Abstract
The current research is based on modeling approach, where the objective is to develop a series of computer codes with the reference of existing pressure bleed-off time mathematical models. The results generated from the model are based on the three parameters: temperature, type of gases filled in annulus and depth of well. These three parameters can affect pressure bleed-off time in well's annulus, with the fixed size of needle valve. Using this model generated from Wolfram Mathematical 8.0, it is enable to notify engineer to receive an early sign of warning if the well is suspected to leakage. Meanwhile, based on the matching process of field data and modeled data, field engineers will be able to aware and determine whether the occurrence of annular pressure is due to thermal induced annular pressure buildup or it is because of leakage in well components. The SCP well will eventually loss in production, caused severe failure in well's integrity.
Highlights
Saeby (2011) defines Sustained Casing Pressure (SCP) as an excessive casing pressure in the wells persistently rebuild after bleed-down procedure was conducted
According to PETRONAS Carigali Sdn Bhd‘s Well Risk Management Guideline, it states that SCP is the pressure which results from the well component leak that allows the flow of fluid across the well control barrier, the uncommented formations or damaged cement after setting
According to Bellarby (2009), after the production stops, it is unavoidable that annulus pressure will drop below atmospheric pressure at surface. He claiming that if the annulus was exposed or opened, or the valves are vacuum tight, air can enter the annulus and this can lead to corrosion problem in the Analysis on well’s parameters: The effect of temperature: From Fig. 7, the estimated time in seconds to bleed-off the annular pressure is decreased when the average temperature of well is increased
Summary
Saeby (2011) defines Sustained Casing Pressure (SCP) as an excessive casing pressure in the wells persistently rebuild after bleed-down procedure was conducted. According to PETRONAS Carigali Sdn Bhd‘s Well Risk Management Guideline, it states that SCP is the pressure which results from the well component leak (tubing leak, packer leak or casing leak) that allows the flow of fluid across the well control barrier, the uncommented formations or damaged cement after setting. When the well is experiencing SCP, there is certain potential risk in resulting underground blowout (Bourgoyne et al, 1999). A close monitoring job is mandatory in order to manage SCP effectively since. If operator company failed to manage SCP effectively, there is a potential risk in losing production, on-site pollution and endanger crews’ working safety as well as jeopardizing wellbore integrity. In diagnostic SCP, Bourgoyne et al (1999) were listed out several methods in analyzing SCP which the data can be obtained from Fluid sample analysis, well logging, monitoring fluid levels, pressure testing, pressure bleed-down and build-up performance and Corresponding Author: Darren Wong Vun Nyap, Faculty of Geosciences and Petroleum Engineering, Universiti Teknologi PETRONAS (UTP), Tronoh, Malaysia
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