Control of Contained-Annulus Fluid Pressure Buildup

Williamson, Roger N.; Sanders, W. W.; Jakabosky, Troy; Serio, Michael; Griffith, James

doi:10.2523/79875-ms

Cited by 9 publications

(6 citation statements)

References 2 publications

Supporting

Mentioning

Contrasting

Unclassified

Order By: Relevance

“…The convective heat transfer coefficient of the annulus fluid (Willhite, 1967;Williamson and Sanders, 2003) is: h c ¼ 0:05ðGrPrÞ 0:33 Pr 0:074 k af r to lnðr ao =r to Þ…”

Section: Convective Heat Transfer Coefficient Of Annulus Fluidmentioning

confidence: 99%

Sealed annulus thermal expansion pressure mechanical calculation method and application among multiple packers in HPHT gas wells

Zhi

Han

2016

Journal of Natural Gas Science and Engineering

View full text Add to dashboard Cite

“…The convective heat transfer coefficient of the annulus fluid (Willhite, 1967;Williamson and Sanders, 2003) is: h c ¼ 0:05ðGrPrÞ 0:33 Pr 0:074 k af r to lnðr ao =r to Þ…”

Section: Convective Heat Transfer Coefficient Of Annulus Fluidmentioning

confidence: 99%

Sealed annulus thermal expansion pressure mechanical calculation method and application among multiple packers in HPHT gas wells

Zhi

Han

2016

Journal of Natural Gas Science and Engineering

View full text Add to dashboard Cite

“…The YPL-WTP software permits the user to input the variables listed at the beginning of the paper to calculate the temperature profiles or the temperature and pressure at the mud line (ML). The software allows appropriate annular fluid design to assist in avoiding lowtemperature-related problems such as hydrates, paraffin deposition, 9 precipitation of salts at high pressure and casing collapse 22,23 in un-vented annuli when multiple casing strings are used. Figure 3 illustrates one of the complex wellbore configurations that can be modeled in the YPL-WTP software.…”

Section: Ypl-wtp Engineering Toolmentioning

confidence: 99%

A New Yield Power Law Analysis Tool Improves Insulating Annular Fluid Design

Horton

Froitland

Foxenberg

et al. 2005

International Petroleum Technology Conference

View full text Add to dashboard Cite

Engineering analysis can help avoid significant problems in deep offshore completions. Because yieldpower-law fluids offer better convective heat-loss control, new algorithms have been developed that allow the modeling of convective heat transfer through such fluids. Special cases-Newtonian, Bingham Plastic, and power law-were also included in this model. This new software permits appropriate annular fluid design to avoid low-temperature-related problems such as hydrates, paraffin deposition, precipitation of salts at high pressure and casing collapse in un-vented annuli when multiple casing strings are used. Yield-power-law fluids have viscosities that increase significantly as shear-strain rates diminish. As control over heat loss due to convection is developed, the shear-rate environment drops and viscosity of the yieldpower-law fluid increases, reducing convective heat loss further. These fluids also tend to have relatively low high-shear-rate viscosity, making them easier to place and displace. This paper explores the use of this novel engineering tool to show how changes in physical properties of the annular fluids, boundary conditions like bottomhole temperature (BHT), and fluids configurations in the wellbore result in changes in the temperature profiles in deep offshore wells-both "dry-tree" and sub-sea completions. These parametric analyses are then used to create practical general guidelines for the selection of annular fluids to meet the performance requirements in deep offshore wells and to avoid the physical and chemical problems that could arise.

show abstract

“…Since the 1980s, scholars all over the world have conducted a great deal of research on the annular pressure in wellbore enclosed space, examined the annular pressure induced by the rise in wellbore temperature, established the related theoretical calculation models (Halal et al, 1994;Hu et al, 2012;Oudeman and Kerem, 2006;Yin and Gao, 2014) and raised some risk mitigation measures in accordance with different well conditions and requirements (Ezell et al, 2010;Sathuvalli et al, 2005;Tahmourpour et al, 2010;Williamson et al, 2003).…”

Section: Introductionmentioning

confidence: 99%

Transient prediction of annular pressure between packers in high-pressure low-permeability wells during high-rate, staged acid jobs

Lee

Rao

Xia

2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

View full text Add to dashboard Cite

For high-pressure low-permeability wells, wellbore temperature drops drastically in high-rate and multistage acid fracturing process. Under the combined action of the swelling of tubing string and the contraction of annular fluid between packers, annular pressure between packers undergoes violent transient change in staged acid jobs, thereby deteriorating loading on the tubing string and packers. Based on the principle of energy conservation and wellbore heat conduction, the transient prediction of two-dimensional (2D) wellbore temperature field under pumping injection condition was established by considering the effects of heat generated by friction and convection heat exchange. Moreover, the effects of wellbore temperature/pressure changes on the annular volume between packers were analyzed. Furthermore, in combination with the transient prediction model of wellbore temperature, PVT state equation of annular fluid, the calculation model of tubing string radial deformation and the transient seepage equation of the formation, the transient prediction model of annular pressure between packers in high-pressure low-permeability wells was established. Finally, by taking a high-pressure low-permeability well as an example, annular pressure between packers was calculated and the forces on the packers and tubing string were analyzed. According to the prediction results, the tubing string, which was regarded to be safe using conventional design method, exhibited an extremely high risk of failure after taking into account the decrease in annular pressure between packers. Therefore, the decrease in annular pressure should be fully considered in the design of tubing string for high-pressure low-permeability wells in multistage acid fracturing process. In combination with sensitivity analysis results, it can be concluded that formation permeability, injection rate and formation pressure all affected the change in annular pressure between packers.

show abstract

Control of Contained-Annulus Fluid Pressure Buildup

Cited by 9 publications

References 2 publications

Sealed annulus thermal expansion pressure mechanical calculation method and application among multiple packers in HPHT gas wells

Sealed annulus thermal expansion pressure mechanical calculation method and application among multiple packers in HPHT gas wells

A New Yield Power Law Analysis Tool Improves Insulating Annular Fluid Design

Transient prediction of annular pressure between packers in high-pressure low-permeability wells during high-rate, staged acid jobs

Contact Info

Product

Resources

About