Drilling/completion fluids
This paper presents the application of degradable particulate-diverter technology to improve oil production by effectively diverting stimulation treatment fluids away from high-water-cut, high-permeability, high-temperature producing intervals or zones.
Adequate consideration must be given to the potential effect of each fluid on the successive phase operations to ensure integrated well-fluids system management.
This paper presents the methodology for developing drill-in organophilic clay-free invert-emulsion-fluid technology that enhances well production through fundamental geological studies and fluid testing.
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Nonaqueous drilling fluids have been used extensively by the industry, particularly in complex drilling scenarios. They carry some concerns, however, with implications for well integrity. -
In this study, pressure-while-drilling technologies are combined with software simulations to differentiate drilling-fluid thermal expansion, wellbore ballooning, and formation influx during riserless drilling operations.
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A fluid technology has been developed to deposit a thin, impermeable barrier over the pores and microfractures of weak, underpressured, and otherwise troublesome formations to maintain wellbore stability and reduce formation damage.
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Drilling in high-pressure/high-temperature conditions poses numerous challenges. Drilling fluid is subjected to extreme pressure and temperature, and its properties such as viscosity are affected strongly by pressure and temperature. Viscosity decreases with temperature and increases with pressure.
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The effects of adding iron oxide NPs on the rheological and filtration properties of aqueous bentonite suspensions have been studied by several researchers.
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Researchers have developed a novel water-based-drilling-fluid system compatible with deepwater HP/HT wells in the Lingshui Block on the basis of a conventional drilling fluid and further optimization.
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A supramolecular viscosifier package has been developed that uses noncovalent associations between additives to enhance the thermal resilience of divalent brine fluids.
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Recent studies have found that the viscosities of borate gels at actual downhole pressure conditions may be 80% less than those from standard high-pressure/high-temperature rheometer measurement (which uses 400-psi top pressure).
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This paper examines the chemistry of developing seawater-based fracturing fluids using two types of polymers as gelling agents and compares results to existing fresh-water-based-fracturing-fluid data under different conditions.
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Always recorded but almost never used, the water hammer signal could offer completions engineers another set of insightful data if petroleum engineers can crack its code.
