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Course 903 - Well Site Completion and Servicing Safety

Safety guides and audits to make your job as a safety professional easier

Well Site Completion Safety

site prep

Once the design well depth is reached, the formation must be tested and evaluated to determine whether the well will be completed for production, or plugged and abandoned.

To complete the well production, casing is installed and cemented and the drilling rig is dismantled and moved to the next site.

A service rig is brought in to perforate the production casing and run production tubing. If no further pre-production servicing is needed, the Christmas tree is installed and production begins.

The Christmas tree includes the control valves, pressure gauges, and chokes assembled at the top of a well to control flow of oil and/or gas after the well has been drilled and completed. It is used when reservoir pressure is sufficient to cause reservoir fluids to rise to the surface.

Specifically, well completion activities include:

  • conducting drill stem test
  • setting production casing
  • installing production tubing
  • starting production flow
  • hydraulic fracturing
  • beam pumping units

After production starts, the well may need further servicing.

If it's decided that the well will not be completed, then it will be plugged and abandoned.

excavation

Conducting Drill Stem Test

To determine the potential of a producing formation, the operator may order a drill stem test (DST).

The DST crew makes up the test tool on the bottom of the drill stem, then lowers it to the bottom of the hole.

Weight is applied to the tool to expand a hard rubber sealer called a packer.

Opening the tool ports allows the formation pressure to be tested.

This process enables workers to determine whether the well can be produced.

Let's take a look at the potential hazards and possible solutions when conducting a drill stem test in the next tab.

Conducting Drill Stem Test (Continued)

Potential Hazards:

  • being pinched or struck by the drill stem test tools during floor operations
  • swabbing the hole on the way out with the test tool could cause a kick to occur (could result in a blowout leading to injuries and deaths
  • being exposed to unexpected release of H2S or other gases or liquids
  • a packer seat failure or fluid loss to an upper formation could cause a kick that might result in a blowout causing injuries and deaths
  • other hazards are similar to those encountered during tripping out/in

Possible Solutions:

  • Wear appropriate PPE.
  • Instruct workers in handling and using the special tools required during drill stem testing.
  • Keep a method for filling the hole in place at all times. Before any test starts, the rig management must ensure that the blow-out prevention system includes a kill system that is capable of pumping fluid into the well below the annular preventer and at least on-set of pipe rams.
  • Run a pump-out-sub or downhole circulating device in the test string to enable the system to be reversed.
  • Ensure all workers on the location understand the dangers before starting any drill stem test. They should be fully informed of and trained in appropriate safety procedures, including the use of safety equipment and breathing apparatus.
  • If in an H2S area, post a sign indicating the test in full view for the general public to see. Post reliable people to stop them from coming to the location. Define a minimum of two muster points with all vehicles parked in an appointed area.

Setting Production Casing

casing production

Production casing is the final casing in a well. It can be set from the bottom to the top. Sometimes a production liner is installed.

This casing is set the same as other casings, and then cemented in place.

Installing Production Tubing

A well is usually produced through tubing inserted down the production casing. Oil and gas is produced more effectively through this smaller-diameter tubing than through the large-diameter production casing.

Joints of tubing are joined together with couplings to make up a tubing string. Tubing is run into the well much the same as casing, but tubing is smaller in diameter and is removable.

The steps for this activity are:

  • Tubing elevators are used to lift tubing from the rack to the rig floor.
  • The joint is stabbed into the string, which is suspended in the well, with air slips.
  • Power tongs are used to make-up tubing.
  • This process is repeated until tubing installation is complete.
  • The tubing hanger is installed at the wellhead.

New technology allows tubing to be manufactured in a continuous coil, without joints. Coiled tubing is inserted into the well down the production casing without the need for tongs, slips, or elevators, which takes considerably less time to run.

Let's take a look at the potential hazards and possible solutions when installing production tubing in the next tab.

Installing Production Tubing (Continued)

coil tubing

Potential Hazards:

  • getting pinched fingers and hands from tongs and slips
  • being struck by swinging tubing and tubing elevators
  • getting caught between the joint and tongs or stump
  • being struck by the tubing hanger wrench if it should slip
  • getting fingers and hands pinched and caught between tubing hanger and tubing head

Possible Solutions:

  • Keep all fingers and hands away from pinch points.
  • Instruct workers to be on alert when on the rig floor and pipe racking area.
  • Avoid placing hands on the end of the tubing stump.
  • Use the correct tools for each task.
  • Inspect the tools before use.
  • Use coiled tubing.

Starting Production Flow

production flow

Production flow is started by washing in the well and setting the packer.

  • Washing in means to pump in water or brine to flush out the drilling fluid. Usually this is enough to start the well flowing.

If the well does not start flowing, then the well may need to be unloaded. This means to swab the well to remove some of the brine.

  • A swab is a hollow mandrel fitted with swab cups used for swabbing. The swab operates on a wireline to lower the pressure in the well bore and bring well fluids to the surface when the well does not flow naturally. Swabbing is a temporary operation to determine whether the well can be made to flow. If the well does not flow after being swabbed, a pump is installed as a permanent lifting device to bring the oil to the surface.
  • A wireline is a slender, rodlike or threadlike piece of metal used for lowering special tools into the well.

If this does not work the flow might be started by pumping high-pressure gas into the well before setting the packer.

  • The packer is a piece of downhole equipment that consists of a sealing device, a holding or setting device, and an inside passage for fluids.

Starting Production Flow (Continued)

Potential Hazard:

  • A blowout may be possible whenever well pressures are changed.

Possible Solution:

  • Monitoring of well pressures and working blow out preventers (BOP's) are the best way to prevent blowouts.

If the well does not flow on its own, well stimulation or artificial lift may need to be considered.

  • Stimulation is the action of attempting to improve and enhance a well’s performance by:
    • the application of horsepower using pumping equipment,
    • injecting water, sand and chemicals in artificially created fractures in rock, or
    • using chemicals such as hydrochloric or acetic acid to dissolve the soluble portion of the rock.

Video

Instructions

Before beginning this quiz, we highly recommend you review the module material. This quiz is designed to allow you to self-check your comprehension of the module content, but only focuses on key concepts and ideas.

Read each question carefully. Select the best answer, even if more than one answer seems possible. When done, click on the "Get Quiz Answers" button. If you do not answer all the questions, you will receive an error message.

Good luck!

1. To determine the potential of a producing formation, the operator may order _____.

2. The hazards encountered during a drill stem test(DST)conducted as part of the well completion process include all of the following, except _____.

3. The hazards to which you may be exposed while installing production tubing include all of the following, except _____.

4. Which of the following is the primary hazard encountered when starting the production flow process?

5. Each of the following are well stimulation methods, except _____.


Have a great day!

Important! You will receive an "error" message unless all questions are answered.