Geoenergy Science and Engineering最新文献

{"title":"Key mechanical properties of hydrate bearing sediment: state of the art and prospects","authors":"Qing Yang,&nbsp;Jiaolong Xu,&nbsp;Yubin Ren,&nbsp;Yunrui Han,&nbsp;Chen Zhou,&nbsp;Gang Yang,&nbsp;Yin Wang,&nbsp;Long Yu","doi":"10.1016/j.geoen.2025.214079","DOIUrl":"10.1016/j.geoen.2025.214079","url":null,"abstract":"<div><div>Natural gas hydrates (NGH), as an exceptionally promising source of clean alternative energy, are widely stored in the seabed. Insufficient understanding of the mechanical behavior of hydrate-bearing sediments (HBS) may increase the risk probability of triggering geological disasters and threatening safe exploitation. The objective of this paper is to make a comprehensive review of the key mechanical characteristics of HBS. Firstly, the preparation technology of HBS samples, including in-situ sampling and indoor synthesis technology was introduced. Then, the compressive characteristics of HBS were systematically concentrated from experimental research, mechanism analysis, numerical simulation and mathematical model. It was followed by the summaries of static mechanical properties, including the current development of test equipment, typical shear behavior of HBS at different conditions, and the major influencing factors. In particular, the research progress of the dynamic mechanical properties of HBS was generalized mainly from two aspects of large or small strain conditions and numerical simulation. Finally, the summary of this review and the shortcomings of the current research, as well as the prospects were made and proposed. This review is expected to deepen the understanding of the mechanical behavior of HBS for subsequent researchers and provide reference for future exploitation.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214079"},"PeriodicalIF":0.0,"publicationDate":"2025-07-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144711223","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental investigation on improving sweep efficiency through temperature-resistant gel foam in heavy oil reservoirs","authors":"Bin Zhang ,&nbsp;You Zhou ,&nbsp;Bojun Wang ,&nbsp;Changfeng Xi ,&nbsp;Weifeng Lv ,&nbsp;Pengcheng Liu","doi":"10.1016/j.geoen.2025.214117","DOIUrl":"10.1016/j.geoen.2025.214117","url":null,"abstract":"<div><div>As global demand for crude oil increases, the problem of steam channeling faced in the thermal recovery of heavy oil reservoirs seriously affects the oil recovery and operation cost. Due to the limitations of profile control in traditional foams, the aim of this experimental investigation is to develop a high-temperature-resistant gel foam system to plug steam channeling paths. Gel foam can compensate for the defect of poor thermal stability in single-component foam, and shows great potential in oil reservoir development. This paper mainly expounds that the gel foam system (0.5 wt% foaming agent AOS + 0.5 wt% polymer HPAM + 0.4 wt% crosslinker PE + 0.5 wt% stabilizer), as a profile control agent for improving the recovery, has better performance than the single foaming agent AOS. Through the experiments on the foam volume and the half - life of liquid separation, the foaming agent AOS has the highest foam complex index both at room temperature and under the high temperature condition of 200 °C. Subsequently, AOS is selected to be compounded with the gel, and the formula of the gel foam system with good gel - forming performance is determined: 0.5 wt% AOS +0.5 wt% HPAM +0.4 wt% PE + 0.5 wt% stabilizer. In the profile control experiment, when the gas-liquid ratio is 1:1, the addition of AOS to the gel can increase its resistance factor by 14 times, which confirms that compared with AOS, this system can effectively block the high - permeability dominant channels and improve the sweep volume, demonstrating great potential for enhancing oil recovery. Moreover, after the gel foam system is aged at 200 °C for 48 h and then subsequent water flooding of 15 PV is carried out, the plugging rate of the gel foam system is still as high as 86.4 %, which also indicates that this system can carry out long - term and effective profile control. Moreover, the heavy oil recovery of the gel foam slug is 6.3 % higher than that of the AOS slug. Therefore, as a profile control agent for improving the sweep efficiency, the gel foam system has greater advantages than AOS profile control.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214117"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144704279","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"CO2 plume monitoring and visualization using pathlines, source cloud and time cloud","authors":"Hongquan Chen,&nbsp;Ao Li","doi":"10.1016/j.geoen.2025.214093","DOIUrl":"10.1016/j.geoen.2025.214093","url":null,"abstract":"<div><div>Effective monitoring of subsurface fluid motion is crucial for successful carbon sequestration. While streamlines are commonly used to visualize fluid flow, they are based on instantaneous velocity fields and do not account for changing field conditions. To address this problem, pathlines are introduced to track the history of individual fluid particles as they move in a changing velocity field.</div><div>This paper presents the development and application of pathlines for flow visualization in CO₂ storage projects. By splicing streamline segments over time, pathlines can trace the trajectory of a particle under a changing velocity field. In addition, streaklines and timelines can be visualized from pathlines. Streaklines represent all fluid particles emitted at the same location, while timelines show the contour formed by all fluid particles emitted at the same instant, representing the fluid front movement. In 3D, these concepts are visualized in groups of points, referred to as source cloud and time cloud.</div><div>To test the effectiveness of our proposed injection monitoring methods, we conducted experiments on 3D synthetic CO₂ storage models. The results show that pathlines, source cloud and time cloud provide a more accurate display of the CO₂ plume than streamlines, particularly in field situations where well schedules are changing.</div><div>Finally, we applied the proposed method to visualize the CO₂ plume in a sequestration model based on Norway's Sleipner site. Under dynamic injection, the pathline-based swept volume closely matched the CO₂ saturation-defined volume (95 % overlap), while the streamline-based volume overestimated it by 127 %. This highlights the effectiveness of pathlines, source cloud, and time cloud for CCUS visualization.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214093"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144704379","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Microscopic performance evaluation of hyperbranched polyamine for sodium montmorillonite hydration inhibition in water-based drilling mud systems","authors":"Jiafang Xu ,&nbsp;Justine Kiiza ,&nbsp;Johann Peter Plank ,&nbsp;Zhehui Jin ,&nbsp;Xiaolong Yang ,&nbsp;Hualin Liao","doi":"10.1016/j.geoen.2025.214115","DOIUrl":"10.1016/j.geoen.2025.214115","url":null,"abstract":"<div><div>Deep to ultra-deep drilling operations are vital strategies for global energy security, requiring high-performance drilling fluid systems. Water-based drilling fluids/muds (WBDFs/WBDMs), especially clay-containing muds, often degrade under extreme wellbore conditions owing to clay mineral hydration, necessitating advanced inhibition strategies and effective additives to minimize expansion and ensure wellbore stability. Amine-based additives are known for their remarkable inhibitive features. Molecular dynamics simulation was used to evaluate the inhibition performance of a hyperbranched polyamine on sodium montmorillonite (Na-Mnt) hydration in WBDFs. This polyamine demonstrated good solubility and effectively interacts, adsorbs and coats the Na-Mnt surface. Adsorption occurs primarily through H-bonding and electrostatic attractions, with minimal van der Waals (vdW) contributions, forming a protective surface layer/film on the Na-Mnt that modifies its hydrophilic properties by layering the surface. Two adsorption configurations were identified: a stable amine head group and a dimethylamine group. The addition of the polyamine reduced counterion and water mobility, minimizing their coordination as the aqueous NH₄⁺ ions replaced Na ⁺ ions and water molecules, reducing the counterion and Na-Mnt hydration, consequently, weakening the Na-Mnt/water H-bonding network and interaction energy, and thus reducing surface hydration. Temperature had a significant impact on the interaction strength and inhibition performance, while high pressure played a minimal role at elevated temperatures. Overall, the hyperbranched polyamine demonstrated splendid inhibition performance under HT/HP conditions (478 K/75 MPa) for enhancing WBDFs performance and supporting safer, stable and more efficient well drilling works.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214115"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144686167","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"CO2-responsive system for preventing gas channeling during CO2 flooding in low permeability reservoirs","authors":"Rui Liu ,&nbsp;Canghai Chen ,&nbsp;Yang Tao ,&nbsp;Zezhou Chen","doi":"10.1016/j.geoen.2025.214094","DOIUrl":"10.1016/j.geoen.2025.214094","url":null,"abstract":"<div><div>At present, CO₂ flooding is extensively used in low-permeability reservoirs to enhance oil recovery (EOR). However, due to the serious heterogeneity of the formation, the gas is prone to escape along large pores during CO₂ flooding. Conventional CO₂ anti-channeling systems have some defects such as poor stability, weak retention capacity and inferior plugging effect. Therefore, it is critical to develop a novel type of CO₂ anti-channeling system for low-permeability reservoirs. Herein, four kinds of systems with amine groups are tested to identify the most effective CO₂-responsive system, which consists of poloxamer, dimethylaminoethyl acrylate, nano carbon powder, acrylamide and initiator. Subsequently, physicochemical properties of the optimum system are researched systematically by rheological experiments, CO₂-responsive processes and structural characterization. The results indicate that the viscosity of the system increases from 4.2 mPa s to approximately 67.8 mPa s as a result of increasing temperature and CO₂ injection. Meanwhile it can be reversibly cycled between low viscosity and high viscosity by alternately introducing and removing CO₂, which indicates the gas response behavior of the system is reversible. Furthermore, the plugging performance and EOR are evaluated using low permeability cores. The experiments demonstrate that the system can effectively restrain gas channeling and enhance recovery factor by as high as 22 % - significantly outperforming conventional water-alternating-gas (WAG) flooding which provided only a 10.62 % enhancement under comparable conditions. We expect our work can provide a new system and method for CO₂ anti-channeling in low-permeability reservoirs.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214094"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144695423","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Effect of fluid saturation on the elastic properties of carbonate rocks with different pore structures in a strike-slip fault zone","authors":"Fei Gong ,&nbsp;Yichen Song ,&nbsp;Lianbo Zeng ,&nbsp;Suping Peng ,&nbsp;Guangui Zou ,&nbsp;Guowei Wang","doi":"10.1016/j.geoen.2025.214110","DOIUrl":"10.1016/j.geoen.2025.214110","url":null,"abstract":"<div><div>Understanding the elastic characteristics of fault-controlled carbonate rocks under dry and water saturated conditions is still rare, despite being essential for hydrocarbon exploration and development. To study the influences of stress and fluid on the elastic characteristics of carbonate rocks controlled by a strike-slip fault, four samples were studied by combining microscopic observation, ultrasonic analysis and theoretical modeling. The results show that significant heterogeneity can be found in the characteristics of carbonate rocks with pore structure differences. The porosity and permeability of the fault core are 3–6 times and 2-3 orders of magnitude greater than those of the damage zone, while velocities are significantly lower. The velocity pressure sensitivity of the saturated samples is less than that of dry ones, because the compressibility of microcracks is greatly reduced under water saturated conditions. The DKT model can simulate the elastic moduli of carbonate strike-slip fault rocks by three equivalent pore geometries, which can qualitatively identify the fault structure. After saturation, the S-wave velocity generally decreases in the fault core and increases in the damage zone. Fault core samples show shear softening after saturation, while the damage zone samples show shear stiffening. The Gassmann's equations may not be valid anymore in this situation. The changes in shear moduli after saturation are affected by the combination of the pore structure and the confining pressure, and the potential mechanisms are also discussed.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214110"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144670349","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Strength development of phosphoaluminate cements in a CO2-containing environments at 110 °C: synergistic evolution of compressive strength, hydration products and micro-morphology, and carbonation mechanism","authors":"Bin Yuan,&nbsp;Shuo Yang,&nbsp;Xingyang Zhang,&nbsp;Zehao Zheng,&nbsp;Bihua Xu","doi":"10.1016/j.geoen.2025.214122","DOIUrl":"10.1016/j.geoen.2025.214122","url":null,"abstract":"<div><div>Phosphoaluminate cements are able to meet the high temperature and high CO₂ content environments faced by oil and gas well cementing, owing to their high temperature and corrosion resistance. However, up to now, there is no research to clarify its compressive strength, hydration product changes and corrosion mechanism in such complex environments. Therefore, this paper analyzes the compressive strength and type of hydration products of phosphoaluminate cement stones at 110 °C and CO₂ environments with different curing times and after corrosion. It was shown that the permeability of phosphoaluminate cement stone first decreased and then increased with the increase of the curing time, while the compressive strength kept increasing, and the specimens' compressive strength after corrosion still maintains a very high level. The stable existence of hydroxyapatite (Ca₅(PO₄)₃OH) and hydrated aluminate (C₃AH₆), as well as the persistent generation of main hydration products (hydrated phosphate (CPH) and hydrated phosphoaluminate (CAPH)), and their morphology always maintains a uniform distribution of flakes and fibers, together guarantee the stable growth of compressive strength. The corrosion mechanism shows that Al(OH)₃ and CaCO₃, generated by the corrosion of CPH, CAPH with C₃AH₆ and CAP with CA, had a positive affect on pore development. At the same time, Ca₁₀(PO₄)₆CO₃ generated by the corrosion of some Ca₅(PO₄)₃OH will maintain the original hexagonal structure to form a protective layer, and H₃PO₄ released by the corrosion of hydration products and reactive minerals will lead to an increasingly acidic solution. This prevents the diffusion of CO₂ toward the internal cement stone, which in turn further inhibits corrosion.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214122"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144665526","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Effect of organic matters on CH4/CO2 replacement in the hydrate-bearing muddy silt sediments","authors":"Liang Mu,&nbsp;Jiguang Zeng,&nbsp;Xinhan Lin,&nbsp;Zijie Chen,&nbsp;Minghu Huang,&nbsp;Qingyan Cui","doi":"10.1016/j.geoen.2025.214105","DOIUrl":"10.1016/j.geoen.2025.214105","url":null,"abstract":"<div><div>The exploitation of natural gas hydrates (NGH) via CH₄/CO₂ exchange is promising for energy extraction and carbon sequestration, while the presence of organic matters in sediments complicates this process. In this study, the CH₄/CO₂ replacement in hydrate-bearing muddy silt sediments containing organic matters was investigated. The effects of organic matter type (lignin, humic acid (HA), fulvic acid (FA)) and content, experimental temperature and pressure, saturations of initial water and CH₄ hydrate were systematically examined. The results revealed that organic matter significantly improved CH₄/CO₂ replacement. For the 1.0 wt% HA-contained sediments, the CH₄ recovery and CO₂ sequestration rate reached 51.07 % and 30.66 %, increasing 64.69 % and 43.00 % than those of the organic matter-free system, respectively. High temperature facilitated CH₄/CO₂ swapping, and CO₂ sequestration rate decreased as the replacement pressure increased. There existed an optimal initial water saturation for HA-contained sediments which favored CH₄/CO₂ replacement. The CH₄ recovery and CO₂ sequestration rate declined with the increase of CH₄ hydrate saturation. In multi-stage replacement, CH₄ recovery continuously increased while CO₂ sequestration rate decreased due to excess CO₂ injection. The CH₄ recovery achieved 73.12 % after the third stage replacement, increasing around 17 % compared to that of the first stage. These findings contribute to better understanding CH₄/CO₂ replacement in practical scenarios and offer new ideas for obtaining CH₄-rich gas in gas swapping in the future.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214105"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144680564","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Assessment of the impact of heterogeneity in volcanic facies, porosity, and permeability on CO2 storage: a case study from Pune-Nashik area and Killari-1 borehole, Main Deccan Plateau","authors":"Jyotirmoy Mallik ,&nbsp;Balram Tiwari ,&nbsp;Nimisha Vedanti ,&nbsp;Thomas Finkbeiner ,&nbsp;Anurag Niyogi ,&nbsp;Arathi Krishna Variyambath ,&nbsp;Adya Anand ,&nbsp;Swatilekha Sarkar ,&nbsp;Domingo Lattanzi ,&nbsp;Dharma Gadela ,&nbsp;Mahmoud Mowafi ,&nbsp;Dip Das","doi":"10.1016/j.geoen.2025.214124","DOIUrl":"10.1016/j.geoen.2025.214124","url":null,"abstract":"<div><div>Carbon Capture and Storage (CCS) is recognized as a vital strategy for transitioning from fossil fuel-based energy systems to sustainable alternatives. This is particularly true in developing countries like India, where economic growth correlates with rising carbon emissions. The Deccan Traps, comprising extensive continental flood basalts, present significant potential for CO₂ storage through mineral carbonation, thanks to their vast coverage and substantial volume. Although the Deccan Traps are well studied from volcanological, geochemical, geochronological, paleomagnetic and overall geodynamics aspects, its potential to become one of the largest CO₂ sinks, both from geochemical and petrophysical point of view is lacking. This study focuses especially in the Pune Nashik area and Killari-1 borehole area on the Main Deccan Plateau (MDP), investigating the various lava flow morphologies present in the region. Fieldwork in these areas provided valuable insights into the internal structure of the lava flows, enhancing our understanding of the distribution and variability of vesicles and fractures, which are essential for evaluating fluid flow behaviour and subsurface permeability. Notably, the prevalent compound lava flow exhibits three distinct morphologies: an upper and lower vesicular zone, separated by a massive core zone. The degree of fracturing in the core zone plays a critical role in determining overall connectivity. We collected rock samples from both the field and the Killari-1 borehole, to determine porosity using traditional porosimetry and micro-computed tomography (micro-CT) imaging. We discuss the discrepancies in porosity estimates derived from both methods and their implications. The vesicular basalt exhibits very low permeability due to limited connected porosity, while fractured basalts have significantly higher permeability as revealed from the Discrete Fracture Network (DFN) modelling of a type section. Finally, we assess various CO₂ storage scenarios in the MDP, incorporating variations in porosity, bulk rock volume, and ECO₂. We acknowledge that the studied samples are too limited to comment on the entire MDP. However, this is the first attempt to assess the petrophysical properties of the MDP from a CO₂ storage perspective.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214124"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144686164","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Changes of trace elements in the transport process from source rocks to solid bitumen","authors":"Changzhi Li ,&nbsp;Huaguo Wen ,&nbsp;Zili Zhang ,&nbsp;Luya Wu ,&nbsp;Pei Guo","doi":"10.1016/j.geoen.2025.214089","DOIUrl":"10.1016/j.geoen.2025.214089","url":null,"abstract":"<div><div>Trace elements in solid bitumen are potential parameters for tracing gas sources. However, it is difficult to choose appropriate trace elements that can be used for gas-source rock correlations due to the poor understanding of trace element behaviors during the complex transport process from source rocks to solid bitumen. The solid bitumen in the Ediacaran Dengying Formation of the Southern Sichuan Basin, southwestern China, was chosen to analyze the changes of trace elements in the transport process from source rocks to solid bitumen. Biomarker comparison suggests that most solid bitumen in the Dengying Formation was sourced from the overlying Cambrian Qiongzhusi Formation. Scanning electron microscopy observation and trace element analysis of the Dengying Formation solid bitumen and Qiongzhusi Formation source rocks show that trace elements are differentially hosted in organometallic complexes or inorganic minerals. By element comparison, we clarify the trace elements in solid bitumen into four types: enriched (Pb, Cu and Sr), depleted (Rb and Co), stable (Ni, Zn, V, Mo, Cr, U and Sb) and fluctuating (including Ba, Cs and Hf) trace elements. Among these four element types, stable trace elements (Ni, Zn, V, Mo, Cr and Sb) in solid bitumen are suggested to be the potential indicators for tracing gas sources due to their main hosts in organometallic complexes and stable behaviors during the transport process from source rocks to solid bitumen.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214089"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144680079","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}