gas to the surface
  4. To isolate the annulus above the packer from the producing interval and anchor the tubing string Correct answer.

Explanation

The production packer seals the tubing-casing annulus, isolating the reservoir from the annulus and protecting the casing from pressure and corrosive well fluids. It also provides a mechanical anchor for the tubing string.

Question 3Completion Operations (compulsory)

Which type of packer is set by mechanical manipulation of the tubing string, such as rotation and setting down weight?

  1. Weight-set or mechanical-set packer Correct answer.
  2. Hydraulic-set packer
  3. Retrievable bridge plug
  4. Inflatable packer

Explanation

A mechanical-set packer is actuated by tubing movement such as rotation and slacking off weight, which shears a pin and drives the slips and element into contact. Hydraulic-set packers rely on applied pressure, and inflatable packers use fluid inflation of an elastomer bladder.

Question 4Completion Operations (compulsory)

What is the purpose of a tubing retrievable safety valve (TRSCSSV) in the upper completion?

  1. To shut off flow automatically when surface controls are lost, providing a fail-safe barrier in the tubing Correct answer.
  2. To regulate the production rate to a set choke size
  3. To inject chemicals into the tubing string
  4. To provide a circulation path between tubing and annulus

Explanation

The surface-controlled subsurface safety valve is a fail-safe barrier that closes when its control line pressure is bled off, isolating the wellbore in an emergency. It is not a flow regulator or injection point.

Question 5Completion Operations (compulsory)

In a gravel pack completion, what is the primary role of the gravel placed in the annulus between the screen and the formation?

  1. To seal off water-producing zones permanently
  2. To retain formation sand while allowing produced fluids to flow through the screen Correct answer.
  3. To support the screen mechanically against collapse
  4. To provide a path for cement to reach the casing shoe

Explanation

Gravel packing places sized gravel around the screen so formation sand is retained behind the gravel while fluids flow freely. The gravel acts as a filter medium, and the screen retains the gravel.

Question 6Completion Operations (compulsory)

What does the term 'perforating' refer to in a cased-hole completion?

  1. Cutting windows in the casing to drill a sidetrack
  2. Running a liner hanger into the wellbore
  3. Testing the casing shoe for leaks after cementing
  4. Creating holes through casing and cement into the formation to allow fluid communication Correct answer.

Explanation

Perforating uses shaped charges to create tunnels through casing, cement and into the reservoir rock, establishing communication between the wellbore and the formation. It is a distinct operation from window milling or liner running.

Question 7Completion Operations (compulsory)

Which completion component is installed to allow selective communication between the tubing and the annulus at a chosen depth?

  1. Sliding side door (sliding sleeve) Correct answer.
  2. Tubing hanger
  3. Landing nipple
  4. Polished bore receptacle

Explanation

A sliding side door or sliding sleeve is opened and closed by wireline or shifting tool to connect tubing and annulus at a specific depth. It is used for circulation, production from a zone, or intervention access.

Question 8Completion Operations (compulsory)

What is the function of the tubing hanger in a completion?

  1. To suspend and seal the tubing string in the wellhead and provide a pressure barrier at surface Correct answer.
  2. To centralise the tubing inside the casing
  3. To provide a downhole anchor for the packer
  4. To control the flow rate from the reservoir

Explanation

The tubing hanger lands in the wellhead, supports the weight of the tubing string, and provides seals and outlets that allow pressure control at surface. It is a key surface barrier in the completion.

Question 9Completion Operations (compulsory)

Before running the completion, the well is normally killed and the casing is pressure tested. Why is a positive pressure test of the casing and wellhead performed at this stage?

  1. To check the viscosity of the completion fluid
  2. To confirm the barriers can hold the maximum anticipated pressure before the well is opened up Correct answer.
  3. To determine the optimum perforating charge
  4. To measure the reservoir permeability

Explanation

A positive pressure test verifies the integrity of casing, wellhead and seals against the maximum anticipated surface pressure before the well is placed in a producing or intervention condition. It is a barrier verification, not a reservoir measurement.

Question 10Completion Operations (compulsory)

A hydraulic-set production packer is to be set. Which sequence is correct?

  1. Run to depth, set weight down on the packer, then pressure test the annulus
  2. Run to depth, apply hydraulic pressure through the tubing to shear the setting device, then release and verify the set Correct answer.
  3. Run to depth, rotate the tubing to shear the pin, then apply pressure to set the element
  4. Run to depth, drop a ball and pump it to seat, then rotate the tubing to set the slips

Explanation

Hydraulic-set packers are run to depth and actuated by applied pressure, typically through the tubing, which shears the setting mechanism and drives the slips and element into contact. Rotation and weight-setting are features of mechanical-set packers.

Question 11Completion Operations (compulsory)

During a gravel pack operation, the screen is run and the gravel is placed. What is the purpose of the washpipe inside the screen during gravel placement?

  1. To carry the packer setting pressure to the packer
  2. To isolate the screen from the formation during perforating
  3. To increase the collapse rating of the screen
  4. To provide a return path for carrier fluid and allow gravel to be placed across the entire screen interval Correct answer.

Explanation

The washpipe provides a return flow path inside the screen so carrier fluid can circulate back to surface while gravel is deposited in the screen-casing annulus, promoting complete packing across the interval.

Question 12Completion Operations (compulsory)

A sliding side door is to be opened by wireline. What is the correct shifting tool action?

  1. Pump a ball to shear a rupture disc
  2. Run a shifting tool on slickline or wireline, locate the sleeve profile and shift it to the open position Correct answer.
  3. Rotate the tubing string to align the ports
  4. Apply annulus pressure to shear the sleeve

Explanation

Sliding sleeves are opened or closed by a shifting tool that engages the sleeve profile and is moved axially to expose the ports. The operation is normally performed on slickline or wireline.

Question 13Completion Operations (compulsory)

Which perforating method is normally preferred when the completion is already in place and the well is underbalanced, and why?

  1. Wireline casing perforating with the well shut in, because it eliminates the need for underbalance
  2. Casing-gun perforating, because it requires the completion to be pulled first
  3. Tubing-conveyed perforating, because it is the only method that can be run on wireline
  4. Through-tubing perforating, because it can be run without pulling the completion and allows underbalanced cleanup Correct answer.

Explanation

Through-tubing perforating is run on wireline or coiled tubing through the installed completion, so the well does not need to be worked over. Combined with underbalanced conditions, it allows the perforations to clean up and flow.

Question 14Completion Operations (compulsory)

What is the purpose of a polished bore receptacle (PBR) in a completion string?

  1. To provide a precision sealing surface for a stinger so the tubing can move while maintaining a seal Correct answer.
  2. To anchor the tubing string to the casing
  3. To measure the tubing pressure at depth
  4. To provide a circulation port to the annulus

Explanation

A PBR is a honed bore that accepts a stinger with seals, allowing the tubing to move with thermal or pressure changes while maintaining a hydraulic seal. It is commonly used above a packer or liner top.

Question 15Completion Operations (compulsory)

During a completion operation, the well is being killed with completion fluid. Which condition indicates the well is properly killed before the completion is run?

  1. The well is flowing at a stable rate through the choke
  2. The well is static with no flow and the fluid column provides sufficient hydrostatic overbalance Correct answer.
  3. The annulus pressure is rising steadily
  4. The tubing pressure is equal to the formation pressure

Explanation

A killed well is static, with no influx or flow, and the hydrostatic pressure of the fluid column exceeds the formation pressure by the designed trip margin. Rising pressures or continued flow indicate the well is not properly killed.

Question 16Completion Operations (compulsory)

Which of the following is a key advantage of a tubing-conveyed perforating (TCP) system over wireline through-tubing perforating?

  1. It allows a large perforating gun to be run with the completion and can be fired underbalanced with immediate flow Correct answer.
  2. It eliminates the need for a packer in the completion
  3. It can be run without any surface pressure control equipment
  4. It can only be used in open-hole completions

Explanation

TCP systems allow large guns to be run on the tubing string and fired with the well underbalanced, enabling immediate cleanup and flow. They are commonly used in cased-hole completions with a packer and firing head.

Question 17Completion Operations (compulsory)

A completion string includes a landing nipple. What is its purpose?

  1. To provide a machined profile for locating and locking wireline tools such as plugs and gauges Correct answer.
  2. To anchor the packer to the casing
  3. To provide a seal for the tubing hanger
  4. To allow the tubing to be rotated during setting

Explanation

A landing nipple has an internal profile that accepts and locks wireline tools such as plugs, chokes and pressure gauges at a known depth. It gives a defined location for interventions.

Question 18Completion Operations (compulsory)

What is the main purpose of a chemical injection valve in a completion string?

  1. To inject cement for a squeeze job
  2. To inject chemicals such as corrosion inhibitor or scale inhibitor into the produced fluids Correct answer.
  3. To measure the produced fluid density
  4. To provide a backup path for well control

Explanation

A chemical injection valve provides a controlled injection point for chemicals such as corrosion or scale inhibitors into the production stream. It is not a cementing or measurement device.

Question 19Completion Operations (compulsory)

In a subsea completion, which component provides the interface between the tubing hanger and the subsea tree?

  1. The packer and the screen
  2. The sliding sleeve and the landing nipple
  3. The perforating gun and the firing head
  4. The tubing head spool and the subsea tree connector Correct answer.

Explanation

The subsea tree connects to the tubing head spool or wellhead, and the tubing hanger lands in the wellhead or spool. The tree connector provides the pressure-containing interface between the tree and the wellhead.

Question 20Completion Operations (compulsory)

A well is completed with a gravel pack and a screen. After gravel placement, what is the purpose of the acid or breaker treatment sometimes pumped before bringing the well on?

  1. To remove filter cake and gravel-pack damage and improve connectivity to the formation Correct answer.
  2. To permanently cement the gravel in place
  3. To set the packer after gravel placement
  4. To increase the collapse strength of the screen

Explanation

A breaker or acid treatment is used to remove filter cake and near-wellbore damage so the well can clean up and produce at its potential. It does not cement the gravel or set the packer.

Question 21Completion Operations (compulsory)

Which statement best describes the role of a downhole gauge in a completion?

  1. It controls the flow rate to the surface
  2. It provides a barrier against formation pressure
  3. It anchors the tubing string to the casing
  4. It measures pressure and temperature at depth for reservoir and well performance monitoring Correct answer.

Explanation

Downhole gauges record pressure and temperature at depth, providing data for reservoir monitoring, well performance and integrity assessment. They are measurement devices, not barriers or flow controls.

Question 22Completion Operations (compulsory)

A completion is being designed for a well with high sand production and a need for zonal isolation. Which combination of components is most appropriate?

  1. Barefoot open hole with no sand control
  2. Slotted liner with no packer and no gravel
  3. Casing and cement only with no perforations
  4. Gravel pack with screens and isolation packers between zones Correct answer.

Explanation

A gravel pack with screens controls sand production, and isolation packers between zones provide zonal isolation. This combination addresses both the sand and isolation requirements.

Question 23Completion Operations (compulsory)

During a completion operation, the tubing is being run and the well is being kept full. Which practice best maintains well control while running the completion?

  1. Leave the BOP open to allow the annulus to vent during running
  2. Fill the tubing and annulus as the string is run and monitor the trip tank for volume changes Correct answer.
  3. Pump the completion fluid into the formation to reduce the hydrostatic head
  4. Allow the fluid level to fall as the string is run and check it at the end

Explanation

Keeping the well full and monitoring the trip tank for volume changes provides early warning of influx or losses while running the completion. Allowing the level to fall or venting the annulus reduces hydrostatic pressure and well control margin.

Question 24Completion Operations (compulsory)

Which factor most directly determines the required setting depth and elastomer selection for a production packer in a high-temperature well?

  1. The length of the washpipe
  2. The colour of the tubing hanger
  3. The type of perforating charge used
  4. The downhole temperature and the differential pressure across the packer Correct answer.

Explanation

Packer elastomer selection and setting depth are governed by the downhole temperature and the differential pressure the packer must hold. These determine the material rating and the mechanical design of the packer.

Question 25Completion Operations (compulsory)

A sliding side door fails to shift open on the first wireline attempt. Which is the most appropriate next action before deciding to pull the completion?

  1. Rotate the tubing string to shear the sleeve
  2. Pump cement to isolate the sleeve permanently
  3. Confirm the shifting tool is engaging the correct profile and check for debris or scale, then reattempt with the correct tool Correct answer.
  4. Increase the wellhead pressure to force the sleeve open

Explanation

Before pulling the completion, the cause should be investigated: confirm the tool matches the sleeve profile and check for debris or scale that may prevent shifting. Reattempting with the correct tool is the appropriate next step.

Question 26Completion Operations (compulsory)

In a cased-hole completion, what is the primary purpose of a cement bond log run before perforating?

  1. To evaluate the quality of the cement sheath and its hydraulic bond to casing and formation Correct answer.
  2. To confirm the casing wall thickness and detect internal corrosion
  3. To determine the formation fracture gradient at the perforation depth
  4. To measure formation porosity and fluid saturation behind the casing

Explanation

A cement bond log uses acoustic measurements to assess how well the cement is bonded to both the casing and the formation, indicating whether hydraulic isolation exists behind pipe. Good bonding supports the decision to perforate, because poor bonding can allow unwanted fluid communication between zones. It is not a porosity, corrosion, or fracture-gradient measurement.

Question 27Completion Operations (compulsory)

A completion is to be run in a well where the reservoir pressure is significantly below hydrostatic. Which completion fluid selection best protects the formation during running?

  1. A solids-laden mud weighted to balance the highest exposed zone
  2. A viscous polymer pill weighted well above pore pressure to control losses
  3. A clear brine weighted to slightly above reservoir pore pressure
  4. A lightweight fluid, such as a treated brine or diesel, that stays below pore pressure Correct answer.

Explanation

In a depleted or low-pressure reservoir, a fluid whose hydrostatic exceeds pore pressure will leak off into the formation and may cause permanent damage or losses. A lightweight, clean fluid keeps overbalance to a minimum while still providing well control. Solids-laden or over-weighted fluids increase invasion and filter-cake damage.

Question 28Completion Operations (compulsory)

What is the main function of a flow control device installed in a sand screen completion?

  1. To provide a hydraulic setting mechanism for the packer above the screen
  2. To restrict or equalize inflow along the wellbore so water or gas breakthrough is delayed Correct answer.
  3. To mechanically centralize the screen across the perforated interval
  4. To filter formation sand before it reaches the screen wire wrap

Explanation

Inflow control devices add a designed pressure drop at each screen joint so that inflow is distributed more evenly along the interval. This restricts high-permeability segments and helps delay early water or gas coning. Sand filtration is the screen's job, and centralization and packer setting are separate functions.

Question 29Completion Operations (compulsory)

A well is completed with a production packer and the annulus above the packer is to be monitored for pressure buildup. Which feature allows this while the packer isolates the producing interval?

  1. A packer with a control line bypass and annulus access port Correct answer.
  2. A packer equipped with an integral safety valve
  3. A packer fitted with a seal bore for a stinger
  4. A packer with a hydraulic setting port left open to the annulus

Explanation

An annulus access port with a control-line bypass lets pressure above the packer be monitored and transmitted while the packer still isolates the producing zone below. This is important for integrity monitoring and for operating annulus-controlled devices. The other features serve setting, safety closure, or stabbing/sealing functions rather than annulus monitoring.

Question 30Completion Operations (compulsory)

Which statement best describes the purpose of a completion string's expansion joint?

  1. It accommodates changes in tubing length caused by thermal expansion and pressure effects Correct answer.
  2. It allows the string to be rotated during running without transmitting torque
  3. It isolates the annulus from the tubing bore during production
  4. It provides a sealed path for electrical control lines past the packer

Explanation

An expansion joint has telescoping seals that absorb length changes in the tubing as temperature and pressure vary during production or injection. Without it, those movements load the packer and connections. It is not a control-line conduit, a torque-decoupling device, or an isolation barrier.

Question 31Completion Operations (compulsory)

A gas well completion uses a subsurface safety valve. Which installation principle is correct for its setting depth?

  1. It is set below the deepest perforation to protect the entire reservoir interval
  2. It is set immediately below the tubing hanger to minimize response time
  3. It is set as deep as possible to maximize the protected tubing volume
  4. It is set at a depth where the valve can still be set and controlled from surface, typically below the mudline in subsea wells Correct answer.

Explanation

A subsurface safety valve must be positioned deep enough to protect the well but shallow enough that it can still be reliably set and controlled, and in subsea wells it is placed below the mudline. Regulatory and operational requirements usually govern the exact depth. Setting it at the perforations or right under the hanger does not meet these design principles.

Question 32Completion Operations (compulsory)

During a completion, a wireline run is planned to set a plug in a landing nipple. Which nipple feature ensures the plug locates at the correct depth and is held against upward movement?

  1. A flow tube and a flapper
  2. A no-go shoulder and a locking profile Correct answer.
  3. A polished bore and a seal stack
  4. A shear pin and a setting ball

Explanation

Landing nipples contain a locking profile that accepts the matching keys of the plug or tool, and a no-go shoulder that stops the tool at the correct depth. Together they locate and anchor the device. Polished bores seal, flow tubes and flappers belong to safety valves, and shear pins and balls are setting mechanisms.

Question 33Completion Operations (compulsory)

A completion is being designed for a well that will be hydraulically fractured through the production tubing after installation. Which completion feature most directly protects the packer and casing during the treatment?

  1. A sliding side door in the tubing above the packer
  2. A large-bore packer with a high differential rating and a fracture port below it Correct answer.
  3. A downhole gauge carrier below the packer
  4. A polished bore receptacle above the packer

Explanation

Fracturing through the completion imposes high pressure and rate, so the packer must be rated for the differential and the treatment must be directed below it through a fracture port. This isolates the casing annulus from the treating pressure. A PBR, sliding door, or gauge carrier does not provide this pressure protection.

Question 34Completion Operations (compulsory)

Which practice best maintains well control while pulling out of hole with the completion string during a completion operation?

  1. Keeping the hole full with completion fluid and monitoring returns and pit gain on each stand Correct answer.
  2. Pulling at maximum speed to reduce exposure time and monitoring pit volume periodically
  3. Waiting to fill the hole until the string is out of the well
  4. Using the trip tank only after the packer is set

Explanation

Keeping the well full as pipe is pulled prevents the hydrostatic pressure from dropping and avoids swabbing influx. Monitoring returns and pit gain on each stand gives early warning of a kick. Deferring fill or relying on periodic checks leaves the well underbalanced and unsafe.

Question 35Completion Equipment (compulsory)

In a completion string, what is the primary function of a production packer?

  1. To measure annular pressure during production logging
  2. To isolate the annulus from the tubing bore and anchor the string Correct answer.
  3. To filter formation sand before it enters the tubing
  4. To centralize the casing during cementing operations

Explanation

A production packer seals the annulus between tubing and casing and anchors the completion string, which lets produced fluids be controlled and protects the casing from pressure and corrosive wellbore fluids. It is a sealing and anchoring device, not a measurement, cementing, or sand-control tool.

Question 36Completion Equipment (compulsory)

Which component is run directly below a packer to provide a positive mechanical lock and hold the packer in its set position?

  1. Tubing drain valve
  2. Sliding side door
  3. Anchor or hold-down slip assembly Correct answer.
  4. Circulating sub

Explanation

Hold-down or anchor slips bite into the casing wall and resist axial loads, keeping the packer set against pressure-induced forces. Sliding sleeves, drain valves, and circulating subs serve flow-control or circulation functions rather than anchoring.

Question 37Completion Equipment (compulsory)

What is the purpose of a sliding side door (SSD) in a completion string?

  1. To provide a selective flow path between tubing and annulus when shifted Correct answer.
  2. To measure tubing movement due to thermal effects
  3. To cut and retrieve tubing during workover
  4. To permanently seal the annulus after the packer is set

Explanation

A sliding side door is a sleeve that can be shifted open or closed with a wireline or coiled tubing tool to establish or isolate communication between the tubing bore and the annulus. It is a selective flow-control device, not a permanent seal or measurement tool.

Question 38Completion Equipment (compulsory)

Which downhole device is installed to allow the tubing to move axially while maintaining a seal, compensating for thermal expansion during production?

  1. Landing nipple
  2. Tubing expansion joint Correct answer.
  3. Blast joint
  4. Seal bore extension

Explanation

A tubing expansion joint uses a polished bore and seals to permit axial movement of the tubing while keeping the pressure seal, absorbing thermal growth or contraction. Blast joints resist erosion, landing nipples provide a locating profile, and seal bore extensions provide a sealing surface but do not stroke.

Question 39Completion Equipment (compulsory)

A completion uses a wireline-set retrievable packer. Which statement best describes how it is run and set?

  1. It is run on drill pipe and set by cement displacement
  2. It is run on tubing and set mechanically or hydraulically after the tubing is landed Correct answer.
  3. It is run on coiled tubing and set by a milling tool
  4. It is run on tubing and set by wireline before the tubing is landed

Explanation

A wireline-set retrievable packer is conveyed on the tubing string and then set by a wireline-run setting tool that applies mechanical or hydraulic force, after which the tubing is landed. It is not set before tubing is run, nor by cement or milling.

Question 40Completion Equipment (compulsory)

What does a tubing-retrievable safety valve (TRSCSSV) use to hold the valve open during normal production?

  1. A spring loaded by annulus pressure
  2. A hydraulic control line from surface Correct answer.
  3. A wireline lock mandrel
  4. A rupture disc set to formation pressure

Explanation

A surface-controlled subsurface safety valve is held open by hydraulic pressure applied through a control line from the surface; loss of that pressure causes the valve to close by spring and flow-tube force. A lock mandrel is for wireline-set valves, and rupture discs or annulus springs are not the standard opening mechanism.

Question 41Completion Equipment (compulsory)

Which device is installed opposite perforations to protect the tubing from erosive jetting and sand-laden flow?

  1. Blast joint Correct answer.
  2. Pup joint
  3. Tubing centralizer
  4. Landing nipple

Explanation

A blast joint is a thick-walled, often carbide-coated joint positioned across the perforated interval to resist erosion from high-velocity produced fluids. Pup joints adjust length, centralizers position tubing, and landing nipples provide lock profiles.

Question 42Completion Equipment (compulsory)

What is the main purpose of a landing nipple in a completion string?

  1. To provide a no-go profile where wireline locks and flow-control devices can be installed Correct answer.
  2. To connect tubing sections of different thread types
  3. To anchor the packer against upward forces
  4. To allow the tubing to be rotated during workover

Explanation

A landing nipple has an internal profile and no-go shoulder that locates and locks wireline tools such as plugs, chokes, and safety valves at a known depth. It is not an anchoring, crossover, or rotation device.

Question 43Completion Equipment (compulsory)

A completion requires a gas-tight seal on premium connections in a high-pressure gas well. Which connection characteristic is most important?

  1. An external shoulder for tongs
  2. A metal-to-metal seal at the pin nose Correct answer.
  3. A coarse buttress thread form
  4. A tapered API round thread

Explanation

Premium gas-tight connections rely on a metal-to-metal seal, often at the pin nose, to prevent gas leakage under high pressure. Buttress and API round threads are not gas-tight by themselves, and an external shoulder serves handling, not sealing.

Question 44Completion Equipment (compulsory)

What is the function of a tubing drain valve in a completion string?

  1. To equalize pressure across the packer during setting
  2. To drain cement from the annulus after cementing
  3. To drain produced water from the annulus to surface
  4. To drain trapped fluid from the tubing when the string is pulled Correct answer.

Explanation

A tubing drain valve opens a port to release trapped fluid from the tubing as the string is pulled, reducing hook load and preventing wet trips. It does not drain the annulus, equalize during setting, or remove cement.

Question 45Completion Equipment (compulsory)

Which statement correctly describes a permanent packer compared with a retrievable packer?

  1. A permanent packer cannot anchor against differential pressure
  2. A permanent packer relies on a wireline lock mandrel for sealing
  3. A permanent packer can be released and re-set repeatedly with tubing manipulation
  4. A permanent packer is removed by milling after use Correct answer.

Explanation

A permanent packer is set with slips and a sealing element designed to remain in place; it is generally removed by milling rather than being released and re-run. It does anchor against differential pressure and does not depend on a lock mandrel for sealing.

Question 46Completion Equipment (compulsory)

In a completion design, what does the term 'liner' refer to?

  1. A wireline tool that locks into a landing nipple
  2. A protective sleeve over the tubing threads
  3. A short pup joint used to space out the packer
  4. A casing string that does not extend to surface and is hung from a previous casing string Correct answer.

Explanation

A liner is a casing or screen string that is hung off inside the previous casing and does not reach surface, often using a liner hanger. Pup joints, wireline locks, and thread protectors are unrelated components.

Question 47Completion Equipment (compulsory)

What is the role of a gravel pack in a sand-producing reservoir completion?

  1. To provide a hydraulic control line for the safety valve
  2. To place sized gravel between the screen and formation to restrain sand movement Correct answer.
  3. To seal the annulus above the reservoir with cement
  4. To increase the collapse rating of the production casing

Explanation

A gravel pack fills the annulus between the screen and formation with sized gravel that filters formation sand while allowing fluid flow, controlling sand production. It is not a cement seal, a casing strength feature, or a control line.

Question 48Completion Equipment (compulsory)

Which completion component allows selective communication between the tubing and a specific zone while isolating other zones?

  1. Pup joint at the wellhead
  2. Sliding side door with a packer above and below the zone Correct answer.
  3. Blast joint across the perforations
  4. Tubing drain valve at the bottom of the string

Explanation

A sliding side door positioned between two packers lets operators open communication with one zone while isolating others, supporting selective production or treatment. Blast joints, drain valves, and pup joints do not provide selective zonal communication.

Question 49Completion Equipment (compulsory)

A well is completed with a wireline-retrievable safety valve. How is this valve typically installed and retrieved?

  1. Run and retrieved on wireline and locked into a landing nipple in the tubing Correct answer.
  2. Installed in the casing annulus and controlled by annulus pressure
  3. Installed as part of the tubing string and removed by milling
  4. Run on drill pipe and cemented in place

Explanation

A wireline-retrievable safety valve is run on wireline or slickline and locked into a landing nipple, allowing replacement without pulling the tubing. It is not milled out, cemented, or installed in the annulus.

Question 50Completion Equipment (compulsory)

What is the purpose of a seal assembly in a completion that uses a polished bore receptacle?

  1. To measure the tubing pressure at depth
  2. To provide a dynamic or static seal between the tubing and the polished bore while allowing stabbing Correct answer.
  3. To centralize the packer in the casing
  4. To anchor the tubing against upward force

Explanation

A seal assembly with elastomer or non-elastomer seals engages a polished bore receptacle to isolate pressure while permitting stabbing and some movement. Anchoring, centralizing, and pressure measurement are performed by other components.