New Water-Soluble Perforation Ball Sealers Provide Enhanced Diversion in Well Completions

Bilden, D.M.; Lacy, L. L.; Seiler, Fred; Ischy, Noel; Fox, Craig R.

doi:10.2523/49099-ms

Cited by 7 publications

(3 citation statements)

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“…Usually a high-pressure ball catcher is required upstream of the choke to prevent the ball sealers from blocking surface equipment. • Dissolvable (Bilden et al 1998). This type of ball sealer is designed to dissolve after a certain period of time exposed to wellbore fluids or downhole temperatures.…”

Section: Ball Sealersmentioning

confidence: 96%

The Art and Practice of Acid Placement and Diversion: History, Present State and Future

Kalfayan

Martín²

2009

SPE Annual Technical Conference and Exhibition

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With the increasing need for highly cost-effective well production enhancement applications, acid stimulation is becoming increasingly popular. To be successful, acidizing procedures require distribution of stimulation fluids across and within the desired treatment interval. Historically, this has been approached with mechanical placement or chemical diversion of treatment fluids. Method selection can be crucial to treatment success -and an increasing number of options exist -each with its own set of limitations and uncertainties. Preferences and success vary for matrix and fracture acidizing -in vertical and deviated wellbores, in sandstones and carbonates and in cased and perforated, gravel packed, and openhole completions. Method selection and implementation can be daunting but greatly rewarding -calling for creativity and field experimentation.This paper focuses on the important role of acid placement and diversion, and the types, purposes, benefits and pitfalls of the methods currently in practice. The importance of treatment placement was evident and recognized in the earliest acid treatments conducted in the late 19 th century. Although this need has been recognized since the dawn of acidizing, at no point in its history has a diversion method found universal reliability and acceptance. Insufficient interval coverage is perhaps still the most common reason why acid jobs often fail to meet expectations. A well-conceived treatment in all other aspects of design (damage assessment, selection of fluids and additives, and volumes) can count for nothing if the treatment does not enter or cover those portions of the interval with the greatest need of stimulation.Since the first commercial acid treatments in the 1930s, mechanical placement has evolved from crude rubber "packers" to advanced coiled tubing technologies. Chemical and particulate diverters have evolved from chicken feed to specialized chemical systems, including self-diverting fluids. With chemical diversion, different methods have come into and fallen out of favor -replaced by new ideas, or those forgotten and subsequently revived.Within its historical perspective, this paper discusses present-day acid placement and diversion methods, their best applications and their limitations -with a view and emphasis on industry needs and direction for the future.

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Section: Ball Sealersmentioning

confidence: 96%

The Art and Practice of Acid Placement and Diversion: History, Present State and Future

Kalfayan

Martín²

2009

SPE Annual Technical Conference and Exhibition

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“…23,24,25 Different applications require the availability of different ball sealers. Ball sealers have different specific gravities and can be used as either sinkers or floaters.…”

Section: Biodegradable Ball Sealers (Bbs)mentioning

confidence: 99%

Optimizing Matrix Acid Treatments in a multi-layered reservoir in Russia by Applying Different Diversion Techniques

Pongratz¹,

Kontarev²,

Robertson³

2005

Proceedings of SPE European Formation Damage Conference

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe target reservoirs are several limestone layers separated by shales and extend over a vertical height of up to 100 m. The reservoirs are developed differently in almost every well, and natural fractures exist in some, but not in all, wells. The wells are completed with regular 13 3/8-in. casing to around 900 m, 9 5/8-in. casing to around 3400 m, and a 7-in. liner through the reservoir section at around 4100 m. Surface temperatures range from +20°C in summer to -50°C and lower in winter, with bottomhole temperatures (BHTs) around 50°C.Both for producers as well as injectors, a properly designed matrix acid treatment covering the entire reservoir proved to be the most successful production enhancement technique. Most of the wells were completed in a way that allowed the matrix acid stimulation treatments to be conducted in two stages. Both stages covered more than one perforation set. However, for the second stage the job team had to consider that the first stage covering the lower zones was already completed, and fluid would most likely be pumped into this lower zone. The challenge was to provide good diversion over the entire reservoir for one stage and, even more difficult, to divert the majority of the acid into the upper zone for the second stage. In addition, this reservoir oil has relatively high paraffin content, and paraffin deposition, hindering if not eliminating production, will occur below a certain temperature. This fact had to be considered in the matrix acid stimulation design.For a single-stage treatment, or the treatment of the lower zones, a combination of Insitu Crosslinked Acid (ICA) and maximum pressure/maximum rate technique (MPMR) proved to give excellent diversion over these intervals. ICA is a chemical diversion technique. It features a thin, gelled acid with a viscosity of approximately 25 cP that forms a highly viscous crosslinked gel when the acid spends on the formation to a pH of approximately 2. The crosslinked gel can

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“…The presence of crossflow during shut-in can cause a redistribution of the injected slug, resulting in more placement in a lower pressure zone. 12 Methods such as staged diversions, 13,14 zonal isolation 15 or maximised injection pressures have been used to ensure uniform clean-up in such cases, [16][17][18] but these can be time consuming and expensive. Current methods to circumvent these problems often rely on extremely expensive coiled tubing operations, 2,6,8 staged diversion (temporary shut-off) treatments 2,[8][9][10][11] or overdosing some zones to gain placement in other (e.g.…”

Section: Introductionmentioning

confidence: 99%

Simulating Chemical Placement in Complex Heterogeneous Wells

Graham¹,

Stalker²,

Wahid³

2006

Proceedings of SPE International Oilfield Scale Symposium

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New Water-Soluble Perforation Ball Sealers Provide Enhanced Diversion in Well Completions

Cited by 7 publications

References 0 publications

The Art and Practice of Acid Placement and Diversion: History, Present State and Future

The Art and Practice of Acid Placement and Diversion: History, Present State and Future

Optimizing Matrix Acid Treatments in a multi-layered reservoir in Russia by Applying Different Diversion Techniques

Simulating Chemical Placement in Complex Heterogeneous Wells

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