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What are the best practices for testing well control barriers?

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Well control barriers are essential for preventing and containing blowouts, which are uncontrolled releases of formation fluids that can cause serious damage, injury, or loss of life. Testing well control barriers is a critical part of ensuring their integrity and functionality, as well as complying with regulatory and industry standards. In this article, you will learn about the best practices for testing well control barriers in drilling engineering, covering the types, methods, frequency, and documentation of barrier tests.

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1 Types of barriers

There are two main types of well control barriers: primary and secondary. Primary barriers are the first line of defense against blowouts, and they include the hydrostatic pressure of the drilling fluid, the annular preventer, and the pipe rams. Secondary barriers are the backup systems that activate when the primary barriers fail, and they include the blind or shear rams, the choke and kill lines, and the diverter. Both types of barriers need to be tested regularly and independently to verify their performance and reliability.

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prem sharma

OIM at OIL AND NATURAL GAS CORPORATION
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Hydrostatically overbalanced fluid column, cement plugs, Blowout Preventer Equipment, Bridge Plugs, Casing, Cement behind Casing, Valves, Managed Pressure Drilling Equipment.cement plug has to be tested as per well plan with correct fluid and surface pressure. BOP has to be tested periodically with either test plug or cup tester. with cup tester along with BOP you can test well head valves. fluid column should be of correct sp gr. it is simple but very very important to test all types of barriers as per the procedure. cement behind casing has to be tested for pressure and cement bond also. bridge plugs and packers has to be tested as per pre-prescribed pressure and method.

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2 Methods of testing

The methods of testing well control barriers depend on the type, location, and function of the barrier. For example, the hydrostatic pressure of the drilling fluid can be tested by performing a leak-off test (LOT) or a formation integrity test (FIT), which measure the maximum pressure that the formation can withstand without fracturing. The annular preventer and the pipe rams can be tested by applying a low-pressure test (LPT) and a high-pressure test (HPT) to check for leaks and proper sealing. The blind or shear rams can be tested by closing them on a drill pipe or a test stump and applying a HPT. The choke and kill lines can be tested by circulating fluid through them and monitoring the pressure and flow rate. The diverter can be tested by diverting the flow to a safe location and verifying the valve operation.

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3 Frequency of testing

The frequency of testing well control barriers depends on several factors, such as the well depth, the formation characteristics, the drilling fluid properties, the operational conditions, and the regulatory and industry requirements. Generally, the primary barriers should be tested at least once every 24 hours, or more often if there is a significant change in any of the factors mentioned above. The secondary barriers should be tested at least once every 7 days, or more often if there is a malfunction, repair, or replacement of any component. Additionally, all barriers should be tested before and after each critical operation, such as drilling out a casing shoe, running a casing or a liner, or setting a packer.

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mahmood alabri

Senior Well Integrity Engineer @OQEP Oman | Expert in well intervention and well integrity.
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An example of an operating well, it has different testing frequencies depending on the type of well. The presence of CITHP (Closed-in tubing head pressure) and H2S levels will determine the frequency of testing the barriers. Most operators will have their own matrix for determining testing frequencies.

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4 Documentation of testing

The documentation of testing well control barriers is an important part of demonstrating compliance, accountability, and transparency. The documentation should include the date, time, duration, method, results, and observations of each barrier test, as well as the names and signatures of the personnel involved. The documentation should also include any deviations, anomalies, or corrective actions taken during or after the test. The documentation should be recorded in a standardized format, such as a well control log or a barrier test report, and stored in a secure and accessible location.

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5 Here’s what else to consider

This is a space to share examples, stories, or insights that don’t fit into any of the previous sections. What else would you like to add?

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Wilfredo Honores

Human ingenuity is at both ends of AI | Inspect. Adapt. Transform.
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Train all the operations teams appropriately, so they become custodians of their and their teammates safety. Empower the team with Stop Work Authority, to apply prevention at the first sight of a potential breach to the integrity of assets and environment.

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mahmood alabri

Senior Well Integrity Engineer @OQEP Oman | Expert in well intervention and well integrity.
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Think of the BOP as our first line of defense against blowouts. It's our safety net, consisting of valves and rams that we can activate to seal off the wellbore if pressure surges unexpectedly. Hydrostatic Pressure our invisible shield. The BOP and hydrostatic pressure work hand in hand to ensure well control. We constantly monitor hydrostatic pressure levels to make sure they're adequate for the drilling conditions. If we detect any pressure imbalances, we adjust the mud weight or activate the BOP as needed to maintain control. In case any unexpected blowout been detected there are 2 main methods to kill the well and restore the control of the well. 1.driller method. 2.weight and wait.

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What are the best practices for testing well control barriers?

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5

1 Types of barriers

2 Methods of testing

3 Frequency of testing

4 Documentation of testing

5 Here’s what else to consider

Drilling Engineering

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What are the best practices for testing well control barriers?

1

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1 Types of barriers

2 Methods of testing

3 Frequency of testing

4 Documentation of testing

5 Here’s what else to consider

Drilling Engineering

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