A comprehensive review of solid particle erosion modeling for oil and gas wells and pipelines applications

A casing sensor and methods for sensing using a casing sensor are disclosed. The casing sensor includes a casing shoe and a sensor coupled to the casing shoe. A casing data relay includes a downhole receiver coupled to a well casing and a transmitter coupled to the receiver. The casing sensor may be coupled to the transmitter. A drill string actuator may be controllable through the downhole receiver.

Casing mounted sensors, actuators and generators

In one embodiment, a method for drilling a wellbore includes an act of drilling the wellbore by injecting drilling fluid through a tubular string disposed in the wellbore, the tubular string comprising a drill bit disposed on a bottom thereof. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The drilling fluid and cuttings (returns) flow to a surface of the wellbore via an annulus defined by an outer surface of the tubular string and an inner surface of the wellbore. The method further includes an act performed while drilling the wellbore of measuring a first annulus pressure (FAP) using a pressure sensor attached to a casing string hung from a wellhead of the wellbore. The method further includes an act performed while drilling the wellbore of controlling a second annulus pressure (SAP) exerted on a formation exposed to the annulus.

Annulus pressure control drilling systems and methods

http://www.123seminarsonly.com/Seminar-Reports/2013-04/52623239-Tribology.pdf

Solid particle erosion wear characteristics of fiber and particulate filled polymer composites: A review

We collected all of the published data we could find on the rise velocity of long gas bubbles in stagnant fluids contained in circular tubes. Data from 255 experiments from the literature and seven new experiments at PDVSA Intevep for fluids with viscosities ranging from 1 mPa s up to 3900 mPa s were assembled on spread sheets and processed in log–log plots of the normalized rise velocity, $\hbox{\it Fr} \,{=}\,U/(gD)^{1/2}$ Froude velocity vs. buoyancy Reynolds number, $R\,{=}\,(D^{3}g (\rho_{l}-\rho_{g}) \rho_{l})^{1/2}/\mu $ for fixed ranges of the Eotvos number, $\hbox{\it Eo}\,{=}\,g\rho_{l}D^{2}/\sigma $ where $D$ is the pipe diameter, $\rho_{l}$ , $\rho_{g}$ and $\sigma$ are densities and surface tension. The plots give rise to power laws in $Eo$ ; the composition of these separate power laws emerge as bi-power laws for two separate flow regions for large and small buoyancy Reynolds. For large $R$ ( $>200$ ) we find
 \[\hbox{\it Fr} = {0.34}/(1+3805/\hbox{\it Eo}^{3.06})^{0.58}.\] For small $R$ ( $ ) we find
 \[ \hbox{\it Fr} = \frac{9.494\times 10^{-3}}{({1+{6197}/\hbox{\it Eo}^{2.561}})^{0.5793}}R^{1.026}.\] The flat region for high buoyancy Reynolds number and sloped region for low buoyancy Reynolds number is separated by a transition region ( $10\,{ ) which we describe by fitting the data to a logistic dose curve. Repeated application of logistic dose curves leads to a composition of rational fractions of rational fractions of power laws. This leads to the following universal correlation:
 \[ \hbox{\it Fr} = L[{R;A,B,C,G}] \equiv \frac{A}{({1+({{R}/{B}})^C})^G} \] where
 \[ A = L[\hbox{\it Eo};a,b,c,d],\quad B = L[\hbox{\it Eo};e,f,g,h],\quad C = L[\hbox{\it Eo};i,j,k,l],\quad G = m/C \] and the parameters ( $a, b,\ldots,l$ ) are
 \begin{eqnarray*} &&\hspace*{-5pt}a \hspace*{-0.8pt}\,{=}\,\hspace*{-0.8pt} 0.34;\quad b\hspace*{-0.8pt} \,{=}\,\hspace*{-0.8pt} 14.793;\quad c\hspace*{-0.8pt} \,{=}\,\hspace*{-0.6pt}{-}3.06;\quad d\hspace*{-0.6pt} \,{=}\, \hspace*{-0.6pt}0.58;\quad e\hspace*{-0.6pt} \,{=}\,\hspace*{-0.6pt} 31.08;\quad f\hspace*{-0.6pt} \,{=}\, \hspace*{-0.6pt}29.868;\quad g\hspace*{-0.6pt}\,{ =}\,\hspace*{-0.6pt}{ -}1.96;\\ &&\hspace*{-5pt}h = -0.49;\quad i = -1.45;\quad j = 24.867;\quad k = -9.93;\quad l = -0.094;\quad m = -1.0295.\end{eqnarray*} The literature on this subject is reviewed together with a summary of previous methods of prediction. New data and photographs collected at PDVSA-Intevep on the rise of Taylor bubbles is presented.

Universal correlation for the rise velocity of long gas bubbles in round pipes

An apparatus for controlling a subsea borehole fluid pressure is proposed for use with a conductor casing (110) positioned below the mudline (57) and within a normal pore pressure environment. The apparatus includes a pump (53) for moving a fluid through a tubular into a borehole. The fluid, before being pumped, exerts a pressure less than the pore pressure of an abnormal pore pressure environment (10). The fluid in the borehole is then pressurized by the pump (53) to at least a borehole pressure equal to or greater than the pore pressure of an abnormal pore pressure environment (10). A pressure housing assembly (15) allows for the drilling of a borehole below the conductor casing (110) into an abnormal pore pressure environment (53) while maintaining the pressurized fluid between a borehole pressure equal to or greater than the pore pressure of the abnormal pore pressure environment (10), and below the fracture pressure of the abnormal pore pressure environment (10).

Method and apparatus for drilling a borehole into a subsea abnormal pore pressure environment

Experimental Study of Erosion in Diverter Systems Due to Sand Production

Sustained Casing Pressure in Offshore Producing Wells

Factors Affecting Bubble-Rise Velocity Of Gas Kicks

Gas contamination of an oil-base drilling fluid during drilling operations, whether it be by the uncontrolled flow of formation gas into the well bore (gas kick) or by the drilling of gas bearing formations (drilled gas), poses a potential hazard to the drilling equipment, environment, and personnel. This danger is the greatest when bottom hole conditions are such that the gas will completely dissolve into the drilling fluid and rapidly evolve as the gas cut drilling fluid is circulated up the well. Before this phenomenon can be well understood and modelled, the solubility of natural gases in a wide variety of oil-base drilling fluids must be known as a function of temperature and pressure. Previous authors have presented experimental work on the solubility of methane in diesel oil, and a limited amount of experimental data has also been presented on the solubility of methane in an unweighted diesel oil drilling fluid system. In this study, previous experimental work has been extended to include other base oils (low toxicity systems) and other gases (methane, ethane, carbon dioxide, and a representative natural gas mixture). In addition, the solubility of natural gases in other chemicals used in oil-base drilling fluids were studied. Finally,more » data on the solubility of these gases in oil-base drilling fluids was measured for a wide range of mud densities. A greater temperature range was included in the study than had been done previously for methane in diesel oil and oil-base drilling fluids.« less

Adam T. Bourgoyne

Papers

Method and apparatus for drilling a borehole into a subsea abnormal pore pressure environment

Experimental Study of Erosion in Diverter Systems Due to Sand Production

Sustained Casing Pressure in Offshore Producing Wells

Factors Affecting Bubble-Rise Velocity Of Gas Kicks

An Experimental Study of Gas Solubility in Oil-Based Drilling Fluids