Tip Screenout Fracturing Applied to the Ravenspurn South Gas Field Development

Martins, João Paulo; Leung, K. H.; Jackson, M. R.; Stewart, Donald; Carr, A.H.

doi:10.2118/19766-pa

Cited by 50 publications

(15 citation statements)

References 11 publications

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“…According to Martins et al (1992) the effective conductivity (kf*bfe) [md*ft] is proportional to proppant coverage, gas rate and the non-darcy flow; relating the production of each case and the base with the initial conductivity can be obtained the resulting conductivity in the Equation 17.…”

Section: Resultsmentioning

confidence: 99%

Estudio de la perdida de conductividad debida a empotramiento de propante en formaciones de shale mediante simulación numérica

Cerón

Socha

Montes³

2017

revfue

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Proppant embedment is inherent in reservoir fracking stimulation, this phenomenon occurs when the in-situ stresses are applied to the proppants surface causing their incrustation into the formation. Proppant embedment occasion conductivity, production and money losses, these issues are intensified in unconventional reservoir of shale plays.This work describes geomechanical and compositional factors, which influence on embedment, as well as some embedment models. Fracture conductivity and width loss are studied by reservoir numerical simulation. The software Predict K was use to pre-select the proppant types implemented onto the simulation. The numerical simulation was carried out on a Black Oil simulator: IMEX, from the CMG suite. Embedment fractures are duplicated with a double permeability model for a gas shale play, this considering closure effective stress through permeability and porosity multipliers.In this article were generated conductivity curves that show proppant performance with applied stress in production. Due to shale data scarcity working with the methodology of this work is convenient, the multipliers can replicate geomechanics without high computational effort. Additionally, it is shown mineralogy and geomechanics impacts on shale gas exploitation.Keywords: Geomechanics, Hydraulic fracture, Double permeability model, Porosity multiplayer, Permeability multiplayer. Gas reservoir, Unconventional reservoir.Estudio de la perdida de conductividad debida a empotramiento de propante en formaciones de shale mediante simulación numérica RESUMENEl empotramiento es inherente en la estimulación de yacimientos a través de fracturamiento hidráulico, ocurre cuando los esfuerzos en sitio son aplicados a la superficie de los propantes causando su incrustación en la formación. El empotramiento ocasiona pérdidas de conductividad producción y dinero, intensificándose en yacimientos no convencionales de formaciones de lutitas.Este trabajo describe algunos factores composicionales y geomecánicos que influyen en el empotramiento, así como modelos matemáticos de empotramiento. Se estudia la pérdida de conductividad y ancho de fractura a través de simulación numérica. El software Predick K fue usado para pre-seleccionar los tipos de propante implementados en la simulación. La simulación numérica fue corrida en un simulador de Aceite Negro: IMEX, de la suite CMG. Las fracturas empotradas son simuladas con un modelo de doble permeabilidad para un yacimiento de gas de lutita, considerando el esfuerzo de cierre efectivo mediante multiplicadores de permeabilidad y porosidad.En este artículo se generaron curvas de conductividad que muestran el desempeño del propante con esfuerzos aplicados en la producción. Debido a la escasez de datos de yacimientos de lutita, trabajar con la metodología de este trabajo es conveniente, los multiplicadores pueden replicar la geomecánica sin un alto esfuerzo computacional. Adicionalmente, se muestra los impactos de la mineralogía y geomecánica en la explotación de gas de lutita.Palabr...

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Section: Resultsmentioning

confidence: 99%

Estudio de la perdida de conductividad debida a empotramiento de propante en formaciones de shale mediante simulación numérica

Cerón

Socha

Montes³

2017

revfue

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“…Propped fracturing treatments are designed using aggressive Tip Screen-Out (TSO) type schedules (Martins et al, 1989). These target delivery of average fracture widths on the order of 0.5Љ and are unfailingly under-displaced in order to ensure that the near wellbore conductivity in the soft Tor formation is maximised and retained.…”

Section: )mentioning

confidence: 99%

Improving North Sea Fracturing and Stimulation Economics Through Increasing Innovation and Efficiency in Operations and Applications: Lessons Learned

Ishteiwy¹,

Doghmi²,

Rylance³

2016

Day 2 Wed, February 10, 2016

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Completion and intervention costs across the North Sea are at an all-time high and continue to challenge development economics; this has been exacerbated recently by a deteriorating oil price making costeffective completion and intervention operations even more challenging. Typically at times such as these, the industry turns to the fracturing and stimulation process to maximise the return from existing assets and new wellbores. While this method continues to be feasible, increasingly this can only be achieved through challenging existing conventions and applying increasingly innovative approaches to the principal aspects and assumptions applied to the operations themselves; namely the deployment and the effectiveness of such operations in the field.As the cost of a fracturing and stimulation execution mounts, due to numerous factors, including the efficiency of the service itself, available/economic well intervention capability, provision of sufficient accommodation (somewhat surprisingly/unhelpfully) and an ability to flow-back and clean-up in an efficient and effective manner. This paper will provide examples and case histories, across a number of our North Sea operations, which challenge and optimise each of these areas and demonstrate a number of mechanisms and approaches that have successfully been applied in order to reduce overall costs.Some of the examples include a case history of the use of a boat (stimulation vessel) to boat (intervention vessel) stimulation approach, in order to eliminate secondary rig costs and thereby maximise the economics. Consideration of the use of a rig-based stimulation capability vs. extensive boat operations, efficient and cost effective well recompletion approaches and a suite of incremental improvements born out of continued North American solution development and deployment, such as the use of expandable packers and ball-drop matrix stimulations. Increasing the effectiveness of fracturing and stimulation (and maximising the productivity of each and every individual wellbore) is an obvious approach to improving economics and can be achieved in any number of ways. Again this paper will present a suite of examples and case histories of where this has already been achieved, across a number of our North Sea operations.The current 'perfect storm', of a low oil-price environment combined with high industry contractual costs, is forcing all operators to become increasingly innovative in their pursuit of economic resource development across the North Sea. This paper presents a number of examples of innovation and cost-saving approaches that have been employed in order to achieve such economic intervention and provide further insight into the additional development potential and opportunity that may exist across this varied asset base.

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“…6,7 During the treatment, a tip-screenout is deliberately created to arrest fracture propagation. Continuous pumping of slurry after the screenout at higher pressure has a "ballooning" effect to increase the fracture width so that more proppant can be placed inside the fracture.…”

Section: Criteria For Tip-screenout Designmentioning

confidence: 99%

New Pump Schedule Generator for Hydraulic Fracturing Treatment Design

Desroches

2003

SPE Latin American and Caribbean Petroleum Engineering Conference

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TX 75083-3836 U.S.A., fax 01-972-952-9435. AbstractA typical hydraulic fracturing treatment executes a pump schedule that includes pad fluid volume and proppant stage concentrations. The automatic generation of such a schedule by a computer program is highly desirable. The generation of a pump schedule for hydraulic fracturing is an inverse problem. The fracture length and the proppant distribution inside the fracture are specified as input, together with formation and fluid properties, and a pump schedule generator (PSG) determines the amount of fluid and proppant needed in every stage of the schedule.Ultimately, the PSG is a primary tool to select the means to achieve a desired fracture conductivity within given operational constraints. It a llows to compare all potential options: changing the proppant size, attempting a tip screen out design or changing the fluid system.

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Tip Screenout Fracturing Applied to the Ravenspurn South Gas Field Development

Cited by 50 publications

References 11 publications

Estudio de la perdida de conductividad debida a empotramiento de propante en formaciones de shale mediante simulación numérica

Estudio de la perdida de conductividad debida a empotramiento de propante en formaciones de shale mediante simulación numérica

Improving North Sea Fracturing and Stimulation Economics Through Increasing Innovation and Efficiency in Operations and Applications: Lessons Learned

New Pump Schedule Generator for Hydraulic Fracturing Treatment Design

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