Academic literature on the topic 'Matrix Type Transdermal Patch'

The term control release means the release of the molecules from any reservoir in very precise and constant amounts and following zero-order or near-to-zero-order release kinetics. This type of formulation and device has a huge market over the medical world. The basic foundation of sustained release drug delivery system enhances the biopharmaceutical and pharmacodynamics pharmacokinetic properties of a drug in such a way that its usefulness is exploited, side-effects are reduced, and cure of the disease is attained easily. The international controlled-release drug delivery technology market has been divided on the basis of technology, application, release mechanism, and geography. This chapter describes these topics: metered dose inhalers, transdermal and ocular patches, drug eluting stents, activation-modulated drug delivery systems, polymer coating systems microelectromechanical technology, implants, micro reservoir partition controlled drug delivery systems, hydrophilic polymer matrix systems, targeted delivery, enzyme activated device.

In this chapter, we will discuss Jitter, a set of objects that handles video and visual-related content in Max. Jitter is for handling video what MSP is for handling audio. Adding visual elements to your patch can turn your interactive systems into multimedia ones. By the end of this chapter, you will have created a patch that changes the color of a live video when pitches are played. In this book, we will not cover all the features and options available with Jitter. Instead, we will focus on ways to incorporate video from cameras and existing video footage into our patches. This will address some of the immediate connections between music education and video while providing a broad enough foundation of Jitter concepts and techniques to build on later through the Jitter tutorials and exploration. In the same way that the MSP objects end with ~, the Jitter objects all begin with “jit.” In fact, you already learned one Jitter object in Chapter 9, jit.cellblock; the object that resembled a spreadsheet. A spreadsheet is a type of grid known as a matrix in which each location on the grid, like a spreadsheet cell, contains some (or no) information. When we discussed the mousestate object and the amount of pixels determined by the screen resolution, we were discussing a matrix—a matrix (a grid) that displays a certain number of pixels (like tiny little cells in a spreadsheet that display color). The more pixels that are used to represent an image, the higher the resolution of the image will be, resulting in a clearer appearance. If, for example, you had a photo of the Mona Lisa that only used 12 pixels to represent the immense detail of the painting, your photo would appear less than lifelike, to say the least. Similar to our discussion last chapter about bit depth, the higher the resolution you can work with, the more clarity your image will have, generally.

Analytical solutions to a set of boundary integral equations are rare, even with simple geometries and boundary conditions. To make any reasonable progress, a numerical technique must be used. There are basically four issues that must be discussed in any numerical scheme dealing with integral equations. The first and most basic one is how numerical integration can be effected, together with an effective way of dealing with singular kernels of the type encountered in elastostatics. Numerical integration is usually termed numerical quadrature, meaning mathematical formulae for numerical integration. The second issue is the boundary discretization: when integration over the whole boundary is replaced by a sum of the integrations over the individual patches on the boundary. Each patch would be a finite element, or in our case, a boundary element on the surface. Obviously a high-order integration scheme can be devised for the whole domain, thus eliminating the need for boundary discretization. Such a scheme would be problem dependent and therefore would not be very useful to us. The third issue has to do with the fact that we are constrained by the very nature of the numerical approximation process to search for solutions within a certain subspace of L2, say the space of piecewise constant functions in which the unknowns are considered to be constant over a boundary element. It is the order of this subspace, together with the order and the nature of the interpolation of the geometry, that gives rise to the names of various boundary element schemes. Finally, one is faced with the task of solving a set of linear algebraic equations, which is usually dense (the system matrix is fully populated) and potentially ill-conditioned. A direct solver such as Gauss elimination may be very efficient for small- to medium-sized problems but will become stuck in a large-scale simulation, where the only feasible solution strategy is an iterative method. In fact, iterative solution strategies lead naturally to a parallel algorithm under a suitable parallel computing environment. This chapter will review various issues involved in the practical implementation of the CDL-BIEM on a serial computer and on a distributed computing environment.

Abstract This paper provides in-depth analysis of a low-cost solution to economically sustain production and avoid high workover costs. This paper conducts the technical and economic analysis on the tubing patch technology that promises to avoid rig intervention for tubing repair. This paper will contain the technical application with risks of the available technologies and their economic benefit in completely avoiding rig intervention. It will also focus on the value of right candidate well selection. The six oil producers and water injectors wells selected with potential SAP-A/tubing leak, were inactive but important wells to achieve production target. The identification of candidate wells was the key to success. The investigation of wells included running logs as noise and multi finger caliper to identify exact leak point. Two different methods of permanent tubing patches were tried, one with Wireline and one via coiled tubing. All the wells,well integrity was restored, post installation evaluation was conducted via pressure test and noise log to confirm the success & savings of 30% over period of 5 years BP. Due to the business need to produce more and more hydrocarbons, activating inactive strings riglessly can save considerable amount of capex. Tubing Patch trials were conducted on 6 candidate wells and it lead 20% savings over 5 years BP. The wells with Gas lift Mandrels (GLMs) were the most critical for tubing patches. The key was depth correlation and accuracy of setting the patch. The high risk of having GLMs and chrome material made depth correlation risky. Many options using Casing collar, casing tally and GR/CCl while running the patches were used along with dissolvable plugs were used to ensure the patch is set at the right depth. Each technology posed certain benefits and challenges in terms of operational procedures, inner diameter after expansion restriction, collapse rating and latching mechanism. The best technology would be the one that can provide unrestricted uniform inner diameter with sufficient collapse and burst rating and economically viable to be used. Consequently, the tubing patches were installed riglessly using coiled tubing and wireline which avoided well intervention and saving huge CAPEX of 20% per well in drilling CAPEX and around 20% bbls/oil per day in production restoration. The selection criteria matrix is now a standard format used in Well Integrity management system to select candidate wells for tubing patch technology. Each candidate well were this tubing patch technology was used promised to save huge MM in CAPEX, depending on the type of well and 30 days average in well duration.Multiple wells were restored with tubing patch technology and thus avoided the expensive workover costs. Reduction of Rig mobilization and over cost for SAP A wells due Tubing leakage repair by using a rigless solution called tubing patch depending on different factors that can extend the life cycle of the wells for low cost and optimization for integrity results. Current challenges to integrity issues include non-productive time for wells and operations when carrying out a traditional work over. The new approach is based on wells that have been identified with sustainable annulus pressure in the A annulus (SAP "A") due to tubing leak. Those wells have been evaluated following the industry best practices and the company Code of Practice. The investigation started on identifying the tubing / Annulus integrity with the different procedures of pressure test, If the leak is established, then the use of leak detection logs (LDL) with an e/L unit to identify the exact location of the leak. At the same time a MultiFinger caliper logs (MFC) is the great use to evaluate the condition of the tubing ID, identifying the extension of the corrode section. During the evaluation of the trial found dictate the selection between tubing patch or a straddle solution. For the tubing patch solution, the requirement is to have one (1-2) leak point in the string, For the straddle solution the requirement is to have multiple leak points (to add the appropriate spacer length), be retrievable and allow accessibility and longevity of the well life cycle. The selection of the rigless solutions for issues due to tubing leak will help in reducing rig mobilization costs and non-productive time and reduce well inactivity of the production/injection of the well. The implementation of the tubing patch was evaluated on 3 different wells. Where well 1 as WI well with 2 identify leak points and solution for 2 different patch sections with a positive result on the Annulus pressure test post patch installation. The 2nd well as WI well with 1 identify leak points with a positive result on the Annulus pressure test and LDL post patch installation. The 3rd well as OP/GLM well with 1 identify leak points with a negative result on the LDL post patch installation. As per the badly corrosion levels in the tubing. The observations found during the resolution and application of these solutions, were the level of corrosion as a limiting factor when selecting the availability and suitability of these solutions. 3 Well were used for the development of the trial and just 2 provided positive results, the 3rd well fails. The utilization of these technologies can enhance the operational side to solve the leakage of tubing strings in short time of inactivity, generating revenue and new procedures for barriers evaluation in different type of string and wells. Providing this solution reduces the utilization of rigs and huge cost related for just recomplete the well, instead of the extension of the life cycle.

Abstract This paper provides in-depth analysis of a low-cost solution to economically sustain production and avoid high workover costs. This paper conducts the technical and economic analysis on the tubing patch technology that promises to avoid rig intervention for tubing repair. This paper will contain the technical application with risks of the available technologies and their economic benefit in completely avoiding rig intervention. It will also focus on the value of right candidate well selection. The six oil producers and water injectors wells selected with potential SAP-A/tubing leak, were inactive but important wells to achieve production target. The identification of candidate wells was the key to success. The investigation of wells included running logs as noise and multi finger caliper to identify exact leak point. Two different methods of permanent tubing patches were tried, one with Wireline and one via coiled tubing. All the wells,well integrity was restored, post installation evaluation was conducted via pressure test and noise log to confirm the success & savings of 30% over period of 5 years BP. Due to the business need to produce more and more hydrocarbons, activating inactive strings riglessly can save considerable amount of capex. Tubing Patch trials were conducted on 6 candidate wells and it lead 20% savings over 5 years BP. The wells with Gas lift Mandrels (GLMs) were the most critical for tubing patches. The key was depth correlation and accuracy of setting the patch. The high risk of having GLMs and chrome material made depth correlation risky. Many options using Casing collar, casing tally and GR/CCl while running the patches were used along with dissolvable plugs were used to ensure the patch is set at the right depth. Each technology posed certain benefits and challenges in terms of operational procedures, inner diameter after expansion restriction, collapse rating and latching mechanism. The best technology would be the one that can provide unrestricted uniform inner diameter with sufficient collapse and burst rating and economically viable to be used. Consequently, the tubing patches were installed riglessly using coiled tubing and wireline which avoided well intervention and saving huge CAPEX of 20% per well in drilling CAPEX and around 20% bbls/oil per day in production restoration. The selection criteria matrix is now a standard format used in Well Integrity management system to select candidate wells for tubing patch technology. Each candidate well were this tubing patch technology was used promised to save huge MM in CAPEX, depending on the type of well and 30 days average in well duration.Multiple wells were restored with tubing patch technology and thus avoided the expensive workover costs. Reduction of Rig mobilization and over cost for SAP A wells due Tubing leakage repair by using a rigless solution called tubing patch depending on different factors that can extend the life cycle of the wells for low cost and optimization for integrity results. Current challenges to integrity issues include non-productive time for wells and operations when carrying out a traditional work over. The new approach is based on wells that have been identified with sustainable annulus pressure in the A annulus (SAP "A") due to tubing leak. Those wells have been evaluated following the industry best practices and the company Code of Practice. The investigation started on identifying the tubing / Annulus integrity with the different procedures of pressure test, If the leak is established, then the use of leak detection logs (LDL) with an e/L unit to identify the exact location of the leak. At the same time a MultiFinger caliper logs (MFC) is the great use to evaluate the condition of the tubing ID, identifying the extension of the corrode section. During the evaluation of the trial found dictate the selection between tubing patch or a straddle solution. For the tubing patch solution, the requirement is to have one (1-2) leak point in the string, For the straddle solution the requirement is to have multiple leak points (to add the appropriate spacer length), be retrievable and allow accessibility and longevity of the well life cycle. The selection of the rigless solutions for issues due to tubing leak will help in reducing rig mobilization costs and non-productive time and reduce well inactivity of the production/injection of the well. The implementation of the tubing patch was evaluated on 3 different wells. Where well 1 as WI well with 2 identify leak points and solution for 2 different patch sections with a positive result on the Annulus pressure test post patch installation. The 2nd well as WI well with 1 identify leak points with a positive result on the Annulus pressure test and LDL post patch installation. The 3rd well as OP/GLM well with 1 identify leak points with a negative result on the LDL post patch installation. As per the badly corrosion levels in the tubing. The observations found during the resolution and application of these solutions, were the level of corrosion as a limiting factor when selecting the availability and suitability of these solutions. 3 Well were used for the development of the trial and just 2 provided positive results, the 3rd well fails. The utilization of these technologies can enhance the operational side to solve the leakage of tubing strings in short time of inactivity, generating revenue and new procedures for barriers evaluation in different type of string and wells. Providing this solution reduces the utilization of rigs and huge cost related for just recomplete the well, instead of the extension of the life cycle.