Fracture Stimulation in Waterflood Fields of Western Siberia: A Case Study of 
Water Prediction and Oil Production Optimization Using Multiphase Reservoir 
Simulation Techniques

Guglielmo, David; Soliman, Mohamed Y.; Kontarev, Roman; Latkin, K. P.; Faizullin, Il'dar

doi:10.2523/98259-ms

Cited by 6 publications

(3 citation statements)

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“…27 In oil fields located outside of Russia, one of the most convincing demonstrations of the benefit of fracture conductivity is in the Kuparuk Field on the North Slope of Alaska. 27 In oil fields located outside of Russia, one of the most convincing demonstrations of the benefit of fracture conductivity is in the Kuparuk Field on the North Slope of Alaska.…”

Section: Comparison To Other Published Resultsmentioning

confidence: 99%

Designing Hydraulic Fractures In Russian Oil And Gas Fields To Accommodate Non-Darcy And Multiphase Flow-Theory And Field Examples

Palisch¹,

Vincent²,

Voronkov³

2006

Proceedings of SPE Russian Oil and Gas Technical Conference and Exhibition

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TX 75083-3836 U.S.A., fax 01-972-952-9435. AbstractNon-Darcy and multiphase flow effects in hydraulic fractures have been well documented during the last several years. The pressure losses due to these phenomena are widely accepted to be of great significance in most gas well completions in the United States and elsewhere. While the importance in gas wells is evident, the authors pose the question of whether non-Darcy and multiphase flow effects are of concern in typical oil wells in Russia.For the analysis, the authors evaluate three primary categories of Russian production wells: gas wells, oil wells producing above the bubble point, and oil wells producing below the bubble point. For each category, the authors describe the significance of non-Darcy and multiphase flow effects using fracture flow theory as well as state-of-the-art fracture production models. This paper will illustrate that non-Darcy and multiphase flow effects can substantially decrease the production potential of gas wells, as well as many of the oil wells found in Russia that are producing below the bubble point.Historically, Russian oil wells have been intentionally operated above the bubble point. However, more aggressive well designs have recently been shown to increase production by over three-fold. The authors explore the economics of producing these wells below the bubble point and show that for these more aggressive strategies, the effects of non-Darcy and multiphase flow can be significant and should be accommodated during fracture design.The authors propose solutions for mitigating these effects through various modifications to the fracture design including the impact of proppant selection on performance. Several operators within Russia have already successfully accounted for these phenomena in their fracture designs, and new field examples are explored, analyzed and presented in the paper. Recent field results are presented for Gazpromneft's Achimovskoya formation BV8 in Tomsk region (Western Siberia) and BP-TNK's field near Buzuluk in the Orenburg region (Volga-Urals). The results found here are compared to published results from the Achimovskoya sandstone in the Kalchinskoye oilfield, the BP12 formation of the Vyngayakhinskoe field, the Priobskoye and Sugmutskoe oilfields, and Gazprom's Yamburskoe gas condensate development.

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Section: Comparison To Other Published Resultsmentioning

confidence: 99%

Designing Hydraulic Fractures In Russian Oil And Gas Fields To Accommodate Non-Darcy And Multiphase Flow-Theory And Field Examples

Palisch¹,

Vincent²,

Voronkov³

2006

Proceedings of SPE Russian Oil and Gas Technical Conference and Exhibition

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“…The production results of jobs using the RPM were compared with results from conventionally fractured wells (Guglielmo et al 2006). The production results of jobs using the RPM were compared with results from conventionally fractured wells (Guglielmo et al 2006).…”

Section: The Importance Of Proper Candidate-well Selection Process (Dmentioning

confidence: 99%

Candidate Selection Process for Fracturing Combined with RPM Treatments for Western Siberia Oilfields Based on Case Studies

Prudnikova

Anashkin

2008

All Days

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Major oil producers in western Siberia widely use hydraulic fracturing to increase recovery from maturing reservoirs. Minimizing the quantity of produced water that typically accompanies increased hydrocarbon production is considered to be of the utmost importance. The traditional approach has been to limit well selection for fracturing treatments to candidates where stimulation can be efficiently performed without a subsequent increase of post-frac water cut. This significantly reduces the desired development of targeted fields.In general, there are two main reasons for water production increase: (1) fracture propagation to water-saturated formations caused by the absence of reliable barriers and (2) phenomenon of water coning caused by pressure drawdown through a highly conductive fracture channel during the exploitation period. To mitigate the problem of post-stimulation water production increase, a relative permeability modifier (RPM) can be applied. The RPM itself is a polymer that can be pumped as a preflush to fracturing treatments or throughout the whole job. Under formation conditions, RPMs decrease the relative permeability of rock (reservoir) to water with almost no effect on the permeability of hydrocarbons. This is crucial to increase the oil-mobility ratio because it allows production of higher oil volumes without unacceptable quantities of associated water production.Several fracturing job RPM treatments have been performed on different oilfields in western Siberia, and not all of them can be considered successful. Both satisfactory and unsatisfactory results were analyzed to classify the major groups of parameters that had the most impact on the final well performance. Based on this data, the candidate selection process for fracturing combined with RPM treatments for western Siberia oilfields should be improved to achieve more desirable treatment results. This paper contains guidelines to select the proper well for this type of treatment and, based on the case study, brings attention to different groups of parameters, related not only to formation properties but also to well preparation process and design criteria, that can significantly affect the final result.

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“…В Ноябрьске и Ханты-Мансийском регионе проводились крупнообъемные ГРП с использованием проппантов типоразмера 12/18 и 8/14, благодаря чему средняя суточная добыча на скважину выросла с 16 тонн до 120 тонн (188 и 888 баррелей в сутки соответственно), а в некоторых случаях до 1000 тонн (7400 баррелей в сутки) 27 .…”

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Designing Hydraulic Fractures In Russian Oil And Gas Fields To Accommodate Non-Darcy And Multiphase Flow-Theory And Field Examples (Russian)

Dedurin¹,

Majar²,

Voronkov³

et al. 2006

SPE Russian Oil and Gas Technical Conference and Exhibition

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Fracture Stimulation in Waterflood Fields of Western Siberia: A Case Study of Water Prediction and Oil Production Optimization Using Multiphase Reservoir Simulation Techniques

Cited by 6 publications

References 0 publications

Designing Hydraulic Fractures In Russian Oil And Gas Fields To Accommodate Non-Darcy And Multiphase Flow-Theory And Field Examples

Designing Hydraulic Fractures In Russian Oil And Gas Fields To Accommodate Non-Darcy And Multiphase Flow-Theory And Field Examples

Candidate Selection Process for Fracturing Combined with RPM Treatments for Western Siberia Oilfields Based on Case Studies

Designing Hydraulic Fractures In Russian Oil And Gas Fields To Accommodate Non-Darcy And Multiphase Flow-Theory And Field Examples (Russian)

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