bluuebunny/crossref_metadata_2025_split huggingface dataset:
Comparative Study of Proppant Transport in the Vertical Fracture for High Viscosity Friction Reducers and Slickwater Fracturing with High-TDS Marcellus Shale Formation Water
Authors: Ge Xiaojing , Imqam Abdulmohsin , Bai Baojun 
Published: September 2023

ABSTRACT
High viscosity friction reducers (HVFRs) have been gaining more attention and increasing in use as proppant carriers. Reusing of produced water has also been driven by both environmental and economic benefits. However, high total dissolved solids (TDS) of produced water and high reservoir temperature significantly decrease the viscoelastic properties of HVFRs even for the cationic ones, which further reduce their proppant transport capabilities. Increasing loadings of HVFRs also has very limited effects on improving their proppant transport performances under high-TDS and high-Temperature conditions. The ultimate objective of this experimental study is to investigate the injection rate effects on the proppant transport performance of HVFRs, especially under high-TDS conditions. 1 gallon per thousand gallons (GPT) slickwater and 4 GPT HVFRs were comparatively analyzed by conducting rheology measurements and dynamic proppant transport experiments with both deionized (DI) water and 30,000 mg/L TDS Marcellus formation water at 60°C. The 1 GPT slickwater was injected at a rate of 1.5 gal/min, whereas the 4 GPT HVFR was injected at a lower rate of 0.75 gal/min. The results showed that HVFRs with low injection rates were preferred when using fresh water. In contrast, slickwater with high pumping rates was preferred during produced water fracturing.

INTRODUCTION
Over the past few years, the use of HVFRs in hydraulic fracturing has been increasing as they offer operational and economic benefits compared to traditional fracturing fluids such as slickwater and guar (Hu et al. 2018; Johnson et al. 2018; Biheri and Imqam 2021a). HVFRs have been found to lower operational costs, require less equipment, exhibit better conductivity in fractured formations, and lead to production improvements (Johnson et al. 2018; Ba Geri et al. 2019; Biheri and Imqam 2021b, 2022). However, hydraulic fracturing fluids are usually prepared using fresh water, which can be costly and present challenges when freshwater resources are scarce. As a result, the industry has been exploring the use of produced or formation water, which typically has high levels of salinity and hardness. Currently, most high TDS applications are focused on the Marcellus shale formation. The Marcellus shale is a Middle Devonian source rock and reservoir that spans over multiple states in the Appalachian Basin, including Kentucky, West Virginia, Ohio, Pennsylvania, and New York. This formation has an average temperature of around 140°F (60°C) and can reach bottom hole pressures up to 6000 psi. The produced and flowback water in this area has high levels of TDS, with a typical concentration range of 30,000 ppm to 50,000 ppm. (Williams et al. 2011; Johnson et al. 2018).
Study on Evolution Law of Pore Pressure Around Well Under Different Fracturing Technology Conditions of Platform Wells
Authors: Zhao Y. F. , Wang F. W. , Huang J. B. , Zhang X. J. , Li J. , Lian W. , Liu G. H. , Huang H. L. 
Published: September 2023

ABSTRACT
In recent years, some platform Wells in the Fengnan 4 well area of Xinjiang Oilfield have adopted the zipper fracturing technology in the production process, which causes the change of pore pressure near the wellbore, and then leads to the complex distribution of ground stress around the well, and increases the risk of casing deformation. Therefore, this paper considers different fracturing technology of platform wells, such as sequential fracturing of platform wells and alternating fracturing, and zipper fracturing, establish corresponding numerical models, analyzes the evolution law of pore pressure around the well, and compares and analyzes the influence of different fracturing processes on pore pressure around the middle well of the platform. The results show that the pore pressure is circularly distributed with the fracturing stage as the center during the fracturing process, and the pore pressure decreases as the distance from the center increases. During the fracturing process of the platform wells, the pore pressure diffusion regions of adjacent wells will gradually connect and influence each other. All fracturing technologies have a cumulative increase effect on pore pressure around intermediate well, and the effect of alternating fracturing in platform Wells is the most significant. The results of this study lay a foundation for the study of the variation of in-suit stress around the well during the fracturing process of the platform wells.

INRTUDUCTION
Multi-stage fracturing of horizontal Wells is a key technology for the economic exploitation of shale oil and gas. By "breaking" the reservoir as much as possible, a large and complex fracture network is formed to maximize the production of a single well (Jiang, 2014; Chen, 2016; Jiang, 2017; Li, 2013). With the spread of the "well factory" model, simultaneous fracturing techniques using alternating fracturing of two or even three wells, zipper fracturing, and cross-zipper fracturing techniques optimize the sequence and location of fracturing have been developed to further improve fracture complexity and reservoir reconstruction volume (Rafiee M, 2012; Waters G, 2009).
Sanding in Sliding-Sleeve Completed Wells in Moderately Competent Reservoir Formations – A Field Case
Authors: Xiao Yuxing , Agrawal Madhusuden , Vaziri Hans , Anthony Rosemary 
Published: September 2023

ABSTRACT
A sliding-sleeve sandface completion consists of a series of blank pipe segments, isolation packers, and short sleeves in-between serving as flow ports. That geometrical configuration renders a unique sanding mechanism. Due to a large opening in the annulus rock starts to disaggregate at a lower depletion than in a cased and perforated completion, but rock aggregates tend to be mainly in blocks and chunks, which are favorable in lowering sanding risk as bigger aggregates have a higher apparent strength and require a higher fluid velocity to mobilize and transport toward the flow ports. Also, fluid flow in the annulus accumulates from the packer and converges toward the sleeve. The annular fluid velocity thus is zero at the packer and the highest at the sleeve. Therefore, an effective practical measure to mitigate and lower sanding risk is to optimize the number and locations of packers and sleeves in relation to the reservoir formation strength and sandface flow contributions.
The above sanding mechanism and practical ramifications are illustrated through historical sanding responses in 11 horizontal wells in an oil field in the UK North Sea. The reservoir formation is moderately competent and its UCS is 1000-3000 psi. The well flow rate ranges from a few thousand barrels per day (mbd) to 25mbd and most of wells have experienced watercut. Despite weak formation intervals that are expected to disaggregate from the get-go, high well rate and watercut, sanding to date is below the design tolerance. A method, including CFD modeling, was developed to estimate the annular fluid velocity and rock aggregate's pickup velocity – the minimum velocity required to mobilize rock aggregates. Through cross-referencing historical sanding responses empirical relationships between sand mass per meter length and annular fluid velocity were established for sand-prone formation intervals with and without watercut respectively. The method and empirical relationships can be used in optimizing sandface completion design in future wells and production and interventions in existing wells.
The Effect of Moisture Content on the Acoustic Properties of Regolith Analogs
Authors: Lisabeth H. P. , Schmerr N. , Lekic V. , Zhu W. , Siegler M. , Ghent R. 
Published: September 2023

ABSTRACT
Successful location of icy deposits on the moon and other planets requires detailed knowledge of the physical properties of both icy and ice-free potential reservoir materials in order to design geophysical equipment, implement surveys, and interpret data. In support of this goal, we have conducted acoustic characterization experiments to measure the physical properties of dry and icy regolith simulant using synchrotron x-ray transmission microtomography and ultrasonic acoustic sensing as a function of temperature. Measurements were performed on a porphyritic basaltic glass from a cinder cone. Synchrotron x-ray microtomography was performed at beamline 8.3.2 at the Advanced Light Source (ALS). Ultrasonic measurements were made on an ultrasonic pulse-transmission system consisting of an upright cylindrical acrylic column outfitted with ultrasonic and temperature sensors. Samples were cooled to −35°C and allowed to equilibrate. Ultrasonic measurements were then taken as the samples were slowly warmed. Waveforms from experiments were then analyzed to calculate changes in acoustic velocity and attenuation as a function of temperature. Oven dried samples show only slight variations in velocity with temperature, while slightly wet samples show significant variations, suggesting water on grain surfaces plays a significant role in the physical behavior of the samples. Further work is needed to address the temperature dependence of truly dry materials versus those with adsorbed volatiles; however, these initial results suggest that temperature-dependent acoustic measurements may be useful in the location of volatiles in regolith.

INTRODUCTION
There has been evidence for trace amounts of water trapped in lunar minerals for at least a decade (Saal et al., 2008), but more recent studies have identified signs that there may be free water stored as ice within the regolith (Schultz et al., 2010). Evidence for water in the lunar regolith from remote sensing shows that the lunar south pole in particular has a significant water resource (Sanin et al., 2017). Recent spectroscopic data suggest that there is between 100 and 400 mg/g of water in the regolith, much more than ever assumed (Honniball et al., 2020). The challenge will be to locate exactly where it sits in the regolith. Planetary science has always been driven by remote sensing, but as the US, other countries and private corporations ramp up robotic and manned missions to the moon in the next decade, direct, experimental measurement of the properties of icy regolith are needed.
Study on the Influence of Injection Rate on Hydraulic Fractures Crossing Natural Fractures
Authors: Chen Houze , Zhang Guangqing , Cao Lutong , Zhang Lu 
Published: September 2023

ABSTRACT
The interaction between hydraulic fractures and natural fractures will directly affect the complexity of fractures, which is an important content that needs to be paid attention to in the fracturing process. To study the interaction between hydraulic fractures and natural fractures at different injection rates, a large-scale true triaxial hydraulic fracturing simulation system was used to conduct fracturing experiments on artificial specimens with prefabricated natural fractures. Results show that increasing the injection rate can generate more complex hydraulic fractures in formations with natural fractures. Hydraulic fractures can cross natural fractures and maintain the original direction of expansion easier by increasing the injection rate. When the injection rate increases from 4ml/min to 6ml/min, the time for the blunt hydraulic fracture to reach the opposite natural fracture is reduced by 29%, and the pressure rise in the fracture increases by 0.6MPa. The cementation at the end of natural fractures is weaker. When the natural fractures are fully activated, generating new fractures at the ends of natural fractures is easier by increasing the injection rate.

INTRODUCTION
Hydraulic fracturing is an important production stimulation method in reservoir exploitation. The generated hydraulic fractures provide migration channels for oil and gas, and the complexity of hydraulic fractures also directly affects the effect of fracturing. Early studies generally believed that the hydraulic fracture is a double-wing symmetrical shape. Faults, veins, and joints in rocks are collectively called natural fractures. (Gale, J. F., Laubach, S. E., Olson, J. E., Eichhubl, P., & Fall, A. 2014) Due to the presence of natural fractures, the actual fracture shape is more complicated. The impact of natural fractures is multifaceted: increased fracturing fluid loss, premature screen-out, fracture stop propagation, formation of multiple fractures, fracture offset, and high net pressure.
There have been many experimental studies on the interaction between hydraulic and natural fractures. Lamont and Jessen (1963) found that when the approach angle between hydraulic and natural fractures ranges from 30° to 60°, hydraulic fractures can cross natural fractures and propagate along the direction orthogonal to natural fractures. Blanton (1982) and Warpinski (1987) showed that hydraulic fractures penetrate existing fractures at large stress differentials and large approach angles. At lower approach angles and stress differentials, natural fractures open, diverting fracturing fluid and preventing passage of induced fractures, at least temporarily. Daneshy (1974) studied the effect of natural fracture size and found that the crystal and matrix boundaries of granite blocks, small fractures (0.5 inches), have little or no influence on the direction of propagation of hydraulic fractures. In contrast, in a few cases, hydraulic fractures cannot penetrate large natural fractures.
Experimental Development and Investigation of Grouting Reinforced Rock for High Geo-Temperature Environment
Authors: Fan L. D. , Su Z. H. , Sun L. , Yu Y. Q. , Wang X. D. 
Published: September 2023

ABSTRACT
With the increase of long and deep-buried tunnels, the disaster caused by high geo-temperature was more and more prominent. Grouting reinforcement was an important tunnel support measurement. Therefore, this study was aimed at an investigation of grouting reinforced rock under the high geo-temperature. Firstly, a new experimental device for grouting reinforced rock was designed, which could be used for laboratory tests under simulate different geo-temperature. Then, an experiment of grouting reinforced rock under different temperatures (20, 30, 40, 50, and 60°C) was carried. Finally, the results indicated that the newly developed device was applicable for the physical and mechanical properties investigation of grouting reinforced for broken rock under different temperatures, which also had the advantage of small size and flexible installation. The strength, ultrasonic velocity, and permeability resistance of grouting reinforced rock first increased and then decreased with temperature, which had an optimal value at the temperature 30°C. In addition, the positive correlation among the strength, ultrasonic velocity, and permeability resistance under different geo-temperature was also demonstrated in this paper. It was expected to make a reference for the tunnel grouting reinforcement design under the high geo-temperature environment.

INTRODUCTION
With the advancement of tunnel design and construction technology, the number of deep-buried long tunnels crossing geologically active areas increases. The high geo-temperature phenomenon (temperature exceeding 28°C during construction operations) is presented in deeply-buried long tunnels, which is due to hydrothermal activity, active fractures, and magmatic activity (Sun et al., 2021). For example, the length of high geo-temperature region accounts about 1/3 of the Gaoligong Mountain Tunnel in China, and the highest geo-temperature is about 50°C (Du et al., 2021). There are more than 10 high geo-temperature tunnels along Sichuan-Tibet Railway. The high geo-temperature not only deteriorats the construction environment but also seriously damages the performance of support materials and surrounding rock stability (Chen et al., 2022; Sun et al., 2022). Therefore, the investigation of support materials under different geo-temperature is imperative.
The Conceptual Subsurface Carbon Storage Development Planning for a Seashore Carbon Storage Site in Taiwan
Authors: Fan C.-H. (Chenners) , Wu W.-J. , Shiao T.-W. , Yang C. C. , Tseng Y.-C. , Bouchet F. , Qiu K. , Zhang H. , Zhao G. , Wang F. 
Published: September 2023

ABSTRACT
As a feedback to the plan to achieve net-zero carbon emissions by 2050 unveiled by the Taiwanese government, this study, the conceptual subsurface carbon storage development plan, was conducted for a selected seashore carbon storage site to blueprint the project and make an initial feasibility assessment. The development plan includes the placement of injection and monitoring wells, conceptual design of injection wells and monitoring wells, and conceptual risk management plan and monitoring planning. In this paper, we describe the conceptual design process, summarizes the key considerations and findings from the work, and provides good references for those CCS projects at the inception stage.

INTRODUCTION
In 2022, The government of Taiwan announced the goal of "2050 Net-Zero Emissions" to combat climate change, and carbon capture and storage (CCS) is considered a critical part of the overall solution to achieve this goal. Under the mandate of the government, CPC Corporation, Taiwan has set up an ambitious plan to commence commercial carbon capture and storage (CCS) operations in 2030. The goal is to inject 5 million metric tons/yr (MTPA) and gradually build up to 14 MTPA CO2 into the selected seashore site and offshore sites.
Unlike other large-scale oil and gas field development projects, CCS projects face unique challenges because of the lack of regulations in many places around the world, the long CO2 flow chain from capture, transportation and storage, and relatively high geological and geomechanical risks for long-term containment in the data-scarce saline aquifers. To mitigate these risks, an extensive literature review of the international CCS guidelines and standards and the previous CCS projects were conducted, the relevant guidelines and standards were identified, and lessons learned and best practices from the previous CCS projects were captured. A conceptual subsurface CCS field development plan was conducted by leveraging the enriched knowledge of worldwide CCS regulations and standards, the best practices and lessons learned. The development plan mapped out the timeline, requirements and cost of the key components of the CCS projects, which paves the foundation for the successful execution of the project.
Experimental Study on Improving the Fracture Conductivity of Acid Etched Fracture for Ultra-Deep and High Stress Carbonate Reservoirs
Authors: Zhou Jun , Zhang Xudong , Zhou Linbo 
Published: September 2023

ABSTRACT
With the development of carbonate reservoirs moves to the ultra-deep layer, the etched fracture would be closes quickly in the high stress. In this paper, high channel sanding method with acid fracturing technology are combined, the strength and spread ways of the different type proppant are optimized, and the fracture conductivity of continuous sanding and channel sanding are tested. The experiment result shows that high strength ceramic proppant can improve the conductivity of acid erosion fractures under high pressure. In the stress of 50MPa, fracture conductivity by high channel sanding with 86MPa ceramic could be increased by more than 51% than that of conventional acid etched fracture. The flow conductivity increase amplitude reaches more than 700% in the condition of 90MPa. By changing the sanding mode, the quantity of proppant can be saved, the pump risk can be reduced, and the stable and solid support channel can also be formed to improve the conductivity of acid etched fractures in ultra-deep carbonate reservoirs.

INTRODUCTION
With the gradual development of the Carbonate reservoir to the ultra-deep layer, the depth of the reservoir has reached 8,800 meters, and the temperature has been raised from 120°C to 180°C. The increase of reservoir depth and temperature brings many new challenges to reservoir stimulation. When the effective closure stress of the reservoir increases from 10 MPa to 55 MPa, the conventional acid etched fracture conductivity decreases by 95% (Yao et al., 2015). With the increase of closure stress, the insufficient support strength is the main reason for the rapid decrease of the fracture conductivity. In order to increase the fracture validity period after acid fracturing, the main objective is to improve the long-term etched fracture conductivity.
The existing acid fracturing is to dissolve calcareous minerals on the fracture surface, leaving the unreacted rock skeleton as the supporting point. Due to the uneven distribution of each point and its low compressive resistance, it will be crushed gradually under high closure stress. Many scholars (Yi et al., 2006, 2008, 2010, Gao et al., 2015, Wang et al., 2012,2016, He et al., 2014) tried to improve the fracture conductivity by using cross-linked acid carrying sand or compound acid fracturing, and achieved certain effect in the oilfield application. However, with the increase of reservoir depth, it becomes more and more difficult to add sand into the carbonate reservoirs. In the meantime, proppant concentration cannot be effectively increased, making it difficult to achieve the effect of high concentration proppant placement (Zhuang et al., 2014). In recent years, many researchers try to use high channel pulse sand-adding method in low permeability reservoir (Zhong et al., 2012, Wu et al., 2014, Liu, 2015, Fu et al., 2016).