Study of massive water huff-n-puff technique in tight oil field and its field application

Qin, Guo‐Wei; Xu, Dekui; Sui, Lei; Geng, Meng; Sun, Lin; Zheng, Yanzhao; Bai, Yanming

doi:10.1016/j.petrol.2020.107514

Cited by 22 publications

(12 citation statements)

References 10 publications

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“…The thermal huff-and-puff method is an effective way for backfilling the formation through liquid/gas media. With the development of the conventional oil and gas industry, numerous alternatives were proposed for specific purposes, such as CO 2 huff-and-puff and microbial huff-and-puff in extra-heavy oil recovery, massive water huff-and-puff in tight oil recovery, and liquid nanofluid huff-and-puff in low permeability reservoirs . The huff-and-puff method has also been adopted to produce natural gas from artificial HBS , in the past decade.…”

Section: Recent Advances In Sand Control Systemmentioning

confidence: 99%

Sand Production Management during Marine Natural Gas Hydrate Exploitation: Review and an Innovative Solution

Chen

et al. 2021

Energy Fuels

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Natural gas hydrate (NGH) is widely distributed worldwide with great reserves and is generally accepted as a promising alternative energy source. However, sustainable, efficient, and safe NGH development has been proven to be restricted by a series of geomechanical problems, among which sand production has become prominent and attention-catching. This review systematically summarizes the up-to-date literatures and reports our latest work to improve the fundamental understandings of the sand production issues in NGH development. It is noted that sand production is defined as a systematic “issue”, rather than a “problem” in this paper, considering both the adverse and favorable influences of sand production on continuous gas production from hydrate-bearing sediment (HBS). Several challenges and insightful suggestions are put forward for future research from the viewpoint of the sand production management system (SMS). Furthermore, an innovative method for unlocking conflicts between sand production and gas extraction in muddy HBS is proposed, namely, the gravel-huff to clay-puff replacement (GCR) technique. The outlook and perspectives of this technique are presented, as well as the key challenges to be resolved.

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Section: Recent Advances In Sand Control Systemmentioning

confidence: 99%

Sand Production Management during Marine Natural Gas Hydrate Exploitation: Review and an Innovative Solution

Chen

et al. 2021

Energy Fuels

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“…Scholars have conducted research on WHP technology in tight oil reservoirs, including applicable conditions, oil recovery mechanisms, and influencing factors. − However, the following problems still exist. (1) There are very few physical simulation experiments for oil recovery by WHP in tight oil reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Study on Influencing Factors of Water Huff-n-Puff Oil Recovery in Matrix-Fracture Systems of the Tight Sedimentary Tuff Reservoirs

Yang

Jin

et al. 2022

ACS Omega

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Tight sedimentary tuff reservoirs (TSTRs) are a new type of tight oil reservoirs, which are mainly developed by water huff-n-puff (WHP). However, there is no quantitative study on the effect of water injection pressure (WIP) and fracture density (FD) on the oil recovery effect of WHP, and the reasons for the low flow-back rate (FR) of the injected water are also not fully explained. In this study, the real cores of TSTRs were used to simulate the seepage state of the matrix-fracture systems of the reservoir, the effects of WIP and FD on the WHP were quantitatively studied, and the reasons for the low FR of the injected water were comprehensively analyzed. The result shows that in five cycles of WHP, the recovery factor (RF) of the core only increases from 8.72 to 10.91% with the WIP increasing from 25 to 30 MPa. However, when the WIP is 40 MPa (rock breakdown pressure), the RF of the core reaches 16.47%, indicating that overfracture-pressure water injection has an obvious improvement effect on the oil recovery effect of WHP in TSTRs. Increasing the FD can also significantly improve the RF and oil recovery efficiency (ORE) of WHP in TSTRs. When the FD of the core increases from 0.34 to 0.44 cm –1 , the RF of five cycles of WHP increases by 9.26%, the ORE increases by 8.61%, and the FR of the injected water decreases by 0.56%. The reasons for the low FR of the injected water in WHP in tight oil reservoirs are matrix water locking, fracture water locking, and reservoir nonconstant-volume water locking. The study can provide an important reference for the efficient development of the WHP in TSTRs.

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“…Thus, the efficient development of the conventional reservoir using water injection cannot be realized . The technology of spontaneous imbibition has been used to achieve a significant effect during the active water huff and puff of the oilfield site. − To better play the role of spontaneous imbibition, it is necessary to carry out research on the influencing factors and laws of spontaneous imbibition. , …”

Section: Introductionmentioning

confidence: 99%

Mechanisms of Spontaneous Imbibition and Wettability Reversal of Sandstone Cores by a Novel Imbibition Agent

et al. 2022

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The basic performance of a novel high-efficiency spontaneous imbibition agent (SXJ-2) was investigated in this study. The mechanisms of spontaneous imbibition and wettability reversal of an oil-wet sandstone surface (OSS) by SXJ-2 were studied by infrared (IR) analysis, scanning electron microscopy (SEM), zeta potential determination, wetting angle experiment, and spontaneous imbibition determination in this work. The interfacial tension between oil and water for the SXJ-2 system is relatively low. SXJ-2 has a better performance than other systems in altering the surface wettability and has a higher imbibition recovery under the same time interval than the other systems. Spontaneous imbibition recoveries of cores with high permeability are greater than that of cores with low permeability for the same surfactant solution. Spontaneous imbibition recoveries decrease as the surfactant concentrations decrease, and the spontaneous imbibition recovery is the highest when the concentration is fixed at 0.5 wt %. The higher the initial water saturation the lower the spontaneous imbibition recovery is. The ultimate imbibition recoveries of cores increase with the decrease of core length. The spontaneous imbibition recovery at room temperature is higher than that at 80 °C. At the initial and later stages of imbibition, the experimental process is controlled by capillary force and gravity, respectively. While at the intermediate stage, the process of imbibition is jointly controlled by capillary force and gravity. The absorption peak at 1170 cm–1 is caused by the sulfone −SO2– stretching vibration, indicating that the surfactant molecule SXJ-2 is adsorbed on the surface of sandstone. Due to the adsorption of the surfactant SXJ-2 on the rock surface, the size of asphaltenes was reduced, rendering the solid surface more water-wet. Thus, the mechanism of the wettability reversal of the OSS by SXJ-2 was indirectly verified by IR analysis and SEM scanning.

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Study of massive water huff-n-puff technique in tight oil field and its field application

Cited by 22 publications

References 10 publications

Sand Production Management during Marine Natural Gas Hydrate Exploitation: Review and an Innovative Solution

Sand Production Management during Marine Natural Gas Hydrate Exploitation: Review and an Innovative Solution

Study on Influencing Factors of Water Huff-n-Puff Oil Recovery in Matrix-Fracture Systems of the Tight Sedimentary Tuff Reservoirs

Mechanisms of Spontaneous Imbibition and Wettability Reversal of Sandstone Cores by a Novel Imbibition Agent

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