Experimental studies on production performance of oil reservoirs with bottom water

Liu, Changwei; Li, Kewen; Tian, Xiaoming; Zhao, Guoxiang; Chen, Youguang; Mahlalela, Bhekumuzi Mgijimi

doi:10.1016/j.petrol.2018.09.052

Cited by 11 publications

(6 citation statements)

References 11 publications

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“…Wang et al [8][9][10][11] researched the water control technology of horizontal wells completed with AICDs/ICDs in bottom water reservoirs, which was best applied to new wells in the early stages. Li, P. F. et al [12][13][14][15][16] carried out a systematic study of laboratory evaluation on the production performance of oil reservoirs with bottom water and discussed influencing factors of water breakthrough in horizontal wells in reservoirs with bottom water. Sun, G. et al [17][18][19][20] studied horizontal well inhibiting water coning and tapping the potential of the remaining oil by numerical simulation methods, and the results suggest that a reservoir with low vertical permeability and an interlayer above the water-oil contact would have a good effect on water extraction and cone control, providing a good direction for the optimization of target wells for water control and plugging measures.…”

Section: Introductionmentioning

confidence: 99%

Research and Practice on Implementing Segmented Production Technology of Horizontal Well during Extra-High Water Cut Stage with Bottom Water Reservoir

Zhang,

Li,

Zhang

et al. 2024

Processes

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Bohai X oilfield has reached the extra-high water cut stage of more than 95%, dominated by the bottom water reservoir. The oilfield mainly adopts horizontal-well exploitation, with the characteristics of high difficulty and low success rate for well water plugging. To solve the above problem, the segmented production technology of horizontal wells was developed to guide oilfield applications and tap their potential. In the segmented design stage, the horizontal section is objectively segmented by drilling condition analysis, optimally based on drilling through interlayers or permeability discrepancy formation, simultaneously combined with the numerical simulation method. When implementing measures, annulus chemical packer materials are squeezed between segments to effectively inhibit the fluid flow between the open hole and the sand-packing screen pipe. Moreover, the packers are used to seal between segments to effectively restrain the flow between the screen and the central tube, achieving the establishment of compartments. In the production process, the valve switch on the central tube can be independently controlled by a remotely adjustable method to achieve optimal production. This segmented production technology was successfully tested for the first time in Bohai oilfield. Up to now, a total of six compartment measures have been implemented, remarkably decreasing water cut and increasing oil production for horizontal wells in the bottom water reservoir. This method does not require water testing, and the optimal production section can be chosen through segmented independent production, greatly improving the success rate of water-plugging measures for horizontal wells. This technology opens up a new mode for the efficient development of horizontal wells in bottom water reservoirs and is planned to be widely promoted and applied in similar oilfields.

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Section: Introductionmentioning

confidence: 99%

Research and Practice on Implementing Segmented Production Technology of Horizontal Well during Extra-High Water Cut Stage with Bottom Water Reservoir

Zhang,

Li,

Zhang

et al. 2024

Processes

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“…30,41−46 By analyzing real production data from deep-water−oilfields, 50 we seek to refine existing prediction methods. 51 and develop novel approaches tailored to the unique challenges of these environments guidance. 52,53 Our ultimate goal is to enhance the accuracy and reliability of production forecasts in deepwater−oilfields, 54,55 thereby facilitating more effective reservoir management and maximizing hydrocarbon recovery.…”

Section: Introductionmentioning

confidence: 99%

Refined Prediction Method for Production Performance of Deep-Water Turbidite Sandstone Oilfield: A Case Study of AKPO in Niger Delta Basin, West Africa

Kang,

Xiong,

Liu

et al. 2024

ACS Omega

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Deep-water oilfields frequently employ large or superlarge well spacing, leading to significant production dynamics influenced by reservoir factors. Traditional methodologies often disregard these influences, resulting in poor accuracy. Therefore, an enhanced prediction methodology rooted in reservoir characteristics is proposed. This approach introduces the dynamic relative permeability law as a bridge, capturing macroscopic oil/water movement within the reservoir. For the first time, it integrates production dynamics with key controlling reservoir factors, encompassing reservoir architecture, injection-production connectivity, and reservoir heterogeneity. The results indicate that (1) In deep-water turbidite sandstone fields with ultralarge injector-producer well spacings, the distribution of oil−water movement is primarily influenced by reservoir connectivity and heterogeneity. The injection water sweeping ability coefficient can quantitatively describe the water flooding capacity, with a strong negative correlation between the injection water sweeping ability coefficient and interwell nonconnectivity coefficient and reservoir homogeneity coefficient. This suggests that better reservoir connectivity or weaker heterogeneity results in stronger water flooding capacity, leading to a wider range of water flooding under the same injection volume. (2) For regions with strong water flooding capacity (injection water sweeping ability coefficient 0.30−0.80), the water-free production period is the main production stage, with a focus on improving the planar flooding conditions. For regions with poor water flooding capacity (injection water sweeping ability coefficient 0.00−0.10), the middle and late water-cut periods are the main production stages, with a focus on improving interlayer dynamic differences in the later stages. For regions with moderate water flooding capacity (injection water sweeping ability coefficient 0.10−0.30), the initial focus should be on expanding planar flooding, followed by a focus on improving interlayer dynamic differences in the later stages. (3) The dynamic relative permeability law, capable of comprehensively portraying the reservoir's influence on macroscopic oil/water movement, emerges as a rational choice for production performance prediction in such contexts. Our method can improve the accuracy, compared with traditional method without geographical factors, from 45% to 90% during water-cut rising stage and 31% to 81% during production declining stage. The high prediction accuracy (90%) observed in the AKPO oilfields underscores the method's efficacy in directing on-site optimization and adjustments for the development of deep-water turbidite sandstone oilfields.

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“…The results are from the imbalance of gravitational and viscous forces . Therefore, there are two main problems involving horizontal wells in bottom-water reservoirs: one is to effectively decrease the bottom water’s advancing speed and prolong the water-free oil production period, , and the other is to control the degree of water invasion and to realize a high oil recovery factor. − …”

Section: Introductionmentioning

confidence: 99%

Macro- and Microanalysis on Noncondensable Gas Antiwater Invasion in a Bottom Water Reservoir with a Rupturable Interlayer

et al. 2022

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Developing a bottom-water reservoir with rupturable interlayers is a significant challenge. This paper used a 2D visualization model to study the seepage characteristics of gas–water in two phases during noncondensable gas antiwater invasion. On this basis, the mechanisms of antiwater invasion and enhanced oil recovery (EOR) were summarized. The results show that bottom water advances from the crack of the interlayer to the oil layer, leading to a profile of radial flow. The major swept area occupies the scope near the horizontal well and the oil layer’s middle part. Therefore, a lot of remaining oil distributes beside the crack of the interlayer. Noncondensable gas preferentially flows into the water-swept area due to a lower seepage resistance. Under gravity differentiation, the dispersed gas displaces the invaded bottom water downward, inhibiting water from invading and increasing the oil production rate. These studies provide practical guidance for analyzing bottom-water invading processes and designing suitable measures to develop such reservoirs.

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Experimental studies on production performance of oil reservoirs with bottom water

Cited by 11 publications

References 11 publications

Research and Practice on Implementing Segmented Production Technology of Horizontal Well during Extra-High Water Cut Stage with Bottom Water Reservoir

Research and Practice on Implementing Segmented Production Technology of Horizontal Well during Extra-High Water Cut Stage with Bottom Water Reservoir

Refined Prediction Method for Production Performance of Deep-Water Turbidite Sandstone Oilfield: A Case Study of AKPO in Niger Delta Basin, West Africa

Macro- and Microanalysis on Noncondensable Gas Antiwater Invasion in a Bottom Water Reservoir with a Rupturable Interlayer

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