The most frequently encountered problems while drilling an oil or natural gas well are lost circulation; the uncontrolled flow of drilling fluids into a downhole formation and differential sticking; condition whereby the drill string cannot be moved along the axis of the wellbore. These problems in turn augment the non-productive time (NPT) causing substantial financial loss. These harms occur generally in the vicinity of porous & permeable zones. The proposed method incorporates using Silicon nanoparticles in drilling mud composition to decrease the mud cake thickness. The advantage of Silicon nanoparticles is that, there is formation of more continuous and integrated mud cake. Hence, by having an integrated (having low permeability and low porosity) mud cake, there is less volume of filtrate entering the formation and therefore mud cake thickness is less than in normal cases. The consistent particle size distribution provides better compaction medium with constrained flow of liquid from the drilling fluid. Furthermore, a thinner mud cake reduces the probability of stuck pipe. The addition of Silicon nanoparticles does not have much effect on the drilling fluid viscosity and other properties. Silicon nanoparticles have thermal stability upto 2500 degree Fahrenheit. Moreover, the use of Silicon nanoparticles does not have side effects on the environment. These nanoparticles are generally immediately available in the required volumes. These require simple application techniques, consequently providing an appropriate solution to problems like stuck pipe and loss circulation while drilling. This technique will provide novel insight in the reduction of problems faced while drilling (both vertical and deviated) wells and help in countering those problems in a more efficient and environment friendly manner.

The most frequent problem encountered in day to day oil well production is the deposition of paraffin or wax inside the production tubing. The solution to this problem is frequent scraping and hot oil operation with help of Coiled Tubing Unit (CTU) thereby increasing the non productive time. The following paper proposes an alternative technique for dewaxing of production tubing.

The vertical-lift performance curves are often generated with the aid of computer software for creating well models of producing oil and gas wells. These models are used as tools for optimizing fluid production, generation of production forecast and well problem diagnosis. The well models are further used to plan for future requirement of artificial lift assistance. One of the important components for development of representative well models is the Vertical Lift performance and Inflow Performance curve matching. The vertical lift performance curve is generated separately using well test data using various correlations and the best matching correlation to actual well pressure gradient is selected for VLP-IPR matching. The VLP depends on various factors such as tubing size, gas-liquid ratio, wellhead pressure, etc. The producing oil wells having higher paraffin content tend to deposit paraffin wax inside the production tubing reducing the flow area and increasing the pressure drop. The deposition generally occurs near the surface and at greater depths the tubing is free from deposition due to higher temperature because of the geothermal gradient. Due to this an error is induced as the effective inside diameter of tubing is less than the actual diameter entered by the user, this leads to variation in the actual and calculated pressure drop ultimately leading to deviation by more than 10% in many cases. This paper describes implementation of method to enter the severity of paraffin deposition in a particular length of tubing and dividing the total length of tubing into sections having different internal diameters. The estimation of deposition can be done by carrying out mechanical scraping operation in which the wax is cut mechanically using paraffin cutters of various sizes starting with the smallest and gradually increasing to higher sizes of cutters. The restriction due to wax is evident at the surface by monitoring the weight loss in the wireline weight indicator. By using this method an accurate well model can be created which will represent the actual behavior of the producing well thereby increasing the accuracy of any further predictions.

The most common oil field wellbore problem encountered is paraffin deposition in the production tubing. The crude oil production is impeded by accumulation of such waxy residues that tend to clog the tubing, perforations and pores of the reservoir rock through which the oil flows.Hot oiling with the help of coiled tubing is usually the method applied for removing paraffin deposits, however there is a high possibility of significant amount of the fluid injected into the well being lost to the formation, and hence the potential to damage the formation with low bottom-hole pressure is high. One such case was encountered in a well operated by Oil India Limited and this paper provides details of innovative technique applied for successful execution of hot oiling operation in the low BHP well minimizing formation damage.As the well had very low BHP, there was a need to use circulating fluid with density lower than that of the source oil utilized for conventional hot oiling operation. Hence, it was decided to carry out the job by using a mixture of hot oil and nitrogen gas so as to reduce the density of the circulating fluid, thereby avoiding loss of injected fluid to the formation.This paper provides the case study of the successful operation carried out in the well along with the detail calculations of pumping rates and pressure of both hot oil and nitrogen gas to obtain the desired density of the circulating fluid.