Volume 11: Petroleum Technology最新文献

{"title":"Effect of Polymer Fluid Viscoelastic Properties on the Initiation of Transition From Laminar to Turbulent Flow Regime and the Drag Reduction in the Flow Through Horizontal Pipe","authors":"Mehmet Meric Hirpa, E. Kuru","doi":"10.1115/omae2020-18098","DOIUrl":"https://doi.org/10.1115/omae2020-18098","url":null,"abstract":"\u0000 This study investigated the flow of viscoelastic fluids through horizontal pipeline mainly focusing on the effect of fluid elasticity on drag reduction and onset of transition to turbulent flow regime. In order to be able to see the sole effect of fluid elasticity (independent from shear viscosity), three non-Newtonian fluids having the same shear viscosity but different viscoelastic properties were tested in the horizontal flow loop. Those fluids were the dilute solutions of partially hydrolysed polyacrylamide (HPAM) and they were prepared by using three polymer grades of HPAM (i.e. 5 × 105, 8 × 106, 20 × 106 g/gmol) in different compositions. Experiments have shown that increasing fluid elasticity resulted in higher drag reduction in pipe flow. Moreover, fluid elasticity affected the onset of turbulent flow and an earlier transition to turbulent flow regime (as compared to water flow) was only observed for the flow of fluid having the highest elastic properties. So, understanding effects of fluid elasticity on flow dynamics might improve the performance of fluids engineered for hole cleaning/cuttings transport in oil and gas well drilling or proppant transport in hydraulic fracturing operations. Also, field efforts to find solutions to problems caused by excessive dynamic pressure losses encountered in drilling horizontal or extended reach wells or in transporting hydrocarbons through pipeline might benefit from the findings of this or further extended research on this subject.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128896373","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Leakages Through Radial Cracks in Cement Sheaths: Effect of Geometry, Viscosity and Aperture","authors":"Ragnhild Skorpa, Torbjørn Vrålstad","doi":"10.1115/omae2020-18496","DOIUrl":"https://doi.org/10.1115/omae2020-18496","url":null,"abstract":"\u0000 Annular cement sheath is considered to be one of the most important barrier elements in the well, both during production and after well abandonment. It is however well-known that mechanical damage to the cement sheath might result in leakage pathways, such as microannuli and radial cracks, and thus loss of zonal isolation. In this paper we have studied the effect of geometry, aperture and viscosity on the resulting pressure driven flow through real radial cracks in cement sheaths using Computational Fluid Dynamics (CFD) simulations.\u0000 Real radial cracks were created by downscaled laboratory pressure cycling experiments and the resulting geometries were mapped by X-ray Computed Tomography (CT). This gave a unique 3D volume of the degraded cement sheaths which provides detailed information about the morphology, such as the irregular apertures and roughness, as well as locations of the radial cracks.\u0000 In this study, we have used five experimentally created geometries, varying from barely connected to fully connected and almost uniform cracks. Additionally, theoretical uniform models with homogeneous aperture and a smooth surface were created for comparison. The simulations were performed by importing the experimentally created leak paths into a CFD simulation software, making it possible to determine the actual flowrate as a function of pressure drop. Methane gas, water and oil was used as model fluids.\u0000 The simulation results show that fluid flow through real cracks in cement sheath is complex with torturous paths, especially around bottlenecks and narrow sections. Additionally, the results show that flow of both methane gas- and water are not linear and hence does not follow Darcy’s law. This illustrates that simple models are not able to fully describe fluid flow through such complex geometries.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123420387","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Gas Suspension Effects in Riser Unloading and Appropriate Modelling Approaches","authors":"Dalila Gomes, K. Fjelde, K. Bjørkevoll, J. Frøyen","doi":"10.1115/omae2020-18049","DOIUrl":"https://doi.org/10.1115/omae2020-18049","url":null,"abstract":"A kick entering a drilling riser and expanding upwards uncontrolled can lead to severe consequences such as riser unloading and riser collapse, and in the worst case a blowout scenario may evolve. If the riser is filled with water-based mud, the kick will normally migrate on its own to surface, but it has been observed both in small scale experiments and in field tests that small amounts of gas are trapped by the mud during the kick migration. In some cases, the kick is not able to reach the surface without additional circulation. Hence, a certain kick size may or may not lead to an unloading scenario depending on the effect of gas suspension in the drilling fluid.\u0000 In this paper, two different modelling approaches for describing the unloading scenario will be compared and the differences will be highlighted. In the first approach, the single bubble model will be considered. Here the gas bubble is assumed to occupy the whole cross-sectional area, and it is fully separated from the mud regions. This will be solved by two different calculations methods, one that is taken from literature and one that is based on a shooting technique. The second and recommended approach is to use a transient drift flux model, which includes friction, acceleration terms, and gas slip. For the gas slippage model, different flow patterns will be accounted for, as will the suspension effect that causes small amounts of gas to be trapped by the mud. The drift flux model will be solved numerically using the explicit AUSMV scheme.\u0000 The impact of gas suspension will be studied by varying the onset for gas suspension to determine from simulations whether a riser will be unloaded or the kick become fully trapped in the riser. In addition, a sensitivity analysis will be presented where kick size, riser ID and riser length are varied to determine when the riser will be unloaded. The different simulations presented solves physical equations of the unloading scenario to calculate pressure at BOP, displaced mud volume (pit gain), liquid mass in well, surface rates, riser friction, and depth profiles of the gas distribution at a certain time. the tables provide a comprehensive overview of which combinations of parameters lead to a trapped gas scenario or and which lead to unloading the riser.\u0000 It is shown that a fully transient drift flux model can cover a vast range of different situations e.g. gas becomes fully trapped in the riser, the riser becomes fully unloaded, and situations where only a very small part of the kick reaches the surface. The simulations show how the dynamics of the scenarios are quite different. A single bubble model will not have this capability.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"29 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133908874","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Quantitative Characterization, Design Considerations and Sustainable Resource Management for Middle Eastern Tight Gas Reservoirs","authors":"A. Suboyin, Motiur Rahman, M. Haroun","doi":"10.1115/omae2020-19307","DOIUrl":"https://doi.org/10.1115/omae2020-19307","url":null,"abstract":"\u0000 Augmented by recent activities in the oil and gas industry, it can be seen that an economical and efficient hydraulic fracturing job has become critical for the successful development of unconventional reservoirs. However, exploitation of unconventional reservoirs is heavily water-intensive as compared to conventional reservoirs. Given this concern, it is essential to reform how water is managed within the industry, especially in water scarce regions such as the Middle East.\u0000 In this study, a comprehensive investigation that deals with the quantification of changes with respect to variation in prime contributors within a traditional fracture design process is presented. This can assist to determine the distinct contributions of an element within fracture design parameters, as they are imperative to evaluate the nature of fracture propagation. After an extensive assessment, a set of natural fractures were introduced to the system and the system behavior was further investigated to identify their behavior and optimize resource management. Based on an iterative process, the results of the constructed simulation models were analyzed in depth and validated with field data.\u0000 Overall, the results indicate that for the given field conditions, fluid and proppant optimization are critical to achieve maximum recovery. The dominance of parameters such as fracture width, fracture length, proppant placement and Young’s Modulus are also illustrated in depth. To examine the associated response on long-term productivity, the results have been extended to current field practices and cases. A rough analysis was conducted in-house, on geological data from a candidate field in the Middle East. Findings shows the potential to optimize and reduce the required water for an operation by 1.3 million gallons. This further highlights the need to optimize and tailor an adaptable workflow, which is proposed in this study, for water scarce regions such as the Middle East.\u0000 In addition to ultimately assisting in verification of modern best practices, this investigative approach will create a paradigm for future studies within the Middle Eastern region to assist in a simplistic prediction of fracture propagation behavior and its associated response to optimize water usage. The results have also been extended along with comparisons to current field practices.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"114 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133379475","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Statistical Assessment of Alternative Methods for Well Recovery Estimation in Naturally Fractured Reservoirs With Fracture Corridors","authors":"Samir Prasun, A. Wojtanowicz","doi":"10.1115/omae2020-19355","DOIUrl":"https://doi.org/10.1115/omae2020-19355","url":null,"abstract":"\u0000 Reliable predictions of well recovery are crucial for designing reservoir development. In the bottom-water naturally-fractured reservoirs (NFRs), comprising a network of distributed fracture “corridors,” spacing (and apertures) of the corridors varies throughout the reservoir. This makes oil well’s recovery a probabilistic variable as it depends upon uncertain well’s location in the network. The uncertainty is two-fold; it concerns well’s location within corridor network and well’s possible intersection with the nearest corridor. In any network’s location (with closely- or sparsely–spaced corridors), wells may intercept fracture corridors (fracture well) or go in-between two corridors in a matrix block (matrix-well). A simplified way of estimating well recovery is to ignore well’s location within corridor network and consider only probability and performance of fracture well and matrix well in a statistically-equivalent reservoir with uniform spacing and aperture equal to their expected values derived from their known statistics. Another (fully probabilistic) method considers the combined probabilities of the well’s location in the network and being a fracture well or matrix well. The study evaluates discrepancy between the two methods, explains its statistical nature, and demonstrates their implementation in a corridor-type NFR described in the literature.\u0000 In the study, recovery process is simulated by coupling the inner (near-well) zone’s discrete single-porosity flow model with the outer zone Dual Porosity Dual Permeability (DPDP) simulator. The matrix well’s inner zone extends from the well to the nearest corridor and for the fracture well inner zone covers the corridor and adjacent matrix blocks. In the simulations, matrix and fracture-wells are operated at maximum rate constrained by minimum downhole flowing pressure and the surface handling limit. The study is performed using statistical data from a corridor-type NFR with power-law-distributed spacing size from 19 ft to 153 ft and corridor apertures varying from 8ft to 31ft correlated with the spacing.\u0000 The simplified method gives recovery values ranging from 28% to 37%, and the single value of total recovery 33% — normalized by the matrix and corridor size fractions of the total reservoir area. Alternatively, the probabilistic method gives two separate distributions of the fracture and matrix wells’ recoveries that are weighted by their probability and converted to a single distribution of total recovery using statistical concept of weighted average. The probabilistic estimation gives higher values of recovery — from 32% to 38% with the expected value of 36.6%. Moreover, there is a considerable 30% probability of having recovery greater than 36.6%. A mathematical proof provides explanation why the probabilistic method gives recovery estimate greater than that from the simplified method. Another advantage of the method is the cumulative probability plot of well recovery that, in practic","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126234993","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Dynamic Analysis of a Progressing Cavity Pump System Using Bond Graphs","authors":"Jeronimo de Moura, G. Rideout, S. Butt","doi":"10.1115/omae2020-18845","DOIUrl":"https://doi.org/10.1115/omae2020-18845","url":null,"abstract":"\u0000 One commonly used pump in the petroleum sector is the Progressing Cavity Pump (PCP). The PCP is a type of positive displacement pump that is used as an artificial lifting system which consists of a helical rotor and elastomeric stator. A mathematical solution to a PCP system model requires that we solve a partial differential equation system. The solution is inherently complex and requires considerable computational time. This paper uses the bond graph formalism, which is based on energy and information flow, to implement a model of a PCP system. Its purpose is to predict the dynamic response of the PCP system when it is subjected to a specific reservoir condition. Specifically focusing on the rod string, the torsional effects are captured by a lumped segment approximation. The software 20-Sim© was used to simulate a realistic PCP system application scenario. The model presented in this paper is able to determine the prime mover, rod string, and other component requirements. This paper shows that the multi-body lumped segment model is a useful way to simulate the rod string performance. The bond graph is effective at modeling the PCP system which contains elements from different energy domains.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"66 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127105677","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Second-Order Correlation of Klinkenberg-Corrected Permeability and its Experimental Verification on Heterogeneously-Stressed Gas Shale","authors":"Yufei Chen, Changbao Jiang, J. Leung, A. Wojtanowicz, Dongming Zhang, Chuanyao Zhong","doi":"10.1115/omae2020-18323","DOIUrl":"https://doi.org/10.1115/omae2020-18323","url":null,"abstract":"\u0000 Shale is an extremely tight and fine-grained sedimentary rock with nanometer-scale pore sizes. The nanopore structure within a shale system contributes not only to the low to ultra-low permeability coefficients (10−18 to 10−22 m2), but also to the significant gas slippage effect. The Klinkenberg equation, a first-order correlation, offers a satisfying solution to describe this particular phenomenon for decades. However, in recent years, several scholars and engineers have found that the linear relation from the Klinkenberg equation is invalid for most gas shale reservoirs, and a need for a second-order model is, therefore, proceeding apace. In this regard, the purpose of this study was to develop a second-order approach with experimental verifications.\u0000 The study involved a derivation of a second-order correlation of the Klinkenberg-corrected permeability, followed by experimental verifications on a cubic shale sample sourced from the Sichuan Basin in southwestern China. We utilized a newly developed multi-functional true triaxial geophysical (TTG) apparatus to carry out permeability measurements with the steady-state method in the presence of heterogeneous stresses. Also discussed were the effects of two gas slippage factors, Klinkenberg-corrected permeability, and heterogeneous stress. Finally, based on the second-order slip theory, we analyzed the deviation of permeability from Darcy flux.\u0000 The results showed that the apparent permeability increased more rapidly as the pore pressure declined when the pore pressures are relatively low, which is a strong evidence of the gas slippage effect. The second-order model could reasonably match the experimental data, resulting in a lower Klinkenberg-corrected permeability compared with that from the linear Klinkenberg equation. That is, the second-order approach improves the intrinsic permeability estimation of gas shales with the result being closer to the liquid permeability compared with the Klinkenberg approach.\u0000 Analysis of the experimental data reported that both the first-order slippage factor A and the second-order slippage factor B increased with increasing stress heterogeneity, and that A was likely to be more sensitive to stress heterogeneity compared with B. Interestingly, both A and B first slightly increased and then significantly as the permeability declined. It is recommended that when the shale permeability is below 10−18 m2, the second-order approach should be taken into account. Darcy’s law starts to deviate when Kn > 0.01 and is invalid at high Knudsen numbers. The second-order approach seems to alleviate the problem of overestimation compared with the Klinkenberg approach and is more accurate in permeability evolution.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"43 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115051700","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Nanoparticles As Promising Additives to Improve the Drilling of Egyptian Oil and Gas Fields","authors":"A. Mady, O. Mahmoud, A. Dahab","doi":"10.1115/omae2020-18858","DOIUrl":"https://doi.org/10.1115/omae2020-18858","url":null,"abstract":"\u0000 Egypt is both one of the major oil-producing non-OPEC countries and one of the oldest energy producers in the Middle East. Recently, the Egyptian government have signed several agreements for the exploration of oil and gas in several provinces/regions including; the Mediterranean, the Western Desert, the Nile Delta, and the Gulf of Suez. Petroleum companies have given great attention to Egypt’s new discoveries such as Zohr Gas Field and Nour exploration prospect. Successful drilling operations to reach the oil and gas targets depends strongly on the effectiveness of the drilling fluid (mud). It can be considered as the heart of the drilling process, where they are used to fulfil several valuable functions.\u0000 Drilling fluid technology is one of the most targeted and developed technologies worldwide. Several studies have examined the use of various types of nanoparticles (NPs) to enhance the properties and improve the performance of muds. NP can be defined as a simple particle structure with a size in the range of nanometers. The effectiveness of NPs can be accredited to their small size and high surface-area-to-volume ratio. Using NPs showed promising enhancements on the rheological and filtration characteristics as well as thermal stability and carrying capacity of the drilling fluid. Moreover, adding NPs to the drilling mud was found to minimize the shale permeability and thus, promote wellbore stability. The swelling and collapse of shale formations is expected under drilling with water-based mud, which might complicate the drilling operation.\u0000 In the present work four types of NPs (nanosilica, nanoaluminium, nanotitanium, and nano copper oxide) were tested as promising additives to improve the characteristics of KCL-Polymer mud, which is mainly used to drill shaly formations. The impact of NPs-type, -size, and -concentration were thoroughly investigated using standard viscometer and API filter press. The results showed higher potential of nanotitanium and nanoaluminium to enhance the mud properties when used at small concentrations (0.3–0.5 wt.%).\u0000 This research paper discusses a latest application and presents the most valuable findings concerning the efficient use of NPs in the drilling fluid industry. On this basis, different recommendations are stated, which might help researchers to better understand NPs’ functionality in this area of application and promote using NPs-based drilling muds as cost-effective and environmental-friendly fluids to drill the Egyptian oil and gas wells.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116881810","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Droplet Size Distributions and Pressure Control in the Gas-Liquid Cylindrical Cyclone","authors":"Lele Yang, Jing Wang, Liangshuai Zou","doi":"10.1115/omae2020-18604","DOIUrl":"https://doi.org/10.1115/omae2020-18604","url":null,"abstract":"\u0000 The gas–liquid cylindrical cyclone (GLCC) employs gravitational and centrifugal forces to realize gas-liquid separation. The aim of this study is to understand the droplet size distribution and pressure control in the GLCC via experiment and numerical analysis. The droplet size and pressure distributions were measured using Malvern RTsizer and pressure transmitters, respectively. The Discrete Phase Model was used to numerically analyze the swirling hydrodynamics of the GLCC. The results showed that the increase in the gas superficial velocity decreased the droplet size distribution at the inlet as a whole due to the shear effect and flow instability. The increase in the liquid superficial velocity only increased the small droplet size distribution at the inlet for the limitation of the gas’s carrying capacity. The pressure loss mainly occurred at the inlet and the overflow outlet. When the liquid level was remained below the inlet and above the liquid outlet, the liquid level and the liquid outlet section approximately met the Bernoulli equation for a finite large flow beam. With the increase in the pressure at the gas outlet, the liquid film fell back and the separation efficiency increased gradually. These results are helpful for further spreading applications of the GLCC in industry.","PeriodicalId":403225,"journal":{"name":"Volume 11: Petroleum Technology","volume":"37 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2020-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121679627","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}