Stability Enhancing of Water-Based Drilling Fluid at High Pressure High Temperature
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RESEARCH ARTICLE-PETROLEUM ENGINEERING
Stability Enhancing of Water-Based Drilling Fluid at High Pressure High Temperature Salem Basfar1 · Ashraf Ahmed1 · Salaheldin Elkatatny1 Received: 29 February 2020 / Accepted: 11 November 2020 © King Fahd University of Petroleum & Minerals 2020
Abstract Over the years, barite (BaSO4 ) as weighting agent was widely used. However, it has an issue with particles settling which is known as barite sagging, that causes a variation in drilling fluid properties and operational problems. This study introduces and investigates a novel combination of Micromax (Mn3 O4 ) and barite weighting materials to prevent the barite sagging in water-based mud under high pressure high temperature (HPHT) situations. Different amounts of Micromax, 0, 25 and 50 wt% from the total weighting material were added to the field formula. Static and dynamic sagging tests were conducted at 250 °F and 120 °F, respectively, to study the sagging tendency and identify the optimum combination. The mud pH and density were measured at ambient conditions. The rheological properties measurements were conducted at 120 °F and 250 °F. The filtration properties were evaluated using HPHT filtration test at 300 psi and 250 °F. The results showed that adding 25/75 wt% Micromax/barite is enough to eliminate the sag issue in both vertical and 45° inclined position, as it enforced the sagging tendency to the safe range. The 25/75 wt% Micromax/barite has no significant effect on the rheological properties compared to the 100 wt% barite, except for the 30 min gel strength which was increased by 19% for better particles suspension while no circulation. The HPHT filtration test indicated a significant decrease in the filter cake thickness and weight with the 25/75 wt% Micromax/barite without significant change in the filtration volume compared to the 100 wt% barite. Keywords Barite sagging · Stability · Micromax · Water-based drilling fluids · High pressure high temperature
1 Introduction Drilling fluids have a crucial continued role in drilling a successful well and designed to perform a variety of important functions at once. The most common drilling fluids types are the water-based and oil-based [1, 2]. The oil-based mud (OBM) has several advantages over the water-based mud (WBM), such as the excellent lubrication, leak off reduction, stabilization of clay or water sensitive, thinner filter cake and better sustainability at the harsh conditions in the high pressure and high temperature reservoirs [2–5]. The
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Salaheldin Elkatatny [email protected] Salem Basfar [email protected] Ashraf Ahmed [email protected]
1
Department of Petroleum Engineering, College of Petroleum Engineering and Geosciences, King Fahd University of Petroleum and Minerals, Dhahran 31261, Saudi Arabia
invert emulsion drilling fluids (IEF), which consists of small droplet of water as internal discontinues phase inside the continuous oil phase [6], is mostly used among the oil-based mud because of its properties [3–5, 7]. In contrast, ther
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