Abstract:A screening study and subsequent chemical EOR application pilot strategy for a complex, low-permeability waterflood is presented. Our focus has been on developing appropriate field application options allowing flexibility of operation against a background of reservoir complexity and uncertainty.
Australia's Barrow Island Windalia reservoir, the nation's largest onshore waterflood, was developed in the late 1960's. Cumulative oil production to date is approximately 288 MMSTBO. Planning a chemi… Show more
“…Despite the volatility of oil prices, it is fair to conclude that operators are showing a growing interest on chemical EOR flooding. This trend is also supported by the increase of screening studies to evaluate or re-estimate the EOR potential of chemical flooding in different basins (Alvarado et al 2008;Costa et al 2008;Fletcher and Morrison, 2008;.…”
Section: Chemical Eor In Sandstone Reservoirsmentioning
Surfactant-polymer (SP) flooding is an enhanced oil recovery (EOR) technique used to mobilize residual oil by lowering the oil-water interfacial tension, micellar solubilization, and lowering the displacing phase mobility to improve sweep efficiency. Surfactant-polymer flooding, also known as micellar flooding, has been studied both in the laboratory and field pilot tests for several decades. Surfactant polymer flooding is believed to be a major enhanced oil recovery technique based on laboratory experiments; however, its applications to field has not met the expectations of laboratory results. Successful field applications of SP flooding have been limited because of a number of obstacles, which include the large number of laboratory experiments required to design an appropriate SP system, high sensitivity to reservoir rock and fluid characteristics, complexity of reservoirs, infrastructure required for field implementation, and lack of reliable statistics on successes of field applications. In other words, there are many variables that affect reservoir performance. Traditionally, in SP flooding, a tapered polymer solution follows the injected surfactant slug. However, in recent years co-injection of surfactant and a relatively high concentration of polymer solution have been used in several field trials. Despite significant increase in oil recovery at early times in several surfactant-polymer floods, the increase in oil production period has had short duration followed by significant reduction in oil production. Thus, this research primarily relied on field test data to understand the problem, hoping that an improved solution strategy can be developed for new field applications. Second, current numerical models do not correctly predict the performance of surfactant-polymer floods and tend to over predict. Thus the second objective of this research was to develop a methodology to use combined field and laboratory data in commercial simulators to improve their predictive capability. iv TABLE OF CONTENTS
“…Despite the volatility of oil prices, it is fair to conclude that operators are showing a growing interest on chemical EOR flooding. This trend is also supported by the increase of screening studies to evaluate or re-estimate the EOR potential of chemical flooding in different basins (Alvarado et al 2008;Costa et al 2008;Fletcher and Morrison, 2008;.…”
Section: Chemical Eor In Sandstone Reservoirsmentioning
Surfactant-polymer (SP) flooding is an enhanced oil recovery (EOR) technique used to mobilize residual oil by lowering the oil-water interfacial tension, micellar solubilization, and lowering the displacing phase mobility to improve sweep efficiency. Surfactant-polymer flooding, also known as micellar flooding, has been studied both in the laboratory and field pilot tests for several decades. Surfactant polymer flooding is believed to be a major enhanced oil recovery technique based on laboratory experiments; however, its applications to field has not met the expectations of laboratory results. Successful field applications of SP flooding have been limited because of a number of obstacles, which include the large number of laboratory experiments required to design an appropriate SP system, high sensitivity to reservoir rock and fluid characteristics, complexity of reservoirs, infrastructure required for field implementation, and lack of reliable statistics on successes of field applications. In other words, there are many variables that affect reservoir performance. Traditionally, in SP flooding, a tapered polymer solution follows the injected surfactant slug. However, in recent years co-injection of surfactant and a relatively high concentration of polymer solution have been used in several field trials. Despite significant increase in oil recovery at early times in several surfactant-polymer floods, the increase in oil production period has had short duration followed by significant reduction in oil production. Thus, this research primarily relied on field test data to understand the problem, hoping that an improved solution strategy can be developed for new field applications. Second, current numerical models do not correctly predict the performance of surfactant-polymer floods and tend to over predict. Thus the second objective of this research was to develop a methodology to use combined field and laboratory data in commercial simulators to improve their predictive capability. iv TABLE OF CONTENTS
“…For example, the laboratory evaluation of Windalia polymer flood reported the emulsion formation tendencies between the reservoir oil and different injection brines. Fletcher and Morrison (2008) reported in their study that higher salinity (TDS = 38,000 ppm) brine showed less emulsification tendencies than lower salinity (TDS = 29,000 ppm) injection brine. However, it is not clear if high polymer retention (≥130 mg/g of rock) and RRF (8 to 45) values reported in this study are due to low permeability (1.0 -13.8 mD) of the reservoir core plugs used and/or the emulsification of oil-waterpolymer in-situ during the corefloods.…”
Section: Summary Discussionmentioning
confidence: 93%
“…Windalia field (Fletcher and Morrison, 2008;Haynes, Clough, Fletcher &Weston, 2013) is a high clay content sandstone and low permeability light oil (36°API) reservoir (65°C) in Australia. Windalia reservoir has an OOIP of 819 MMbbls and it is under line-drive water injection since 1967 reporting a recovery factor of 37%.…”
Polymer flooding has been the most widely used chemical enhanced oil recovery (EOR) method. The experience gained over the past decades from laboratory studies to project design and field implementation has been well documented in the literature. The main objectives of this paper are to evaluate recent observations of polymer floods that report injection rates leading to pressure values above the formation fracture pressure (FFP), high polymer production, formation of tight emulsions and/or productivity losses.Based on this review, it can be concluded that no direct evidence exists to support that injecting polymer above the FFP will lead to more polymer production. However, uncertainties associated with the estimation of fracture propagation/dimensions using pressure Fall-Off Tests (FOT) still remain. High polymer production, other than severe channeling, is generally reported in large scale/commercial projects. The impact of oil geochemistry/ composition and water salinity on oil-water-polymer emulsions is commonly overlooked in polymer flood studies. The formation of in-situ emulsions can also explain the injectivity and/or productivity reduction and well test interpretation (i.e. FOT) reported in polymer floods. It was also identified that the OPEX (Operational Expenditures) associated with oil-water separation in the presence of polymer and productivity losses (i.e. workovers, stimulation costs) are generally underestimated. Finally, this review is expected to contribute with the planning, design and implementation of future polymer flood pilots and field expansions.
OBSERVACIONES HISTÓRICAS Y RECIENTES EN INYECCIÓN DEPOLÍMEROS: REVISIÓN ACTUALIZADA.
OBSERVAÇÕES HISTÓRICAS E RECENTES DE INJEÇÃO DE POLÍMEROS:REVISÃO ACTUALIZADA. EDUARDO MANRIQUE et. al. 18 L a inyección de polímeros es el método químico de recobro mejorado con mayor número de implementaciones a escala de campo. La experiencia adquirida en las últimas décadas desde estudios de laboratorio hasta el diseño e implementación de campo ha sido bien documentada en la literatura. El objetivo principal de este trabajo es evaluar observaciones recientes de proyectos de inyección de polímero reportando tasas de inyección por encima de la presión de fractura de la formación, alta producción de polímero, formación de emulsiones viscosas y/o pérdidas de productividad.Basados en esta revisión, se puede concluir de que no existen evidencias directas de que la inyección de polímero a tasas que impliquen superar la presión de fractura induzcan a una mayor producción de polímeros. Sin embargo, existen incertidumbres relacionadas con la estimación de las dimensiones y propagación de fracturas utilizando pruebas de caídas de presión (FOT). La alta producción de polímero, por razones diferentes a canalizaciones severas, generalmente se reportan en proyectos a escala comercial. Por otra parte, el impacto de la composición y geoquímica del crudo y de la salinidad del agua en la formación de emulsiones agua:petróleo:polímero ha sido subestimado en estudios de in...
“…Therefore and despite the volatility of oil prices, it is fair to conclude that operators and surfactant manufacturers are showing a growing interest in EOR chemical flooding [132,133]. This trend is also noticed with an increase of screening and lab studies to evaluate or re-estimate EOR potential of chemical flooding in different basins [134][135][136][137][138][139][140][141].…”
With the decline in oil discoveries during the last decades it is believed that EOR technologies will play a key role to meet the energy demand in years to come. This paper presents a comprehensive review of EOR status and opportunities to increase final recovery factors in reservoirs ranging from extra heavy oil to gas condensate. Specifically, the paper discusses EOR status and opportunities organized by reservoir lithology (sandstone and carbonates formations and turbiditic reservoirs to a lesser extent) and offshore and onshore fields. Risk and rewards of EOR methods including growing trends in recent years such as CO 2 injection, high pressure air injection (HPAI) and chemical flooding are addressed including a brief overview of CO 2 -EOR project economics.
scite is a Brooklyn-based organization that helps researchers better discover and understand research articles through Smart Citations–citations that display the context of the citation and describe whether the article provides supporting or contrasting evidence. scite is used by students and researchers from around the world and is funded in part by the National Science Foundation and the National Institute on Drug Abuse of the National Institutes of Health.