Optimization on fracturing fluid flowback model after hydraulic fracturing in oil well

Qu, Zhanqing; Wang, Jiwei; Guo, Tiankui; Shen, Lin; Liao, Hualin; Liu, Xiaoqiang; Fan, Jia-Cheng; Tong, Hao

doi:10.1016/j.petrol.2021.108703

Cited by 21 publications

(7 citation statements)

References 32 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…As well as carrying out explorations of the combined nature of experiments and mathematical models. , For example, Qu (2022) supplemented the modified proppant settling velocity model based on the original wellhead pressure calculation model through experiments to achieve the accurate calculation of the critical backflow velocity of proppant. The average errors of this model in field tests were 11.9 and 11.6%, respectively . Chen (2021) carried out mathematical modeling of shale water-rock interactions under fracturing fluid retentate conditions, and this model was able to quantitatively analyze the extent of the effects of chemical permeability, clay expansion, and mineral dissolution.…”

Section: Introductionmentioning

confidence: 99%

Correlation between Natural Seepage and Ionic Diffusion in Shales

Yang,

Liu

2024

Energy Fuels

View full text Add to dashboard Cite

The contact between fracturing fluid and shale reservoir induces water-rock reactions such as self-absorption, hydration damage, and ion diffusion, which leads to disturbed reservoir test results and makes it impossible to scientifically formulate extraction plans. Currently, there is a lack of interaction analyses, so we took the shale gas reservoir core in Fuling, Sichuan Basin, as the research object and carried out simultaneous tests of shale self-absorption and conductivity and the correlation between natural seepage and ion diffusion with the help of elemental geochemical measurements. The study concludes that self-absorption and ion diffusion have synchronous response characteristics, and self-absorption develops significantly in the early stage and then tends to stabilize gradually; the presence of cavities or clay-type hydrolysis-prone minerals in the shale pore space leads to a step-like pause in the absorption and conductivity curves at the specific self-absorption time.

show abstract

Section: Introductionmentioning

confidence: 99%

Correlation between Natural Seepage and Ionic Diffusion in Shales

Yang,

Liu

2024

Energy Fuels

View full text Add to dashboard Cite

show abstract

“…As an important basic resource for the prosperity and development of modern industry, petroleum and natural gas play an important role in national development. − The key to the current contradiction between petroleum and natural gas supply demanded goods lies in the exploitation of complex petroleum and natural gas resources such as low permeability, compactness, and even ultra-deep wells. − Hydraulic fracturing is a commonly used method to reform low-permeability petroleum and natural gas reservoirs, but the performance of the fracturing fluid will also directly affect the quality of exploitation. Therefore, it is necessary to develop a water-based fracturing fluid with excellent performance for the exploitation of complex oil and gas fields. − …”

Section: Introductionmentioning

confidence: 99%

Zr, N-Co-Doped Carbon Quantum Dot Crosslinking Agents for Use in Fracturing Fluids

Fan

Duan

et al. 2023

ACS Appl. Nano Mater.

View full text Add to dashboard Cite

To further improve the performance of the fracturing fluid, the Zr, N-co-doped carbon quantum dot nano-crosslinking agent was synthesized by the hydrothermal method to solve the problems of easy agglomeration, instability, and gel breaking after crosslinking of the conventional polyacrylamide fracturing fluid crosslinking agent. The crosslinking agent has good stability and multiple crosslinking sites, as well as can be crosslinked with anionic polyacrylamide (HPAM) solution to form a high-strength hydrogel fracturing fluid. Moreover, it can be used as a nano-fluorescent tracer to test the flowback rate of fracturing fluid. The fracturing fluid composed of 0.3 wt % HPAM and 0.8 wt % crosslinking agent was named as Zr-CDG. At 180 °C, the viscosity of Zr-CDG remains above 180 mPa·s after shearing for 2 h, indicating that Zr-CDG has excellent temperature tolerance and shearing resistance. The residue is only 169 mg/L after gel breaking, which means low damage to the formation. Finally, the backflow process of fracturing fluid is simulated by core displacement. According to the good luminescence of the carbon quantum dot nano-crosslinking agent, the flowback rate of the fracturing fluid is calculated. It shows that the carbon quantum dot nano-crosslinking agent also has the role of fracturing fluid tracer. The results show that the properties of the prepared carbon quantum dot nano-crosslinking agent are more stable, and the performance of the crosslinked fracturing fluid system is greatly improved, which points out a direction for the application of carbon quantum dots.

show abstract

“… 12 Improper adjustment of the flowback rate can cause proppant backflow, reduce fracture conductivity, and even lead to reservoir damage. 13 Pressure drop management has attracted a lot of attention in recent years. Shale gas flow is generally restricted by setting different sizes of nozzles at the wellhead, 14 which decreases the decline rate of wellhead pressure and sacrifices the initial high production to achieve long-term stable production.…”

Section: Introductionmentioning

confidence: 99%

“…Among them, depressurization production means that there is no flow restriction at the wellhead, and the bottom hole flow pressure in the initial production stage is rapidly reduced to the constant pressure of the gas well . Improper adjustment of the flowback rate can cause proppant backflow, reduce fracture conductivity, and even lead to reservoir damage . Pressure drop management has attracted a lot of attention in recent years.…”

Section: Introductionmentioning

confidence: 99%

Pressure Drawdown Management Strategies for Multifractured Horizontal Wells in Shale Gas Reservoirs: A Review

Liu

et al. 2022

ACS Omega

View full text Add to dashboard Cite

The flow capacity of shale gas reservoirs is easily impaired during the depletion process due to strong stress sensitivity. Thereby, an adequate production system, namely, the managed pressure drop method, has been widely introduced to the industrial practice application by decelerating the wellbore pressure drop rate and ultimately improving the long-term production process. This work presents a review of the pressure drawdown management mechanisms for shale gas formations. However, clarifying the water–shale interaction physical chemistry process and developing a mathematical model that accurately describes the water–shale interaction mechanism remain a challenge. Moreover, different classifications of the managed production simulation research approaches are discussed in detail. Each approach has its own merits and demerits. Among them, numerical simulations are commonly seen in cognizance of characterizing the managed pressure drawdown production period but are found to be relatively time-consuming and also computationally expensive. An optimized theoretical model is therefore essential because it can lead to a precise estimation of the ultimate long-term production and capture instantaneously the actual shale gas reservoir depletion phenomenon with various production systems compared to other available methods. The key influence of managed pressured production for single wells in shale reservoirs is elaborated as well. As observed from the current review, an accurate description of the pressure drop management mechanism is crucial for the theoretical model of the pressure control production process for shale gas wells. The influence of water–rock interaction on the managed pressure drawdown mechanism cannot be ignored. There have thus been works to improve and enhance it for use in theoretical models for shale formations. On the other hand, the advancement of theoretical models presents an opportunity for better representation of the managed pressure drop production process.

show abstract

Optimization on fracturing fluid flowback model after hydraulic fracturing in oil well

Cited by 21 publications

References 32 publications

Correlation between Natural Seepage and Ionic Diffusion in Shales

Correlation between Natural Seepage and Ionic Diffusion in Shales

Zr, N-Co-Doped Carbon Quantum Dot Crosslinking Agents for Use in Fracturing Fluids

Pressure Drawdown Management Strategies for Multifractured Horizontal Wells in Shale Gas Reservoirs: A Review

Contact Info

Product

Resources

About