Evaluation of steam injection potential and improving ongoing CO2 injection of the Bati Raman field, Turkey

Babadagli, Tayfun; Sahin, Secaeddin; Kalfa, Ülker; Çelebioğlu, Demet; Karabakal, U.; Topguder, Nazan Necibe Senol

doi:10.1016/j.petrol.2009.06.015

Cited by 16 publications

(8 citation statements)

References 25 publications

(16 reference statements)

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“…In fact, as seen in Fig. 6, all surfactant cases followed a similar trend of recovery, but NaOH revealed less preliminary recovery and then a razor-sharp increase, which could be an evidence of wettability change eventually yielding a higher capillary imbibitions recovery than any other surfactants (Babadagli et al 2008(Babadagli et al , 2009.…”

Section: Chemically Improved Wag Applicationmentioning

confidence: 68%

“…But concentration of additive was slightly increased taking into account the effect of chemical retention and the field pilot was started in 2010. Recognizing through the lab tests that the wettability alteration by NaOH is not an immediate process, the field response is projected to be relatively slow (Babadagli et al 2008(Babadagli et al , 2009). The pH, liquid level and production data were recorded frequently at the neighboring wells.…”

Section: Chemically Improved Wag Applicationmentioning

confidence: 99%

“…At this stage, steam injection is an inevitable alternative for field wide development of the Bati Raman field since thermal diffusion is nearly five times faster than mass diffusion and this makes thermal applications much more favorable in terms of matrix oil recovery from heavy-oil fractured carbonates (Babadagli et al 2008(Babadagli et al , 2009. Although, the heterogeneous structure that causes early breakthrough of injected steam and uneven distribution of the heat is the main challenge in steam injection in carbonates, it is still measured as the only viable course of action for heavy-oil recovery even in challenging circumstances.…”

Section: Plans Aheadmentioning

confidence: 99%

“…5-spot pilot performed in the field in 1969 showed that the displacement type injection in this kind of fractured reservoirs is not feasible. Therefore, it was recommended to use steam as a heating agent rather than a displacement fluid (Babadagli, et al 2008(Babadagli, et al , 2009. Injection of steam into formation from top to heat the reservoir (crestal injection) using vertical communication towards the bottom is an alternative to enhance gravity drainage as suggested earlier (Shahin et al2006;Snell and Close 1999).…”

Section: Plans Aheadmentioning

confidence: 99%

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A Quarter Century of Progress in the Application of CO2 Immiscible EOR Project in Bati Raman Heavy Oil Field in Turkey

Sahin¹,

Kalfa²,

Çelebioğlu³

et al. 2012

All Days

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The Bati Raman field is the largest oil field in Turkey containing approximately 1.85 billion barrels of initial oil in place at an average depth of 4300 ft. The oil is heavy (12 o API) with high viscosity and low solution gas. Primary recovery between 1961 and 1986 was less than 2% of OOIP.The commercial CO 2 -EOR project began in 1986 and is still active. With the implementation of the CO 2 flood, the recovery is expected to potentially reach up to 10% of OOIP.The reservoir rock is naturally fractured carbonate where the heterogeneities and the unfavorable mobility ratio of CO 2 and crude caused inefficient sweep. The solubility of CO 2 in the oil, which is highly sensitive to reservoir operating pressure, was a significant factor for the success of the CO 2 flood. Currently, the injected agent is increasingly bypassing the remaining oil and the production is curtailed by excessive high gas/oil ratio (GOR) severely jeopardizing recovery. These conditions prompted the use of applications of the conformance-improvement systems in the wells in western part of the field.Successful applications of fracture plugging polymer gel system intended for the conformance improvement were carried out in the years of 2002 and 2004. Also, to improve the recovery by a better sweep (or displacement), a chemically augmented water injection process was proposed in the areas having relatively lower reservoir pressure. Chemicals were tested for wettability alteration and IFT reduction to select the best performing ones. After an economic analysis, a field trial of the water alternating gas (WAG) injection process with caustic was put into progress in 2010.Optimized application cases were determined by tuning the total gas injection rates of the field, proration of the individual well rates according to the GOR, investigation of infill drilling, and alteration of the gas injection pattern, based on the results of the simulations carried out in different time frames of the project history.The Bati Raman immiscible CO 2 injection project has been acknowledged as one of the most unique and successful enhanced oil recovery (EOR) applications in the history of fractured heavy-oil carbonate reservoirs. This paper presents a comprehensive overview of this project after a quarter century of experience. IntroductionBased on its in-situ gravity of 12º API and viscosity of 600 cp, the Bati Raman oil is classified as extra heavy. Due to adverse oil properties (12º API viscosity of 600 cp, and low solution gas), low reservoir energy and heterogeneity caused by naturally fractured and vuggy structure, only 1.7 percent of the OOIP corresponding to 32 million STB, was produced prior to CO 2 application. All primary recovery was due to fluid and rock expansion. With a drastic drop of pressure in reservoir after a short period of time the effect of solution gas drive was dwindled. Hence supplemental recovery through EOR was called for. Water drive resulted in insignificant additional oil; consequently, the field was extensively studied for an efficient...

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Section: Chemically Improved Wag Applicationmentioning

confidence: 68%

Section: Chemically Improved Wag Applicationmentioning

confidence: 99%

Section: Plans Aheadmentioning

confidence: 99%

Section: Plans Aheadmentioning

confidence: 99%

See 2 more Smart Citations

A Quarter Century of Progress in the Application of CO2 Immiscible EOR Project in Bati Raman Heavy Oil Field in Turkey

Sahin¹,

Kalfa²,

Çelebioğlu³

et al. 2012

All Days

View full text Add to dashboard Cite

show abstract

“…Steam injection in fractured carbonates is much more challenging and limited to a few field scale applications, mostly at a pilot level (Al-Bahlani and Babadagli 2008;Babadagli et al 2009). The reason behind this is the inefficiency of the steam displacement process due to heterogeneity.…”

Section: Introductionmentioning

confidence: 99%

In-situ recovery of heavy-oil from fractured carbonate reservoirs: Optimization of steam-over-solvent injection method

Al-Gosayir

Babadagli

Leung

et al. 2015

Journal of Petroleum Science and Engineering

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Performance comparison of novel chemical agents in improving oil recovery from tight sands through spontaneous imbibition

et al. 2019

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Tight sands are abundant in nanopores leading to a high capillary pressure and normally a low fluid injectivity. As such, spontaneous imbibition might be an effective mechanism for improving oil recovery from tight sands after fracturing. The chemical agents added to the injected water can alter the interfacial properties, which could help further enhance the oil recovery by spontaneous imbibition. This study explores the possibility of using novel chemicals to enhance oil recovery from tight sands via spontaneous imbibition. We experimentally examine the effects of more than ten different chemical agents on spontaneous imbibition, including a cationic surfactant (C12TAB), two anionic surfactants (O242 and O342), an ionic liquid (BMMIM BF4), a high pH solution (NaBO2), and a series of house-made deep eutectic solvents (DES3–7, 9, 11, and 14). The interfacial tensions (IFT) between oil phase and some chemical solutions are also determined. Experimental results indicate that both the ionic liquid and cationic surfactant used in this study are detrimental to spontaneous imbibition and decrease the oil recovery from tight sands, even though cationic surfactant significantly decreases the oil–water IFT while ionic liquid does not. The high pH NaBO2 solution does not demonstrate significant effect on oil recovery improvement and IFT reduction. The anionic surfactants (O242 and O342) are effective in enhancing oil recovery from tight sands through oil–water IFT reduction and emulsification effects. The DESs drive the rock surface to be more water-wet, and a specific formulation (DES9) leads to much improvement on oil recovery under counter-current imbibition condition. This preliminary study would provide some knowledge about how to optimize the selection of chemicals for improving oil recovery from tight reservoirs.

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Evaluation of steam injection potential and improving ongoing CO2 injection of the Bati Raman field, Turkey

Cited by 16 publications

References 25 publications

A Quarter Century of Progress in the Application of CO2 Immiscible EOR Project in Bati Raman Heavy Oil Field in Turkey

A Quarter Century of Progress in the Application of CO2 Immiscible EOR Project in Bati Raman Heavy Oil Field in Turkey

In-situ recovery of heavy-oil from fractured carbonate reservoirs: Optimization of steam-over-solvent injection method

Performance comparison of novel chemical agents in improving oil recovery from tight sands through spontaneous imbibition

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