Working Guide to Drilling Equipment and Operations offers a practical guide to drilling technologies and procedures. The book begins by introducing basic concepts such as the functions of drilling muds; types of drilling fluids; testing of drilling systems; and completion and workover fluids. This is followed by discussions of the composition of the drill string; air and gas drilling operations; and directional drilling. The book identifies the factors that should be considered for optimized drilling operations: health, safety, and environment; production capability; and drilling implementation. It explains how to control well pressure. It details the process of fishing, i.e. removal of a fish (part of the drill string that separates from the upper remaining portion of the drill string) or junk (small items of non-drillable metals) from the borehole. The remaining chapters cover the different types of casing and casing string design; well cementing; the proper design of tubing; and the environmental aspects of drilling.

Oil and gas well tubing strings must be designed to withstand the forces and stresses generated by the anticipated service conditions over the operating life of the well. In addition, if the tubing is free to move, tubing length changes must be determined so that adequate seal assembly lengths are selected. This section is designed to help the completion engineer in understanding the reasons and consequences of the stresses and strain caused to the tubing and guide him/her through the tubing stress analysis process. Introduction: The cost of tubulars and completion components is often a large portion of the total well cost and can be as high as 20% of the total. The tubing and the completion form an integral part of the safety of the well. Failure of the completion can result in injuries, fatalities, major expenditure and considerable loss of production. Tubing stress analysis is a major requirement of any completion design. Since the calculations involved in the analysis procedure are complex, a computer program is used in determining the optimum tubing design. Consequently, it is no longer necessary for the designer to perform hand calculations to analyse tubing string stress and strain. However, an understanding of the calculations and procedure is required to properly utilise the tubing analysis computer model. Computer analysis liberates the designer from the drudgery of repetitious calculations due to the all the permutations of prognosed data available and optional completion designs so that he or she can concentrate on achieving a more accurate estimate of the service conditions. The tubing stress analysis computer program in use by BP worldwide is Enertech’s WellCat package. This document is not intended to be a user manual for such computing packages although reference can be made to the WellCat manual. Keywords: tubing stress analysis, oil and gas industry, drilling

In petroleum refining, the Crude Distillation Unit (CDU), also known as as the Atmospheric Distillation Unit, is usually the first processing equipment through which crude oil is fed. Crude oil is composed of a mixture of hydrocarbons, and the distillation process separates this crude oil into broad categories of its component hydrocarbons, or "fractions," which serve as feedstocks for all other processing units at the refinery.  As oil is being fed into the crude distillation unit, the first thing that happens is the crude is heated to a temperature between 215°F and 280°F (100°C - 137°C).  This allows salts, which can be harmful and corrosive to some equipment, to be removed at the desalter.  The now desalted crude is further heated to temperatures up to 750°F (400°C) as it is fed into the atmospheric distillation tower where the vapors and liquids separate based on the different temperatures at which they boil/condense. At temperatures above 750°F (400°C), the oil would thermally crack, or break apart, which would hinder the distillation process.

What is Oil and Gas Separation? The process of oil and gas separation is crucial in the petroleum industry as it helps in the separation of crude oil, natural gas, and water for further processing and transportation. When oil and gas come out of the wellhead, they are in a state of a multiphase system that comprises of hydrocarbons, water, and at times solids. When there is no separation, downstream refining and transport are affected, and this leads to operational problems and high costs. The main goal of the oil separation process is to maximize the purity of each component with the least amount of energy and time. Effective separation improves productivity, reduces wear and tear of equipment and helps in meeting the legal requirements of environmental impacts. It works like the traffic light system of a city where each component is guided to its proper place to prevent traffic jam and delay. This not only safeguards the infrastructure but also enhances the efficiency of hydrocarbon recovery, which is a key element of the current gas industry.

Joint efficiency is a factor required in all head and shell calculations that accounts for how closely a finished weld joint approximates the quality of the seamless parent material. Without further inspection it is assumed the welded joint is weaker than the material around it due to potential defects such as porosity, slag inclusions, and others. Shell thickness and therefore weld quantity is increased to account for this reduction in strength. Code welders following a qualified weld procedure are tested to weld a finished joint that maintains 100% of the parent material strength, but without further testing the allowed strength of a production joint is reduced to 70%. For some design conditions, such as lethal service, the Code requires the designer to specify full radiography. However, when not required, the designer can specify optional radiographic examination to increase joint efficiency and reduce the required thickness of shells and heads. The designer weighs the material and welding costs against inspection costs to determine which course is best suited for the application.  The figures below show the ASME VIII-1 joint efficiency values based on Type 1 joints (butt joints fully welded from both sides or equivalent) and degree of radiographic examination. The information is generated using the radiography logic diagrams and samples from Part 7 of PTB-4-2013 ASME Section VIII – Division 1 Example Problem Manual – the PTB-4 ‘E7.1’ through ‘E7.4’ example numbers are indicated where applicable. Radiography test is a nondestructive testing method of inspecting some hidden cracks in the material by using radio magnetic radiation to penetrate through the materials. The purpose is to ensure the structural integrity of the weld joint. As per ASME, there are four types of Radiography test (RT), i.e. RT1, RT2, RT3 and RT4. Joint efficiency is the number used to define welded joint strength which basically depends on the RT type. This Joint efficiency plays a vital role in determining the thickness of the pressure vessel components in Mechanical calculation. For RT1 and RT2 joint efficiency is 1.0, for RT3 efficiency is 0.85 and for RT4 efficiency is 0.70. The Weld Joint Category is how each weld on a Pressure Vessel Engineering is classified to a Joint category, based on the criticality. As per ASME there are four types of weld joint categories, Category A, Category B, Category C, and Category D. Now we can see how these three are interlinked as per ASME Sec VIII Div.1 As per ASME Sec VIII Div.1 the RT type 1 or 2 or 3 or 4 will be selected based on the type of weld joint category A or B or C or D. In turn the type of RT 1 or 2 or 3 or 4 will decide the Joint efficiency value 1.0 or 0.85 or 0.7. So this is how the Radiography test, Joint efficiency and Weld Joint category are interlinked as per ASME Sec VIII Div.1. To give an example, we have detailed the RT type with Joint efficiency based on weld category. Category A and D butt welds shall be fully radiography (RT1) hence the Joint efficiency is 1.0. Category B and C butt welds shall be spot radiography (RT3) hence the joint efficiency is 0.85. This is because longitudinal joints are more critical than circumferential joints. In general, heads connecting with shell will fall on Category B (RT-3 Spot Radiography), however in case of hemispherical head, the head with shell joint will fall on Category A (RT-2 full radiography), because this joint is more critical or it will be under double stress.

This study explores the transformative role of artificial intelligence (AI) in reshaping digital diplomacy, public relations, and security dynamics across the Middle East and North Africa (MENA) region. By integrating AI-driven analytics with social media monitoring, the research emphasizes how machine learning and algorithmic tools redefine information dissemination mechanisms, influence political narratives, and enhance cybersecurity frameworks. The study employs a mixed-methods approach, combining qualitative analysis of digital communication patterns with quantitative data on user perceptions of online security, surveillance, and self-censorship. The findings reveal that AI-enabled technologies-such as automated content moderation, sentiment analysis, and predictive modeling-serve as double-edged instruments: while they empower governments and institutions to counter disinformation, manage crises, and engage global audiences, they also raise concerns about algorithmic bias, digital surveillance, and privacy violations. In the MENA context, AI facilitates both strategic narrative control and participatory engagement, reflecting the tension between innovation and constraint in authoritarian environments. The research highlights that over 68% of surveyed users expressed fear of surveillance, and over 70% practiced self-censorship, illustrating the pervasive impact of AI monitoring on civic discourse. Ultimately, the study concludes that the future of digital diplomacy in MENA depends on adopting AI-driven but ethically governed communication strategies-balancing security imperatives with transparency, inclusivity, and digital rights. This work contributes to the emerging scholarship on AI in international communication, proposing a framework for responsible AI integration that protects user autonomy while strengthening national and regional stability.

Radiography is carried out based on the geometrical shape of the material and the required details of the image. The best possible configuration is chosen and the film placement and location of radiation source is determined. In this respect the configuration of cylindrical objects like pipeline and offshore structural members are more critical.

Measuring the flow of liquids is a critical need in many industrial applications. In some operations, the ability to conduct accurate flow measurements is so important that it can make the difference between making a profit or taking a loss. In other cases, inaccurate flow measurements – or failure to take measurements – can cause serious (or even disastrous) results. With most liquid flow measurement instruments, the flow rate is determined inferentially by measuring the liquid’s velocity or the change in kinetic energy. Velocity depends on the pressure differential that is forcing the liquid through a pipe or conduit. Because the pipe’s cross-sectional area is known and remains constant, the average velocity is an indication of the flow rate. The basic relationship for determining the liquid’s flow rate in such cases is: Q = V x A Where Q = Liquid flow through the pipe V = Average velocity of the flow A = Cross-sectional area of the pipe Other factors that affect liquid flow rate include the liquid’s viscosity and density, as well as the friction of the liquid in contact with the pipe. What is a Flow Meter? A flow meter (or a flow sensor) is type of flow instrument that is used to indicate the amount of liquid, gas, or vapor moving through a pipe or conduit by measuring linear, non-linear, mass, or volumetric flow rates. Since flow control is often essential, measuring the flow of liquids and gasses is a critical need for many industrial applications – and there are many different types of flow meters that can be utilized depending on the nature of the application. When choosing a flow meter, one should consider such intangible factors as familiarity of plant personnel, their experience with calibration and maintenance, spare parts availability, and meant time between failure history, etc., at the particular plant site. It is also recommended that the cost of the installation be computed only after taking these steps. One of the most common flow measurement mistakes is the reversal of this sequence: instead of selecting a sensor which will perform properly, an attempt is made to justify the use of a device because it is less expensive. Those “inexpensive” purchases can be the costliest installations. 

Pipe welding involves several sequential passes to create a perfect, strong weld. The welding passes refer to the order of execution required when carrying out the pipe welding process. The four passes typically used in pipe welding include the root pass, hot pass, fill-up pass and capping. Root Passes A root pass is the first step in any welding process and involves joining two pieces to form one structure. In this step, we heat the filler metal to an exceptionally high temperature and pass it through the gap between the pipes. Utilising the root pass requires more expertise than the following passes, so it is essential to exercise caution. To ensure complete fusion, the welder should use quality control measures like backing gas. In order to complete the weld pass, you must keep the root face smooth and uniform. If there are any imperfections on the weld face, you can correct them by grinding it out, so it does not have to be smooth or uniform initially. distribution of non-critical materials in industrial settings. People typically use it for transporting water, non-combustible chemicals, and other non-hazardous materials. Because its contents are not hazardous or flammable, low-pressure pipes provide a safe and cost-effective solution for many applications.

Pressure vessels are specialized containers used to store or transport gases and liquids under pressure, either significantly higher or lower than the surrounding atmospheric pressure. These containers are highly regulated and must meet strict safety standards to ensure they can withstand the extreme pressures they are subject to. Examples of pressure vessels include boilers, compressed air tanks, propane tanks, heat exchangers, and chemical reactors. In addition to steel, pressure vessels can also be made from aluminum or composite materials. Pressure vessels can be either spherical or cylindrical in shape and range in size from small tanks one person can carry to massive industrial vessels several stories tall. Regardless of their size or shape, all pressure vessels share one common goal: safely contain their contents at high pressures. Pressure vessels are used on space vehicles to store a variety of consumable commodities in liquid or gaseous form over a wide range of pressures and temperatures. The stored commodities can be used as pressuring, propellants, pneumatic gases, hydraulic fluids, power reactants, coolants, purge gases, or sources of breathable atmosphere. The pressure vessels themselves can be designed with any geometry; however, due to packaging efficiency and manufacturing considerations, they are typically spherical or cylindrical in shape and designed primarily for the storage of pressurized fluids.

Damage Mechanisms Affecting Fixed Equipment in the Refining Industry, is a recommended practice developed and published by the American Petroleum Institute (API) that provides an in-depth look at nearly 70 different damage mechanisms that can occur to process equipment in refineries. According to the third edition of this recommended practice, its purpose is “to describe the wide variety of service-induced damage and deterioration mechanisms, including corrosion and other types of metallurgical damage, that are most likely to affect the condition of the materials of construction commonly used in refinery equipment.” However, much of the information included in this document can also be applied to petrochemical and other industrial applications, as the user deems appropriate. API RP 571 was originally published in 2003, and the third edition was released in March of 2020. This RP is intended to supplement API RP 580, API RP 581, and API RP 579, and is nearly 400 pages long.

<div> Types of Industrial Pumps Used in the Oil and Gas Industry </div> <div> Various types of industrial pumps are utilized for fluid transfer in the oil and gas industry. Pumps used in O&G can be classified based on their design and construction and generally fall into 6 major categories: </div> <div> <span>Centrifugal pumps</span> </div> <div> Reciprocating plunger pumps </div> <div> Progressive Cavity pumps </div> <div> Gear Pumps </div> <div> Diaphragm pumps </div> <div> Metering pumps </div> <div> <span>1. Centrifugal Pumps</span> </div> <div> Centrifugal pumps are the most common types of pumps used in the oil and gas industry. Centrifugal pumps use centrifugal force through the rotation of the pump impeller to draw fluid into the intake of the pump and force it through the discharge section via centrifugal force. The flow through the pump is controlled by discharge flow control valves. </div> <div> <span>Single stage centrifugal pumps are primarily used for transferring low-viscosity fluids that require high flow rates. They are typically used as part of a larger pump network comprising other centrifugal pumps like horizontal multistage pump units for crude oil shipping or water injection pumps used in secondary oil and gas recovery.</span> </div>