Development of New Rheology Modifier for Invert Emulsion Drilling Fluids

Low ECD High Performance Invert Emulsion Drilling Fluids: Lab Development and Field Deployment

10.2118/202115-ms ◽

2021 ◽

Author(s):

Vikrant Wagle ◽

Abdullah Yami ◽

Michael Onoriode ◽

Jacques Butcher ◽

Nivika Gupta

Keyword(s):

High Performance ◽

Filter Cake ◽

Drilling Fluid ◽

Field Performance ◽

Superior Performance ◽

Core Material ◽

Drilling Fluids ◽

Invert Emulsion ◽

Field Deployment ◽

Permeability Studies

Abstract The present paper describes the results of the formulation of an acid-soluble low ECD organoclay-free invert emulsion drilling fluid formulated with acid soluble manganese tetroxide and a specially designed bridging package. The paper also presents a short summary of field applications to date. The novel, non-damaging fluid has superior rheology resulting in lower ECD, excellent suspension properties for effective hole cleaning and barite-sag resistance while also reducing the risk of stuck pipe in high over balance applications. 95pcf high performance invert emulsion fluid (HPIEF) was formulated using an engineered bridging package comprising of acid-soluble bridging agents and an acid-soluble weighting agent viz. manganese tetroxide. The paper describes the filtration and rheological properties of the HPIEF after hot rolling at 300oF. Different tests such as contamination testing, sag-factor analysis, high temperature-high pressure rheology measurements and filter-cake breaking studies at 300oF were performed on the HPIEF. The 95pcf fluid was also subjected to particle plugging experiments to determine the invasion characteristics and the non-damaging nature of the fluids. The 95pcf HPIEF exhibited optimal filtration properties at high overbalance conditions. The low PV values and rheological profile support low ECDs while drilling. The static aging tests performed on the 95pcf HPIEF resulted in a sag factor of less than 0.53, qualifying the inherent stability for expected downhole conditions. The HPIEF demonstrated resilience to contamination testing with negligible change in properties. Filter-cake breaking experiments performed using a specially designed breaker fluid system gave high filter-cake breaking efficiency. Return permeability studies were performed with the HPIEF against synthetic core material, results of which confirmed the non-damaging design of the fluid. The paper thus demonstrates the superior performance of the HPIEF in achieving the desired lab and field performance.

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A selection of emulsifiers for preparation of invert emulsion drilling fluids

Topical Issues of Rational Use of Natural Resources 2019 ◽

10.1201/9781003014638-2 ◽

2019 ◽

pp. 487-494

Author(s):

S.R. Islamov ◽

A.V. Bondarenko ◽

D.V. Mardashov

Keyword(s):

Drilling Fluids ◽

Invert Emulsion ◽

Selection Of

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Experimental Investigation of the Rheological Behavior of an Oil-Based Drilling Fluid with Rheology Modifier and Oil Wetter Additives

Molecules ◽

10.3390/molecules26164877 ◽

2021 ◽

Vol 26 (16) ◽

pp. 4877

Author(s):

Mobeen Murtaza ◽

Sulaiman A. Alarifi ◽

Muhammad Shahzad Kamal ◽

Sagheer A. Onaizi ◽

Mohammed Al-Ajmi ◽

...

Keyword(s):

High Temperature ◽

Zeta Potential ◽

Hot Rolling ◽

Emulsion Stability ◽

Drilling Fluid ◽

Temperature Tolerance ◽

Fluid Loss ◽

Drilling Fluids ◽

Before And After ◽

Rheology Modifier

Drilling issues such as shale hydration, high-temperature tolerance, torque and drag are often resolved by applying an appropriate drilling fluid formulation. Oil-based drilling fluid (OBDF) formulations are usually composed of emulsifiers, lime, brine, viscosifier, fluid loss controller and weighting agent. These additives sometimes outperform in extended exposure to high pressure high temperature (HPHT) conditions encountered in deep wells, resulting in weighting material segregation, high fluid loss, poor rheology and poor emulsion stability. In this study, two additives, oil wetter and rheology modifier were incorporated into the OBDF and their performance was investigated by conducting rheology, fluid loss, zeta potential and emulsion stability tests before and after hot rolling at 16 h and 32 h. Extending the hot rolling period beyond what is commonly used in this type of experiment is necessary to ensure the fluid’s stability. It was found that HPHT hot rolling affected the properties of drilling fluids by decreasing the rheology parameters and emulsion stability with the increase in the hot rolling time to 32 h. Also, the fluid loss additive’s performance degraded as rolling temperature and time increased. Adding oil wetter and rheology modifier additives resulted in a slight loss of rheological profile after 32 h and maintained flat rheology profile. The emulsion stability was slightly decreased and stayed close to the recommended value (400 V). The fluid loss was controlled by optimizing the concentration of fluid loss additive and oil wetter. The presence of oil wetter improved the carrying capacity of drilling fluids and prevented the barite sag problem. The zeta potential test confirmed that the oil wetter converted the surface of barite from water to oil and improved its dispersion in the oil.

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A novel star-shaped copolymer as a rheology modifier in water-based drilling fluids

Journal of Petroleum Science and Engineering ◽

10.1016/j.petrol.2018.05.003 ◽

2018 ◽

Vol 168 ◽

pp. 98-106 ◽

Cited By ~ 14

Author(s):

Zhihua Luo ◽

Longxiang Wang ◽

Jingjing Pei ◽

Peizhi Yu ◽

Boru Xia

Keyword(s):

Drilling Fluids ◽

Water Based ◽

Rheology Modifier

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Sagging Prevention for Hematite-Based Invert Emulsion Mud

Journal of Energy Resources Technology ◽

10.1115/1.4052181 ◽

2021 ◽

pp. 1-19

Author(s):

Ashraf Ahmed ◽

Salem Basfer ◽

Salaheldin Elkatatny

Keyword(s):

Laboratory Experiments ◽

Filter Cake ◽

Emulsion Stability ◽

Gel Strength ◽

Drilling Fluids ◽

Drilling Mud ◽

High Pressure High Temperature ◽

Solids Suspension ◽

Invert Emulsion ◽

Drilling Cost

Abstract The solids sagging in high-pressure high-temperature (HP/HT) reservoirs is a common challenge associated with hematite drilling fluids. This study provides a solution to hematite sagging in invert emulsion mud for HP/HT wells which involves the combination of Micromax (Mn3O4) with hematite. The particles of both weighting agents were characterized to address their mineralogical features. A Field formulation of the mud was used over a range of Micromax/hematite ratios (0/100, 20/80, and 30/70%) in laboratory experiments to address the sag performance and determine the optimal combination ratio. Then, density, emulsion stability, rheology, viscoelasticity, and filtration performance for the formulated mud were addressed. The tests were conditioned to 500 psi and 350 °F. The acquired results of sag tests indicated that incorporation of 30% Micromax solved the hematite sagging issue and brought the sag tendency within the recommended safe range. An insignificant reduction in mud density was observed upon the inclusion of Micromax, while the emulsion stability was obviously improved from 551 to 614 volts with the 30% Micromax mixture. The recommended 30/70% combination had almost no effect on plastic viscosity and yield point since they were increased by one unit, but the gel strength was improved resulting in flat rheology and better solids suspension capacity. The filtration behavior of the formulation with 30% Micromax was enhanced compared to pure hematite as it resulted in 10 and 14% reduction of the filtrate volume and filter-cake thickness, respectively. This study contributes to improve and economize the drilling cost and time by formulating a stabilized and distinguished-performance drilling mud using combined weighting agents at HP/HT.

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