Gas Solubility in Synthetic Fluids: A Well Control Issue

Silva, C.T.; Mariolani, José Ricardo Lenzi; Bonet, E.J.; Lomba, R.F.T.; Santos, Otto; Ribeiro, Paulo Leonardo Lima

doi:10.2118/91009-ms

Cited by 19 publications

(7 citation statements)

References 8 publications

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“…Ribeiro et al (2006) and Silva et al (2004) measured the methane dissolution in synthetic liquids and developed a model for solubility of methane in them. Carroll et al (2009) measured the solubility of methane in aqueous solutions of monoethanolamine, diethanolamine, and triethanolamine from 25 ı to 125 ı C and pressures up to about 13 MPa.…”

Section: Introductionmentioning

confidence: 99%

The Effect of Multi-walled Carbon Nanotubes on Solubility of Methane in Water

Mohammadi

Manteghian

Hoseini-Nasab

et al. 2013

Petroleum Science and Technology

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In this research, the effects of multi-walled carbon nanotubes (NTs) on dissolution of methane in water have been investigated. The tests were performed in a 370 CC vessel at pressures 3 and 5 bar and temperatures of 1-5 ı C. The solution volume was 300 CC. For any solution data of vessel pressure versus time and the total absorption capacity were collected. NTs were dispersed in water by using the sodium dodecyl sulfate (SDS) solution with a concentration of 1 wt% and applying ultrasonic agitation for 25 min. Utilization of 0.1 wt% SDS at a pressure of 3 bar reduced the dissolution capacity, while at the pressure of 5 bar a negligible increase was observed. Dissolution capacity increased up to 5.26% by using of NT along with SDS at the pressure of 5 bar and low temperatures. Utilization of SDS, NT, and their mixtures improved the pressure reduction slope of methane at low temperatures.

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Section: Introductionmentioning

confidence: 99%

The Effect of Multi-walled Carbon Nanotubes on Solubility of Methane in Water

Mohammadi

Manteghian

Hoseini-Nasab

et al. 2013

Petroleum Science and Technology

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“…The authors also proposed a methodology for pit-gain calculation and showed that it could be 80% less for an OBM. Silva et al (2004) studied mixtures of methane/n-paraffin and methane/ester at two temperatures (160 and 190°F) for pressures up to 7,500 psi. The results showed a small influence of the temperature on the PVT properties, for the range of temperatures and pressures of the experiments.…”

Section: Introductionmentioning

confidence: 99%

Study of the PVT Properties of Gas—Synthetic-Drilling-Fluid Mixtures Applied to Well Control

Monteiro

Ribeiro

Lomba

2009

SPE Drilling &Amp; Completion

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The study of the interaction between the formation gas and the drilling fluid during offshore operations as well as in high-pressure/high-temperature environments is essential to drill the pay zone of the well safely and economically. The environmental regulatory issues and the peculiar technical aspects involved in deep and ultradeep waters require low-toxicity synthetic drilling fluids. The main objective of this study was to understand the pressure/ volume/temperature (PVT) behavior of those fluids by the experimental determination and modeling of properties such as solubility, specific gravity, and formation volume factor of the fluid. Those properties have a direct impact on kick detection and circulation out of the well and should be addressed in well-control planning and execution. The experimental work was conducted in a PVT laboratory, using mixtures of methane and n-paraffin-based emulsions as unweighted drilling fluids, tested at temperatures of 158, 194, and 302°F. The pressure, temperature, and fluid-composition effects on those gas/liquid mixture properties were analyzed, and the experimental data for solubility and formation volume factor were compared to predictions considering the additivity hypothesis and mathematical fittings based on the experimental data. A model for the methane/n-paraffin system based on literature data and the Peng-Robinson equation of state has also been fitted to the data to discuss the application of the additivity hypothesis for the emulsions. Pit gain evaluation based on the correlated experimental data for the synthetic drilling fluid has been performed and compared to the values expected for water-based muds (WBMs).

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“…Several degrees of gas solubility in OBM and their impact on influx behavior were studied. Typically, it is hard to define the exact solubility value as many factors are affecting gas solubility in OBM such as pressure, temperature, gas gravity, solid content, and water/oil ratio (Silva et al, 2004;Ribeiro et al, 2006;Monteiro et al, 2010). In all cases, the surface pit gain was kept constant at 20 bbls, while the downhole volume changed according to the degree of solubility.…”

Section: Impact Of the Degree Of Gas Solubility In Oil Based Mudmentioning

confidence: 99%

“…N-paraffin compared to ester based fluids showed higher solubility and formation volume factor accompanied by lower bubble point pressure. Therefore, in n-paraffin based mud, gas kick detection is harder than in ester based fluids (Silva et al, 2004). Ribeiro et al (2006) extended this work for deep water drilling.…”

mentioning

confidence: 99%

“…The facts that gas diffusion deteriorates the mud properties and that the gas ratio increases regardless of the overbalance pressure are alarming and should be carefully considered (Bradley et al, 2002). Silva et al (2004) experimentally studied methane-liquid thermo-dynamical properties. This included bubble point pressure, solubility, density, and formation volume factor at temperatures of 158 and 194 o F.…”

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confidence: 99%

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Hydraulics and Well Control Complications in Unconventional Shale Laterals

Elshehabi¹

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Unconventional shale resources are drilled horizontally following the geologic bed dip upward or downward to maximize reservoir contact. Despite the efforts to control formation pressures, well control emergencies arise. Wellbore communication with high pressure zones through natural or induced fractures is a major cause of blowouts in unconventional shales. The philosophy of well control is to maintain the bottomhole pressure while balancing the formation pressure; however, it is a challenging process. The objective of this study is to investigate mud hydraulics and well control complications in unconventional shale laterals. This included the impact of wellbore configuration (inclined upward or downward laterals), drilling fluid type (water or oil based mud), and drillstring configuration (drillpipe, casing, or liner). This research employed an interactive drilling and well control full-scale simulator for more than 500 hours of real-time operations. It also utilized a robust steady-state hydraulics and multiphase dynamic well control program. A hydraulics base model was developed and verified with field data from a recently drilled Marcellus Shale well in Monongalia County, WV. In inclined upward laterals, gas bubbles migrated and accumulated at the lateral end. Consequently, the choke experienced lower pressure, volume, and gas discharge rate for extended periods of time. Thus, higher circulation rates and longer operation times were essential to flush-out the dispersed and trapped gas bubbles. The deeper and over-pressurized Utica Shale presents more challenges compared to Marcellus Shale wells. Well integrity was verified by monitoring surface choke, casing shoe, and bottomhole pressures throughout the entire well control operations. This research revealed that it is crucial to identify accurate hydraulics and well control complications for unconventional shale laterals. Some examples were drilling inclined upward and downward laterals using different string and fluid configurations. This improves rig and personnel safety and diminishes the environmental risks and hazards associated with blowouts.

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Gas Solubility in Synthetic Fluids: A Well Control Issue

Cited by 19 publications

References 8 publications

The Effect of Multi-walled Carbon Nanotubes on Solubility of Methane in Water

The Effect of Multi-walled Carbon Nanotubes on Solubility of Methane in Water

Study of the PVT Properties of Gas—Synthetic-Drilling-Fluid Mixtures Applied to Well Control

Hydraulics and Well Control Complications in Unconventional Shale Laterals

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