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Search Petrowiki: Formation damage from paraffins AND asphaltenes
...Formation damage from paraffins and ...asphaltenes Perhaps the most common ...formation damage problem reported in the mature oil-producing regions of the world is organic deposits forming both ...
Perhaps the most common formation damage problem reported in the mature oil-producing regions of the world is organic deposits forming both in and around the wellbore. These deposits can occur in tubing, or in the pores of the reservoir rock. Both effectively choke the flow of hydrocarbons. Table 1 shows the gross composition of crude oils, tars, and bitumens obtained from various sources. It is evident that crude oils contain substantial proportions of saturated and aromatic hydrocarbons with relatively small percentages of resins and asphaltenes.
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...Formation damage from completion workover fluids When completion or workover operations are conducted on a well (perfor...d that the use of drilling fluids during completions was inappropriate because fluids caused severe damage to the productive zone. A wide variety of fluids are now available as completion or workover fluids... This page focuses on formation damage issues related to these different types of completion and workover fluids. Contents * 1 Types of...
When completion or workover operations are conducted on a well (perforating, gravel packing, etc.), the fluid present in the wellbore must minimize the impact on the near-wellbore permeability. Several decades ago, engineers realized that the use of drilling fluids during completions was inappropriate because fluids caused severe damage to the productive zone. A wide variety of fluids are now available as completion or workover fluids. This page focuses on formation damage issues related to these different types of completion and workover fluids. A list of fluids used for completion or workover is provided in Table 1.
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...Formation damage Producing ...formation damage has been defined as the impairment of the unseen by the inevitable, causing an unknown reduction in... the unquantifiable. In a different context, formation damage is defined as the impairment to reservoir (reduced production) caused by wellbore fluids used durin...
Producing formation damage has been defined as the impairment of the unseen by the inevitable, causing an unknown reduction in the unquantifiable. In a different context, formation damage is defined as the impairment to reservoir (reduced production) caused by wellbore fluids used during drilling/completion and workover operations. It is a zone of reduced permeability within the vicinity of the wellbore (skin) as a result of foreign-fluid invasion into the reservoir rock. Typically, any unintended impedance to the flow of fluids into or out of a wellbore is referred to as formation damage. This broad definition includes flow restrictions caused by a reduction in permeability in the near-wellbore region, changes in relative permeability to the hydrocarbon phase, and unintended flow restrictions in the completion itself.
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...PEH:Formation Damage Publication Information Petroleum Engineering Handbook Larry W. Lake, Editor-in-Chief Volu...Engineering Joe Dunn Clegg, Editor Copyright 2006, Society of Petroleum Engineers Chapter 6 โ Formation Damage Mukul M. Sharma, SPE, U. of Texas at Austin Pgs. 241-274 ISBN 978-1-55563-118-5 Get permissio...oduction Any unintended impedance to the flow of fluids into or out of a wellbore is referred to as formation damage. This broad definition of ...
Introduction Any unintended impedance to the flow of fluids into or out of a wellbore is referred to as formation damage. This broad definition of formation damage includes flow restrictions caused by a reduction in permeability in the near-wellbore region, changes in relative permeability to the hydrocarbon phase, and unintended flow restrictions in the completion itself. Flow restrictions in the tubing or those imposed by the well partially penetrating a reservoir or other aspects of the completion geometry are not included in this definition because, although they may impede flow, they either have been put in place by design to serve a specific purpose or do not show up in typical measures of formation damage such as skin. Over the last five decades, a great deal of attention has been paid to formation damage issues for two primary reasons: (1) the ability to recover fluids from the reservoir is affected very strongly by the hydrocarbon permeability in the near-wellbore region, and ...
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...Additional causes of formation damage There are many possible causes of ...formation damage. In addition to the numerous sources identified in separate articles (see See Also section below), ... * 10 Category Emulsions and sludges The presence of emulsions at the surface does not imply the formation of emulsions in the near-wellbore region. Most often, surface emulsions are a result of mixing and ...
There are many possible causes of formation damage. In addition to the numerous sources identified in separate articles (see See Also section below), other, less common causes include emulsions and sludges, wettability alteration, bacterial plugging, gas breakout, and water blocks. The presence of emulsions at the surface does not imply the formation of emulsions in the near-wellbore region. Most often, surface emulsions are a result of mixing and shearing that occur in chokes and valves in the flow stream after the fluids have entered the well. It is uncommon to have emulsions and sludges form in the near-wellbore region without the introduction of external chemicals.[1]The
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...Asphaltenes and waxes Deposition of the high-molecular-weight components of petroleum fluids as solid precipi...ing on the reservoir fluid and the type of recovery process, the deposited solid may consist of: * Asphaltenes * Waxes * A mixture of these materials The deposits also can contain resins, crude oil, fines, s...cales, and water.[1] Asphaltenes and waxes are a general category of solids and, thus, cover a wide range of materials. Understandin...
Deposition of the high-molecular-weight components of petroleum fluids as solid precipitates in surface facilities, pipelines, downhole tubulars, and within the reservoir are well-recognized production problems. The deposits also can contain resins, crude oil, fines, scales, and water.[1] Asphaltenes and waxes are a general category of solids and, thus, cover a wide range of materials. Understanding the fundamental characteristics that define the nature of asphaltenes and waxes is valuable in reducing or avoiding the production impacts of their deposition. This page examines the general chemical classifications and types of asphaltenes and waxes, in addition to their solidification behaviors.
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...Category:1.8 Formation damage . Pages in category "1.8 ...Formation damage" The following 14 pages are in this category, out of 14 total. A * Additional causes of ...Asphaltenes and waxes D * Determination of flow efficiency and skin * Drilling induced ...
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...PEH:Asphaltenes and Waxes Publication Information Petroleum Engineering Handbook Larry W. Lake, Editor-in-Ch...Engineering John R. Fanchi, Editor Copyright 2007, Society of Petroleum Engineers Chapter 9 โ Asphaltenes and Waxes Long X. Nghiem and Bruce F. Kohse, Computer Modelling Group Pgs. 397-464 ISBN 978-1-... * 1.1 Asphaltene-Precipitation Behavior * 1.2 Wax-Precipitation Behavior * 2 Characteristics of Asphaltenes and Waxes * 2.1 Chemical Classification of Petroleum Fluids * 2.2 Asphaltene Characteristics * 2...
Deposition of the high-molecular-weight components of petroleum fluids as solid precipitates in surface facilities, pipelines, downhole tubulars, and within the reservoir are well-recognized production problems. Depending on the reservoir fluid and the type of recovery process, the deposited solid may consist of asphaltenes, waxes, or a mixture of these materials. The deposits also can contain resins, crude oil, fines, scales, and water.[1]
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...al Engineering John R. Fanchi, Editor Copyright 2007, Society of Petroleum Engineers Chapter 9 โ Asphaltenes and Waxes Long X. Nghiem and Bruce F. Kohse, Computer Modelling Group ISBN 978-1-55563-108-6 Get ...pending on the reservoir fluid and the type of recovery process, the deposited solid may consist of asphaltenes, waxes, or a mixture of these materials. The deposits also can contain resins, crude oil, fines, sc...es the experimental measurement and thermodynamic modeling of the phase behavior of solid waxes and asphaltenes in equilibrium with fluid hydrocarbon phases. Models for solid deposition in the reservoir and in p...
Several approaches that use the activity-coefficient model assume the oil and asphaltene as two pseudocomponents: one component representing the deasphalted oil and the other the asphaltenes. Andersen and Speight[69] provided a review of activity models in this category. Other approaches represent the precipitate as a multicomponent solid.
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...can be used to remove asphaltene deposits. Although these methods provide good cleaning and minimal formation damage, their application is limited to the wellbore and does not resolve the problem associated with near...-wellbore formation plugging. Contents * 1 Solvents * 2 References * 3 Noteworthy papers in OnePetro * 4 External...ch as xylene and toluene commonly are used to dissolve asphaltene deposits in both the wellbore and formation. Stricter regulations governing disposals, volatile-emission limits, and flammability concerns have...
Asphaltene precipitation and its subsequent deposition in the wellbore and near-well region are detrimental to oil production. The most effective preventive method is to operate at conditions outside the asphaltene precipitation envelope (APE) (seeAsphaltene precipitation). This is not always possible because of the large drawdown in the vicinity of the wellbore, which lowers the reservoir pressure below the onset pressure. For precipitation in the wellbore, mechanical methods, such as rod and wireline scrapers, can be used to remove asphaltene deposits. Although these methods provide good cleaning and minimal formation damage, their application is limited to the wellbore and does not resolve the problem associated with near-wellbore formation plugging.
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