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Cold heavy oil production with sand (CHOPS) is a primary production method used for heavy oil reservoirs with no requirements of external energy consumption. A new model for CHOPS is simulated by incorporating wormhole propagation and foamy oil behaviour mechanisms to evaluate the recovery of an extra‐heavy oil reservoir of the Athabasca region. The most critical mechanisms of CHOPS, wormhole propagation and foamy oil behaviour, are captured by using Wang's model for wormhole propagation and Uddin's model of gas exsolution. After 120 months of simulation, 53.38%, 99.76%, and 100% of wormhole propagation were achieved during three time steps of 12, 48, and 60 months, respectively, toward the sides of the studied reservoir section. The propagation was achieved within all directions of the investigated section compatible with the erratic nature of wormhole propagation. Furthermore, the application of Uddin's model was incorporated into production by reducing the fluid viscosity as a result of the foamy oil behaviour. Over 3% of the recovery was achieved at the end of the primary CHOPS phase simulation by taking into account that we modelled the recovery based on highly viscous oil with API 7.5. Finally, the model can provide an improved understanding of the primary CHOPS process by considering its two significant mechanisms. [ABSTRACT FROM AUTHOR]

In carrying out research for the oil and gas (O&G) industry and similar fields of study, it is necessary to have a general understanding of multiphase flow and its components. A multiphase flow is one in which two or more phases flow simultaneously, with the term "phase" defined here as the state of matter (i.e., gas, liquid or solid). For O&G-related applications, two-phase flows are the most frequently used forms of multiphase and include gas-solid, gas-liquid, liquid-liquid and solid-liquid patterns. In general, pressure gradients and flow resistance are reduced when water is added to the flow of oil. In the present work, the effect of pressure and temperature on multiphase flows in horizontal and subsea pipelines is investigated. As well, models of flow patterns and pressure drops are created specifically for horizontal and subsea pipeline environments. Note that the terms "one-phase" and "single-phase" are used interchangeably in this study. [ABSTRACT FROM AUTHOR]

Multiphase flow is a critical phenomenon in the petroleum and chemical engineering industries. Hence, it is extremely important to understand flow behaviour, including the precise identification of multiphase flow in pipelines, as multiphase flows can affect flow rates as well as the measurement accuracy of phase fractions and other phase parameters. Well streams and influx are a complex mixture of different phases, including water, oil, gas and sand, and are crucial to multiphase flow patterns, particularly in relation to the control and monitoring of pressure. If there is a pressure imbalance in the wellbore, reservoir fluids can be forced into it, creating a kick situation that can cause blow-outs with disastrous human, financial and environmental consequences. All of these events are related to multiphase flow assurance. The major objective of the present work is to gain a better understanding of multiphase flow characteristics in long pipelines. The results of experimental research on multiphase flow that investigates fluid characteristics in a pipe are presented. The experimental unit consists of pipes comprised of clear PVC, which can produce several different flow regimes (e.g., stratified, churn, slug, bubble and annularmist flow) of gas-liquid flows. The flow loop measures 25 m in length; it contains sensors for gauging pressure ranging from 20 to 300KPa, temperature ranging from -5 to 35°C at numerous locations along the pipeline loop, and liquid flow rate (which measures volume flow) ranging from 3 to 30 gallon/min. An experiment is conducted for multiphase flow (bubble, and slug flow regimes). The outcomes of this study will provide relevant new experimental data on multiphase flow characteristics for diverse flow regimes, which can help to develop flows that take into consideration pipeline conditions as well as the effects of temperature and pressure. [ABSTRACT FROM AUTHOR]

Phenolic compounds exist widely in the industrial effluents such as those from oil refineries and the coal tar, plastics, leather, paints pharmaceutical and steel industry. Since they are highly toxic and are, in general, not amenable to biological degradation methods of treatment which are continuously being modified and developed. Possible methods include chemical oxidation, coagulation, solvent extraction, liquid membrane permeation and adsorption. In the present study, three organic Phenolic compounds (Cresol, phenol and Nitro phenol) have been used to determine their adsorption from dilute aqueous solutions on cement kiln dust (CKD). The adsorption studies were carried out in three stages. In the first stage the adsorption isotherm process was studied. A fixed amount of cement kiln dust (by-pass) with different initial concentration of the Phenolic compounds was used. The maximum adsorption capacity for cement kiln-dust CKD) was found to be: q max = 87 mg/g for Cresol, q max = 125 mg/g for phenol and q max = 101 mg/g for Nitro phenol. An attempt has been made to represent the experimental data obtained by the Langmuir, Freundlich and Redlich-Peterson models. All the models were found to satisfactorily represent the experimental data under investigation with varying degrees of success. For solute systems, the experimental data were found to conform the Langmuir isotherm. Also, the results have been proven the favorability of such cement kiln dust for removal of the phenolic compounds. In the second stage batch process was carried out for phenolic compounds with different initial concentration and adsorbent masses, these variables affecting the external mass transfer coefficient. Different Design equations were obtained: Kf = 0.9549 M0.393 for the adsorption of cresol, Kf = 1.918 M0.983 for the adsorption of phenol, Kf = 1.667 M0.7217 for the adsorption nitro phenol, Kf = 0.2043 Co for the adsorption of cresol, Kf = 0.7176 Co-0.983 for the adsorption of phenol, and Kf = 0.0997 Co-0.4775 for the adsorption nitro phenol. The third stage of this present work was carried out using a fixed bed column. The effects of the process variables such as height of the bed, the rate of flow, and breakthrough have been investigated. The results have been used to predict the effect of parameter changes on the system by using the bed depth service time (BDST) and the EBRT model. [ABSTRACT FROM AUTHOR]

Multiphase flow is a multi-component flow which occurs in many industrial processes including those involved in the pharmaceutical, food, processing, and petroleum industries. Oil and gas exploration, production and transportation in arctic and offshore conditions are technically very challenging. In addition to the technical challenges involved in arctic operations, there are several environmental challenges posed by offshore operations. One of the operational challenges of hydrocarbon transmission through flow lines in offshore and arctic environments is the formation of hydrates. This imposes a severe flow assurance challenge in offshore operations. Hydrates can form during untreated water flow through a pipeline with high pressure in cold weather. This untreated water can characterize by their multiphase nature and therefore require flow assurance analysis and evaluation during each design stage of offshore project. The main goal of this study is to conduct experiments to understand how multiphase flow affects the formation of hydrates in flow lines. From the preliminary experimental results in the Multiphase Hydrate Flow loop at Memorial University of Newfoundland, we have observed that two-phase gas-liquid flow produces higher pressure in the flow lines compared to single- phase flow. Moreover, due to turbulence in the bends of the flow lines, there is an approximately 1°C local temperature increase in bends. In the future work related to this study, a parametric study will be presented to attempt to understand how multiphase hydrodynamic and pipe length scale (diameter) will affect the hydrate induction time. This study will also help to minimize flow assurance challenges in offshore flow lines and provide improved design conditions. [ABSTRACT FROM AUTHOR]