This article describes the standards applicable for Well Control. General Standards All wells drilled shall comply with the guidelines as specified in API RP 53. All pressure containing well control equipment shall comply with API RP 53 and NACE MR-01-75. The standard shut in procedure to be used in all well control situations is the … Well Control Standards
The pressure at the top of a gas bubble at any point in the annulus while circulating it out using the Driller’s method can be calculated as follows: By calculating the expected annular pressures at the top of the influx at specific points along the wellbore together with the associated influx volumes at these points, … Pressure at the top of a Gas Influx in the Annulus using the “Driller’s Method”
The pressure at the top of a gas bubble at any point in the annulus while circulating it out using the “wait and weight” method can be calculated as follows: By calculating the expected annular pressures at the top of the influx at specific points along the wellbore together with the associated influx volumes at … Pressure at the top of a Gas Influx in the Annulus using the ‘Wait and Weight’ Method
Examples of BOP Configuration for the diferent hole sizes. Hole Size 26in 17.1/2in / 16in 12.1/4 / 8.1/2in 6in Workover Diverter fitted fitted BOP size / rating 13.5/8in 5 000 psi WP 13.5/8in 5 000 psi WP 13.5/8in5 000 psi WP BOP’s top to bottom Annular fitted … Example of BOP Configuration
Procedure and calculation example for Change in Circulating Rate while circulating an influx during a well control incident. 1. Calculate the average mud weight (Wav) in the string at the time pumping is stopped or changed. 2. Calculate shut in drillpipe pressure (PDP) at the time pumping is stopped/changed. 3. Maintain Pchoke constant for the … Procedure and Calculation example for Change in Circulating Rate
When drilling through depleted and/or fractured reservoirs, total losses are a common occurrence. In the worst case, if the well penetrates the top of the formation (fracture) above the gas-oil contact there is a high risk of a blowout if insufficient fluid is not pumped down the annulus at all times between encountering total losses … Total Losses and Requirement for Continuous Fill-Up
While monitoring the drilling parameters and maintaining primary control it is also necessary to prepare in anticipation of an influx and consequent loss of primary control. This involves the pre-recording of the relevant information. 1. General Pre-planning Pre-planning is important to ensure all personnel involved are aware of the action to be taken during well … Primary Control – Planning Considerations
Wireline BOPs are not normally used for open hole logging operations or cased hole operations where the Drilling BOPs are installed. Exceptions to this rule are: Open Hole logging operations (rig on site) where losses or kicks have been encountered during drilling. The Drilling Supervisor and Drilling Engineer shall decide if a 7in shooting nipple … Well Control during Logging Operations
If normal well killing techniques are not possible or will result in critical well control conditions bullheading may be considered whereby mud/influx in displaced/squeezed back into the weakest open hole formation. Bullheading is a critical option of well killing and authorisation to proceed with this method of well killing must generaly be obtained form the … Bullheading
In this method the well is killed in two circulations. In the first circulation the influx is circulated out using the original mud. In the second circulation, when weighted up mud is available, the well is killed. Advantages of the Driller’s Method pumping can begin as soon as drillpipe pressure build-up is established; there is … Well Kill Using The Driller’s Method With The Bit On Bottom