Simulation Study of Miscible Gas Injection for Enhanced Oil Recovery in Low Permeable Carbonate Reservoirs in Abu Dhabi

Vark, W. van; Masalmeh, Shehadeh K.; Dorp, Johan van; Nasr, Mohamed; Al-Khanbashi, S.

doi:10.2118/88717-ms

Cited by 9 publications

(5 citation statements)

References 10 publications

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“…The results demonstrated a distinct pattern of reservoir response to acid gas injection, showing an increase in reservoir pressure and, thus, in oil production over time. These findings align with previous simulation studies that have highlighted the efficiency of acid gas injection in improving recovery rates in sour reservoirs [45][46][47], as well as with past field experience, such as the Zama field in Canada [48], the Tengiz oilfield in Kazakhstan [28,49] and the ARF and GAF fields located in the Gulf Arab region [28], endorsing the fact that acid gas re-injection can serve as an effective EOR technique.…”

Section: Discussionsupporting

confidence: 89%

Prospects of an Acid Gas Re-Injection Process into a Mature Reservoir

Kanakaki,

Samnioti,

Koffa

et al. 2023

Energies

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This study provides insights into the experience gained from the investigation of the dynamic behavior of a mature sour hydrocarbon reservoir modeling under an acid gas re-injection process production strategy. The primary objective was to analyze and evaluate the production behavior of proposed injection zones by assessing various injection scenarios and obtaining oil production over time. To achieve that, a workflow was developed to prioritize potential injection areas, select the optimal wells, determine the optimal operational parameters and optimize a pilot application design based on expected performance. Within this framework, the study encompasses diverse acid gas injection schemes on a pilot scale approach, including acid gas combined with waterflooding. The outcome of this analysis will eventually lead to the identification of the most promising and highest-performing injection scheme, elucidating the optimal range of operating parameters. This optimal combination forms the basis for the economic analysis of the venture and the subsequent detailed design of a full-scale application, where real-world implementation will validate the projected results.

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Section: Discussionsupporting

confidence: 89%

Prospects of an Acid Gas Re-Injection Process into a Mature Reservoir

Kanakaki,

Samnioti,

Koffa

et al. 2023

Energies

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“…Forouzanfar et al (2010) developed a two-stage well placement optimization method, employing a gradient-based algorithm with the adjoint method and gradient projection for constraints, effectively determining the optimal number, locations, and rates of water injection and producing wells, while mitigating the effects of pre-specifying well rates and operational reservoir life. Taware et al (2012) utilized a novel method based on streamline simulation and total time of flight calculations to optimize well placements in a mature offshore carbonate field, outperforming traditional well placement techniques and successfully validating the approach with subsequent field infill drilling. Deng et al (2010) implemented a comprehensive approach integrating proactive well placement technology, thorough rock physics and petrophysics studies, geomechanical analysis, and real-time interpretation and reservoir simulation, successfully enhancing productivity beyond initial predictions for horizontal wells in the complex offshore field of Bohai Bay.…”

Section: Techniques Advantage Disadvantagementioning

confidence: 99%

Horizontal well placement optimization based on matrix directional continuous element summation algorithm

Huang,

Wang,

et al. 2024

Front. Energy Res.

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During the course of actual oilfield development, judicious selection and design of well placement are paramount due to cost constraints and operating conditions. This paper introduces the Matrix Directional Continuous Elements Summation Algorithm (MDCESA), which is utilized to identify that segment with the largest summation for a given length in a 2D or a 3D matrix. An additional function that accounts for the distance between segments was added when searching for multiple segments to avoid intersections or overlaps between segments. The well placement optimization was transformed into a segment summation on a 3D matrix. Our findings reveal significant advancements in well placement optimization. Employing the MDCESA method, six producers were identified and their production performance was compared against two previously selected producers using a reservoir numerical simulator. The results demonstrated that the wells selected through MDCESA exhibited a substantial improvement in production efficiency. Specifically, there was an 11.6% increase in average cumulative oil production over a 15-year period compared to the wells selected by traditional methods. This research not only presents a significant leap in well placement optimization but also sets a foundation for further innovations in reservoir management and development strategies in offshore oilfields.

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“…Miscible gas such as carbon dioxide (CO2) has been proving to increase the recovery factor of unconventional shale oil reservoirs [8,20,21]. Benefits of using CO2 as the injectant for shale oil recovery are stated as follows [20]:…”

Section: Introductionmentioning

confidence: 99%

Pressure Transient Behavior of Horizontal Gas Injection Well in Low Permeable Reservoirs

Wen,

Habte

2023

Unconventional Methods for Geoscience, Shale Gas and Petroleum in the 21st Century

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This work addresses the pressure transient behavior of horizontal gas injection well in low permeable reservoirs. Low permeable reservoirs such as shale oil reservoirs have been receiving great attentions lately which normally require hydraulic fracturing and horizontal well development to maximize the oil production. However, the primary recovery factor of shale oil reservoirs is still low and has been estimated to be below 10–15% due to tight nature of the shale formations. Enhanced oil recovery method such as miscible carbon dioxide (CO2) injection is said to be one of the most efficient and effective methods used to increase the oil recovery factor of a low permeable shale oil reservoir. The objective of this paper is to study the pressure transient behavior of the horizontal gas injection well in low permeable shale oil reservoirs using numerical simulator, CMG-GEM. Flow regimes and its significant reservoir parameters are investigated from the log-log plot of pressure-derivatives. It is found that a unit-slope line is developed on pressure-derivative log-log plot at early time due to the gas compressibility effect, followed by early radial flow and early linear flow regimes. The effect of various parameters such as gas injection rate, duration of gas injection, well location and well perforation length are studied and analyzed on the changes of pressure transient characteristics. It is identified that gas injection rate affects the pressure-derivative response significantly at middle time due to gas mobility and viscosity; whereas well location and well perforation length affect the late time pressure-derivative response which relate to dominant boundary effect; however, duration of gas injection is not able to show or prove any impacts on the pressure-derivative behavior due to numerical instability issue. Reservoir characteristics such as average permeability and skin can be identified from the flow regimes equations similar to the horizontal production well.

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Simulation Study of Miscible Gas Injection for Enhanced Oil Recovery in Low Permeable Carbonate Reservoirs in Abu Dhabi

Cited by 9 publications

References 10 publications

Prospects of an Acid Gas Re-Injection Process into a Mature Reservoir

Prospects of an Acid Gas Re-Injection Process into a Mature Reservoir

Horizontal well placement optimization based on matrix directional continuous element summation algorithm

Pressure Transient Behavior of Horizontal Gas Injection Well in Low Permeable Reservoirs

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