bluuebunny/crossref_metadata_2025_split huggingface dataset:
Plunger Lift System: A Field Implementation Case Study in Upper Assam Shelf Basin
Authors: Maut Partha Protim , Prakash Yerra , Dutta Udai Anand , Saikia Partha Protim , Sowmyanarayanan N M , Yadav Abhishek 
Published: October 2024

Abstract
Plunger lift is an economical artificial lift system applicable to high gas-liquid ratio gas wells and gas lift wells. This rig-less hybrid technology was deployed in various marginal fields of the Upper Assam Shelf Basin with the primary objective of extending the economic lifespan of the wells. The project involves candidate selection, installation, commissioning, optimization, and troubleshooting of plunger Lift system in gas wells and intermittent gas lift wells.
In this project, plunger lift system is installed in gas wells with the following objectives:
Potential increase in overall influx due to deliquification. Reduced liquid fall back, which results in overall crude oil gain. Increased gas production. The tubing bore is kept clean by eliminating hydrate and scale deposits.
The intermittent gas lift wells are operated with conventional gas lift mandrels and valves. The plunger lift system was integrated with the gas lift system to eliminate common gas lift well inefficiencies to achieve the following:
Minimize liquid slippage and fallback control. Decrease issues related to paraffin deposits. Increase oil production.
This paper presents an exceptionally detailed analysis of the plunger lift system installed in gas and intermittent gas lift wells, which provides a mechanical interface between gas and liquid for:
Improved drawdown and maximized flow potential. Cyclic deliquification of gas wells. Stabilized gas and liquid flow. Increased overall efficiency of the gas lift system. Resumption of a normal decline curve. Enhance the economic lifespan of the well. Delays high CAPEX expense of other artificial lift system methods.
The paper emphasizes the selection of potential wells, integrating plunger lift systems for gas and intermittent gas lift wells, optimizing the gas lift system, and troubleshooting. This hybrid project was successfully executed to increase oil, condensate, and gas production in addition to reducing paraffin deposit-related issues, compression horsepower, and overall operating expenditure while maintaining an optimized injection gas rate. A detailed analysis of the plunger lift system optimization and troubleshooting has been presented in this paper. This plunger lift project resulted in an overall average of 36% liquid and 83% gas gains in the candidate wells of the Upper Assam Shelf Basin.
A significant potential for low investment and rapidly increasing production and development of the reserve lies in the application of plunger lift systems in gas and intermittent gas lift wells. As a result of this project, we have gathered valuable technical experience that shows plungers can substantially increase production in gas and intermittent gas lift wells in brownfields in the Upper Assam Shelf Basin and other exploration and production (E&P) companies throughout the world.
Development of a Novel Modelling Tool for Condensate Emulsions: Key Factors Influencing Oil-In-Water Emulsions
Authors: Amir M. Mahamad , Halim N. , Sagar S. Wan , Razali N. , Shafian S. M , Zulkifli N. , Razak A. A , Hendraningrat L. , Baharuddin S. , Zainal S. , Othman A. Ahmad , Wahab M. A , Noor M. Md , Sedaralit M. , Yusof M. 
Published: October 2024

Abstract
As the global energy landscape shifts towards cleaner alternatives like natural gas, managing the emulsions in condensate production becomes increasingly important for environmental compliance and operational efficiency. This study presents the development of a novel modelling tool designed to predict condensate emulsions, focusing on key factors causing emulsions such as pH, solid content, asphaltene concentration, droplet size, and organic acids. Through a series of controlled experiments using turbidity measurements, transmission analysis, and the Turbiscan Stability Index (TSI), the effects of these variables on emulsion stability were systematically evaluated. The findings reveal that higher shear rates and presence of asphaltenes significantly enhance the emulsion stability, while pH and organic acid content play complex roles in either stabilizing or destabilizing the emulsions. The modelling tool offers a predictive capability for emulsion behavior, aiding in the optimization of separation processes and improving effluent discharge quality (EDQ) to meet stringent environmental standards. This research contributes to better emulsion management strategies in the oil and gas industry, particularly in fields with condensate production ensuring both improved operational outcomes and environmental protection.
Research on Key Materials and Systems of Ultra High Temperature Cement Slurry for Ultra-Deep Wells Cementing
Authors: Xiujian XIA , Yongjin YU , Fengzhong QI , Huiting LIU , Congfeng QU 
Published: October 2024

Abstract
With the continuous deepening of oil and gas exploration and development, the number of ultra-deep and ultra-high temperature wells is gradually increasing in China. The key materials and systems of cementing slurry are crucial for ensuring the safe construction of wells, effective sealing of cement sheath, and safe production of oil and gas. However, the complex working conditions such as ultra-high temperature pose serious challenges to the materials and systems of cement slurry. Focusing on the technical difficulties of ultra-high temperature cement slurry for deep and ultra-deep wells cementing, the cementing retarder, fluid loss additive, stabilizer, and set cement strength retrogression inhibitor with the temperature resistance of 240 ° C were developed through the technical methods, such as optimizing polymer molecular structure, surface modification of powder materials, and synergistic effects between materials. The novel cement slurry system with the temperature resistance of 240 ° C was formed on basis of the above-mentioned four key additives and their supporting materials. Its comprehensive performance was evaluated. The cement slurry system has the resistance to bottom hole circulating temperature of 240 ° C. After curing at 240 ° C, the settling stability of cement slurry can be controlled within 0.05 g/cm3, the API fluid loss is less than 50 mL, and its thickening time can be adjusted arbitrarily within 200 to 600 min, which is linearly related to the test temperature and retarder dosage. The compressive strength of set cement is 45.8 MPa and 55.2 MPa cured at 240 ° C for 2 d and 28 d, respectively. The comprehensive performance of the cement slurry system is excellent, solving a series of problems such as slurry instability, non-adjustable thickening time, uncontrollable water loss, cement stone cracking, and strength decline under ultra-high temperatures. It can meet the requirements of the ultra-high temperature cementing operations and long-term sealing of cement sheath for complex deep and ultra-deep wells. The key materials and systems of ultra-high temperature cement slurry have been successfully applied for more than 20 wells in China, including the highest temperature well of Qiantan 1 with 213 ° C in Dagang Oilfield and the deepest vertical well Pengshen 6 in Asia with 9026 m. The novelty of this paper is in the ability to solve the problems of high-temperature performance failure of cementing additives and the instability of slurry system. Meanwhile, it can provide the technical guidance for the polymer structural design and synthesis of key additives, and the formation of ultra-high temperature cement slurry. It plays an important role in the safe and efficient exploration and development of deep and ultra-deep oil and gas.
Analyzing Greenhouse Gas Emission Leading Indicators: Case Study of Compressor Profile Optimization
Authors: Kongkiatpaiboon Suradech , Apornsupavit Asit , Manoharn Songkiet , Phetket Chawanin , Nimanong Sasiwan , Prabhasawasdi Saranya , Charungrattanapong Worasak 
Published: October 2024

Abstract
This study examines energy efficiency and emission management projects as well as the challenges and solutions. Best practices are identified through multiple workshops, and they are applied to our emission data. These include reviewing factors impacting energy performance, and benchmarking visualization across locations and comparing key equipment. Upon extensive analysis, it becomes evident that there is a significant decrease in the operating pressure of the sales gas export pipeline in comparison to its previous state. Consequently, the optimization of compression profiles is necessary to effectively reduce emissions.
Standard emission dashboards primarily report lagging indicators, such as the quantity of emitted gas and burned fuel gas. These factors are significant, but they are measured after the fact. Another important parameter to be considered is the leading indicator. However, the analysis and focus on equipment activities or instrument operations that contribute to lagging indicators are typically lacking.
The compression system in gas processing plants is widely recognized for its high fuel consumption. This is mainly influenced by three factors: compression ratio, engine speed, and critical valve operation, which are responsible for maintaining the pressure profile. Opportunities exist for our plants due to the significantly lower sales gas pipeline pressure compared to the original design conditions. This is coupled with the fact that the compression ratio remains the same. After thorough engineering analysis, we have identified that the opening of recycle valves, anti-surge valves, and back pressure control valves are the primary indicators that are valuable for visualizing and implementing decisive measures. Engineering measures have been implemented to address the limitations, allowing the compressors to operate at lower speeds. This has led to a significant reduction in emissions and operating expenses.
The increasing convenience of the world poses a significant environmental concern for future generations. Mitigating it effectively is challenging. This study examines various efforts and proposes an effective approach for monitoring, visualizing, and managing emissions in gas processing plants’ compression system. This paper will benefit individuals engaged in emissions reduction efforts and anyone interested in contributing to environmental preservation.
Analysis of Ammonia Discharged from Ammonia Fuel Supply System During Ammonia Depressurization Process According to Recovery Pressure
Authors: Jeong G. , Go W. , Jung J. , Park J. , Seo Y. 
Published: October 2024

Abstract
The dual-fuel engines secure the stability of the engine and the fuel supply system through a purging process with nitrogen in situations such as dual-fuel stop or shutdown. However, since ammonia has fatal toxicity depending on its concentration and exposure time, discharged flow analysis of the ammonia fuel supply system is required. In this study, the flow characteristics of ammonia and nitrogen mixture discharged from the fuel supply system were analyzed by simulating the ammonia purging process with Aspen HYSYS. The fuel supply system was modeled for the ammonia engine under development from MAN ES, and some parts of fuel supply system were estimated. Purged ammonia was mixed with water in the ammonia catch system except for the amount that can be recovered. The investigation reveals that as the recovery pressure increases, the amount of recovered ammonia also increases. Simultaneously, the amount of ammonia discharged into the atmosphere through the water tank decreases. The results showcase a positive correlation between recovery pressure and the efficiency of ammonia recovery during the depressurization process. These findings contribute valuable insights for designing effective systems that prioritize the recovery and treatment of discharged ammonia, mitigating potential safety concerns.
Implementation of Top-Hole Collision Risk Management for Drilling a Well with a Separation Factor Below 1.0 in a Dense Fixed Platform: A Success Story from Offshore North West Java, Indonesia
Authors: Yuda Bintang Kusuma , Sany M Fajar , Kurniawan Aris , Adi Bayu Arie Punto , Christyananta Thewa , Sirait Nikolai , Dewi Elys Irayana , Munoz David Humberto 
Published: October 2024

Abstract
This paper introduces a risk management strategy for a drilling campaign with a high collision risk. ELG-X was drilled from an existing platform, necessitating the wellpath to pass within close proximity of an adjacent well with an SF of 0.79. An SF below 1 poses a risk of collision due to overlapping Ellipsoid of Uncertainty (EoU), jeopardizing drilling and company's business plan. Hence, effective mitigation and directional planning were crucial for safe well execution.
A comprehensive risk mitigation strategy was developed to manage adverse consequences to an acceptable risk level, encompassing two primary activities during the drilling process. Firstly, the 12-1/4" pilot hole, typically employed for shallow gas risk mitigation, was endorsed in this case to reduce the likelihood of hole contact in the top-hole interval, with engineering mitigations including GWD utilization, high bend-degree mud motor application, passive rock bit employment, subject & adjacent well monitoring, and well integrity placement. Secondly, the 17-1/2" hole enlargement process involved maintaining drilling parameters and employing a less aggressive hole opener to prevent damage to the adjacent well.
The developed strategy was implemented during drilling in the top-hole section. The 12-1/4" rock bit, paired with a 1.83-degree bend mud motor, was utilized for controlled drilling in the collision risk interval, allowing for precision and effective maneuvering. By applying control parameters and tight survey monitoring per joint drilled, the result shows that no major indications of well collision were observed. ELG-X trajectory convincingly separated away from the adjacent well and got SF above 1. The mud motor's bend degree was subsequently adjusted to 1.5-degree, facilitating the continuation of drilling toward the casing point in alignment with the planned trajectory. Positive signs were also noted during the 17-1/2" hole enlargement, with no significant evidence of well collision or damage to the adjacent wellbore. The upcoming operations, such as running 13-3/8" casing and cementing, can be managed properly without encountering any issue or findings. In summary, the top-hole section can be secured without any safety incidents and related NPT.
This paper details the implementation of a collision mitigation strategy in the ELG-X well, Offshore North West Java Operation, serving as a valuable reference for future drilling. It showcases a successful case of top-hole drilling in a dense fixed platform with a minimum SF. The strategy is anticipated to provide insights for unlocking idle wells facing similar challenges as ELG-X.
Novel Alternative Solution for Deviated or Horizontal Geo-Steering in High and Ultra-High Temperature Reservoir, A Case from Australia
Authors: Angus Ross, , Michelle Yim, Poh Wan 
Published: October 2024

Operator is developing an unconventional gas reservoir, drilling horizontal 6 1/8" production wells in an Ultra High Temperature (UHT) basin with Bottom Hole Temperature (BHT) of up to 200°C. Rotary Steerable Systems (RSS) are not commonly available with temperature rating to 200°C. Standard rated RSS (150°C) are used instead. The first well (offset well H-5) was drilled using this methodology and achieved a 1000m lateral section, however the tools were exposed to operating temperatures of 172°C. The operating temperature exceeded tool specification and resulted in significant Damaged Beyond Repair.
The operator sought an alternative solution, using robust fit for purpose steerability that would survive the high temperature environment while achieving the Minimum Acceptable Outcome (MAO) of 900m of horizontal reservoir exposure.
The contractor offered a novel solution combining technologies to drill the second (subject well) of this paper, H-4. An Adjustable Gauge Stabilizer (AGS) rated to 200°C was incorporated into a Bottom-Hole Assembly (BHA) with a UHT rated Logging While Drilling (LWD) tool rated to 200°C. This tool incorporated directional survey, gamma ray (GR), pressure-while drilling (PWD) and downhole vibration sensors. The AGS could be set to Full-Gauge (FG) or Under-Gauge (UG) diameter and the BHA was designed to drop or build inclination (respectively) depending on the setting. This provided a simple 2-D steerable assembly. UHT-rated directional, GR and PWD sensors provided directional surveys, formation correlation and downhole annulus and internal pipe pressure data. Downhole vibration sensors provided drilling efficiency data and facilitated mitigation of downhole vibration extending tool reliability.
Investigation of Applications of 3D Printing to Oilfield Equipment: A Case Study of Hydrocyclones
Authors: Zhao Xiaojie , Wang Jue , Gao Yang , Wang Wenchang , Wei Songbo , Zhou Yutian 
Published: October 2024

Abstract
Three-dimensional (3D) printing offers several advantages, including flexible design, faster production, cost-effectiveness, suitability for small-batch production and reduction of carbon emissions. In particular, by optimizing the structure of oilfield equipment and adjusting the microstructure of metal 3D printed parts, high-performance components can be manufactured for complex working conditions in the oilfield.
Taking the hydrocyclone as an example, the preparation process is as follows. Firstly, the optimization of the hydrocyclone's structure. The response surface design was combined with computational fluid dynamics to optimize the type and parameters of the hydrocyclone. Secondly, the selection of 3D printing material. Maraging stainless steel was chosen as the 3D printing material based on the performance requirements of the hydrocyclone. Thirdly, determining the 3D printing process parameters. Parameters were selected based on the microstructures, mechanical properties, wear resistance, and corrosion performance of the 3D printed parts. Ultimately, a novel hydrocyclone was 3D printed, and its separation performance was evaluated using a laboratory testing system.
Results show a variable pitch hydrocyclone structure with high separation efficiency was designed and a high-density hydrocyclone part was successfully printed. Heterogeneous microstructures present in 3D printing stainless steel lead to excellent strength (tensile strength, σb = 1184 MPa), toughness (impact energy, Wt = 149 J) and wear and corrosion resistance. The 3D-printed complex hydrocyclone features greatly improved separation efficiency (99.38%, which is 0.58% higher than that of the conventional structure). Based on the above results, an innovative mindset based on 3D printing for cost reduction and efficiency enhancement was formed, and a comprehensive technical system, from structural design to manufacturing, microstructure characterization and performance evaluation, was developed.
The challenges and prospects of applying 3D printing in the oilfield were analyzed, with a focus on the research and development of key oilfield equipment. This research promotes applications of 3D printing in the petroleum industry and advocates for the intelligent manufacturing of high-end petroleum equipment.
The Best Practices and Workflow of Tight Reservoir Fracturing Diagnosis, Optimization, and Productivity Evaluation
Authors: Yu Huijuan , He Zejun , Zhang Wei , Wang Meng , Xu Danian , Zhou Yongsheng , Wang Chenyang , Prabowo Ken , Gui Feng 
Published: October 2024

Abstract
Hydraulic fracturing (HF) is an effective technology to develop tight oil & gas reservoirs, which is expected to achieve ideal production in reservoirs that would otherwise achieve little or no production. However, it is not uncommon that many of these fractured wells are not able to achieve the expected enhancement. The objective of this paper is to demonstrate the best practices and workflow to make post-fracturing diagnosis, fracturing design optimization and pre-fracturing and post-fracturing productivity assessment.
This is a model-based approach, and the workflow is based on comprehensive understanding of geological characteristics of the reservoir. Following the general HF feasibility study, 1D geomechanical (GM) model of single well is established, then a fracturing model is built for fracturing simulation. Post-fracturing diagnosis and fracturing effect evaluation will be based on simulation results. Finally, a well flow model is established to predict productivity and conduct sensitivity analysis. In this way, the main factors affecting fracturing effectiveness can be identified and the relevant engineering parameters can be optimized.
Experimental Investigation of Infilled-Shear Fractures Conductivity in Shale Reservoirs
Authors: Lu C. , Wang S. X. , Chen C. , Li Y. Q. , Zeng Q. J. , Zhu Q. Y. , Sun J. H. , Guo J. C 
Published: October 2024

Abstract
The study and assessment of flow conductivity within infilled-shear fractures play a pivotal role in guiding the development of shale gas resources. This paper presents an investigation using shale reservoir rock samples from the Longmaxi Formation. We employed a novel infilled-shear seepage coupling experimental system, developed in-house, to perform nitrogen flow tests under stress seepage coupling conditions. Our findings reveal that the incorporation of proppants mitigates the impact of fracture roughness, and the effect of fracture morphology on conductivity is primarily evident at lower concentrations. The impact of shear slip on flow conductivity is discernible only in rock samples with higher roughness. Furthermore, the evolution of infilled-shear fracture conductivity with increasing proppant concentration follows a biphasic pattern: an initial decrease followed by an increase. Intriguingly, a significant positive correlation exists between the critical proppant concentration and the volume capacity, with an approximate threshold of 25%. This correlation is of profound importance for the strategic planning of fracturing operations.