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Channel Fracturing Extension to Low-Temperature Formations. Field Case Studies in Russia.
Yudin, Alexey (Schlumberger) | Glaznev, Ivan (Schlumberger) | Lyapunov, Konstantin (Schlumberger) | Loznyuk, Oleg (Rosneft) | Korolev, Alexandr (Rosneft) | Khamidov, Timur (Rosneft) | Prokhorov, Alexey (Rosneft) | Rylance, Martin (BP Exploration)
Abstract Channel fracturing technology has been a key enabler to unlocking hydrocarbon production from low-permeability formations in Russia for 10 years, by minimizing treatment costs and improving operational efficiency. However, an intrinsic limitation existed for candidate selection because the technique requires post-job dissolution of the fiber that is a principal component of the success of achieving efficient channel fracturing behavior. This set a lower temperature limitation of 60°C, such that formations with temperatures below this value were not recognized as potential candidates. This project was aimed at eliminating the temperature limitation and thereby enhancing the potential candidate pool for application. The channel fracturing technique creates infinite-conductivity channels within a fracture, using a proppant-pulsing technique delivered by the surface equipment. Proppant structures are consolidated and transported along the fracture by means of fibrous material, which then degrades in the channels and proppant pillars within days after the treatment, conventionally because of the high formation temperature. Expanding hydraulic fracturing into new low-temperature oil provinces such as Eastern Siberia and the Turonian formation in the Yamal region called for adjustment in the channel fracturing technique. Specifically, surface equipment was used in a modified mode to alter the pumping schedule of the fiber additive to add fiber in pulses that are synchronized with proppant pulses. The new channel fracturing methodology was designed and tested under laboratory conditions initially and then subsequently applied in several low-temperature (20 to 30°C) oil and gas fields/wells in Russia. The first campaign yielded positive results. New software and equipment adjustments allowed for precise and accurate synchronization that resulted in fiber-free channels. The first productivity results also illustrated the potential of the technology to match or exceed the planned hydrocarbon production. The main advantages of the channel fracturing technique remained unchanged—improved barrels/dollar ratio by up to 10% compared with conventional methods and fracturing cycle operational efficiency reduction of up to 25% as compared with standard techniques. Thus, the temperature limitation was removed, leaving one major criterion for channel fracturing applicability: rock competency to hold channels open and stable throughout the life of the fracture. The study breaks new ground in the stimulation of low-temperature formations by extending the channel fracturing technique, well-recognized in the traditional basins of Russia. The project includes laboratory testing and real field examples from two regions of Russia—the first campaigns.
- Europe > Russia (1.00)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District (0.29)
- North America > United States > Texas > Dawson County (0.24)
- Europe > Russia > Northwestern Federal District > Barents Sea > Pechora Sea > Timan-Pechora Basin > Prirazlomnoye Field (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Nadym-Pur-Taz Basin > Block V > Urengoyskoye Field > Achimov Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Nadym-Pur-Taz Basin > Block IV > Urengoyskoye Field > Achimov Formation (0.99)
- (4 more...)
Abstract To provide designed oil production and to minimize non-productive time new approaches in hydraulic fracturing have been tried and introduced for several years in Uvat project. During this optimization process, several new technologies were pilot tested including fiber-laden fluid, rod-shaped proppant and channel fracturing technique. The main goal was to improve fracturing fluid reliability and to decrease the risk of premature screen-outs in combination with more aggressive fracturing design to maximize oil production. Uvat project oil field is located in Western Siberia. Jurassic formation is the main oil producer from the field, presented by significant net height (up to 45 m), relatively high permeability which varies in wide range from 2 md to more than 50 mD. The formation temperature is 80-90°C. The requirements to fracture geometry is gradually increase in these conditions. The greater fracture width must be accompanied with sufficient effective fracture half-length. This goal cannot be achieved with standard hydraulic fracturing techniques because of limitations in proppant pack conductivity. Besides, the more aggressive design is associated with the higher risk of premature job screen-out that consequently results in non-productive time. Paper describes the results of pilot projects for the following new technologies introduction: fibers that allow better proppant distribution in the fracture and decrease polymer concentration without sacrificing proppant transportation ability of the fluid (the new generation of fibers was implemented which is for low temperature formation); rod-shaped proppant to prevent particles flowback and to increase fracture conductivity; channel fracturing technology that allows to decrease treatment costs and risk of premature screen-out while keeping or even increasing the flow capacity of the fracture. In channel fracturing application a proppant is added in short pulses alternated with clean fluid pulses. This becomes even more vital in remote locations as the same stimulation result can be achieved with less proppant amount replaced by clean fluid pulses that leads to decrease in spending on logistics and time optimization for fracturing job. The manuscript describes the candidate selection methods for re-fracturing jobs and states the main success criteria (such as presence of formation energy and current skin calculation). The authors represent comparative analysis of horizontal wells and multistage fracturing effectiveness in low productive regions resulted in high incremental oil rate when compared to vertical wells with a single fracture.
- Europe (1.00)
- Asia > Russia > Ural Federal District > Tyumen Oblast (1.00)
- North America > United States (0.68)
- Europe > Russia > Volga Federal District > Orenburg Oblast > Volga Urals Basin > Tsarichanskoye Field (0.99)
- Asia > Russia > Ural Federal District > Tyumen Oblast > West Siberian Basin > Ust-Tegussky License Area > Uvat Fields (0.99)
- Asia > Russia > Ural Federal District > Tyumen Oblast > West Siberian Basin > Ust-Tegussky License Area > Ust-Tegusskoye Field (0.99)
- (17 more...)
First Channel Fracturing Applied in Mature Wells Increases Production from Talinskoe Oilfield in Western Siberia
Kayumov, Rifat (Schlumberger) | Klyubin, Artem (Schlumberger) | Yudin, Alexey (Schlumberger) | Enkababian, Philippe (Schlumberger) | Leskin, Fedor (TNK-BP) | Davidenko, Igor (TNK-BP) | Kaluder, Zdenko (TNK-BP)
Abstract In the last two decades, hydraulic fracturing has become a routine completion practice in most oilfields producing from the low- and medium-permeability Jurassic formations in western Siberia. To optimize hydraulic fracture conductivity, operators and service companies were progressively decreasing polymer loading in fracturing fluids, developing new polymer-free fluids, implementing foams as fracturing fluids, increasing proppant size and concentration, enhancing polymer breaker performance, increasing breaker concentration, and implementing the tip screenout technique. All these methods have some positive impact on proppant pack conductivity but lead to higher risk of premature screenout. The intrinsic limitations stem from the fact that conductivity is created by the proppant pack, which physically limits permeability. The new channel fracturing technique allows development of an open network of flow channels within the proppant pack; thus, the fracture conductivity is enabled by such channels rather than by flow through the pores between proppant grains in the proppant pack. The channel fracturing technique is capable of increasing fracture conductivity by up to two orders of magnitude. Talinskoe field, located near Nyagan, Russia, produces from a series of Jurassic sublayers at depths of 2270 to 2700 m. Several oil-saturated sandstone sublayers are separated by shale barriers, and their development is conducted separately. For some wells, production from bottom sublayers JK10 and JK11 became uneconomical due to injection water breakthrough or low liquid rates. Production in these wells was switched to upper layers JK2 through JK9 after perforation and stimulation operations. Five of these wells were stimulated with the channel fracturing technique. Six-month of post-frac production data were compared with production data from eight offset wells stimulated recently via conventional hydraulic fracturing. The wells stimulated with the channel fracturing technology showed an average productivity index about 51% higher. This production effect still remains positive. The absence of screenouts confirmed reliability in proppant placement observed in other projects worldwide. The successful implementation of the channel fracturing technique in brownfield development is described in detail with a theoretical and operational review, results from laboratory experiments, and analysis of the production results in comparison with conventional fracturing.
- Europe (1.00)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug (1.00)
- North America > United States > Texas (0.94)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.34)
- North America > United States > Wyoming > Green River Basin > Jonah Field (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- (10 more...)
Implementation of Relative Permeability Modifiers in Krasnoleninskoe Oil Field: Case Histories
Parkhonyuk, Sergey (Schlumberger Oleg Sosenko) | Levanyuk, Olesya (Schlumberger Oleg Sosenko) | Oparin, Maxim (Schlumberger Oleg Sosenko) | Sadykov, Almaz (Schlumberger Oleg Sosenko) | Mullen, Kevin (Schlumberger Oleg Sosenko) | Lungwitz, Bernhard (Schlumberger Oleg Sosenko) | Enkababian, Philippe (Schlumberger Oleg Sosenko) | Mauth, Kevin (Schlumberger Oleg Sosenko) | Alexander, Karpukhin (TNK-BP.)
Abstract Excess water production is a major concern for Russian oil companies. Maturing fields are producing at ever-increasing water cut resulting in problems such as the cost of disposal and environmental issues. In recent years, operators have shown a rising interest in Relative Permeability Modifiers (RPMs) as a potential solution to reduce water production. RPMs are designed to disproportionately reduce the relative permeability to one phase (water) over the oil phase. RPMs are a preventive approach to reduce water production. Ideally, they should completely block water flow without affecting oil flow. While RPMs are used worldwide, they must be adjusted to the reservoir conditions. This becomes even more important in the case of hydraulic fracturing of formations with nearby water-saturated layers. Commonly, service companies recommend one type of RPM which fits all reservoirs. This paper demonstrates how RPM selection on reservoir cores is critical for successful application in the field. We describe laboratory testing and review field trial results of RPMs in a low permeability (2 to 14 mD), highly laminated formation. Because RPMs are typically used only in high-permeability reservoirs, this application is unique. We evaluated chemically different RPMs on actual core material and found strong performance variations of the tested RPMs. We selected a suitable RPM following both core flow testing and compatibility testing. For the field test, wells in the Krasnoleninskoe oilfield were selected for RPM treatments. Oil production was increased in most cases while the water cut was reduced or only slightly increased by up to 5% during 6 months following the treatment. These results show that with proper evaluation, RPMs can also be successfully used in low-permeability reservoirs. We demonstrated also that otherwise proven successful RPMs may not fit every reservoir and proper evaluation and monitoring is critical for success.
- North America > United States (1.00)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug (1.00)
- Research Report > Experimental Study (0.48)
- Research Report > New Finding (0.34)
- Geology > Mineral (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.46)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin (0.99)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Talinskoye Field (0.99)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Central Basin > Kamenny License > Krasnoleninskoye Field (0.99)
- (15 more...)