bluuebunny/crossref_metadata_2025_split huggingface dataset:
Remote Sensing in Oil Spill Handling in Offshore North West Java
Authors: Ligafinza Audra , Sajjad Farasdaq Muchibbus , Jabbar Mohammad Abdul , Fatmawati Anggia , Wirawan Alvin Derry , Suganda Wingky 
Published: October 2021

Abstract
During the blowout event, it is critical to track the oil spill to minimize environmental damage and optimize restoration cost. In this paper, we deliver our success story in handling oil spill from recent experiences. We utilize remote sensing technologies to establish our analysis and plan the remediation strategies. We also comprehensively discuss the techniques to analyze big data from the satellites, to utilize the downloaded data for forecasting, and to align the satellite information with restoration strategies.
PHE relies on its principle to maintain minimum damage and ensures safety by dividing the steps into several aspects of monitoring, response (offshore and onshore), shoreline management and waste management. PHE utilizes latest development in survey by using satellite imaging, survey boat, chopper and UAV drone. Spill containment is done using several layers of oil boom to recover oil spill, complemented with skimmers and storage tanks. PHE encourages shoreline remediation using nets and manual recovery for capturing oil sludge.
Using this combination of technologies, PHE is able to model and anticipate oil spill movement from the source up until the farthest shoreline. This enables real time monitoring and handling, therefore minimum environmental damage is ensured. PHE also employs prudent engineering design based on real time field condition in order to ensure the equipment are highly suited for the condition, as well as ensuring good supply chain of the material availability.
This publication addresses the first offshore blowout mitigation and handling in Indonesia that uses novel technologies such as static oil boom, satellite imaging and integrated effort in handling shoreline damage. It is hoped that the experience can be replicated for other offshore operating contractors in Indonesia in designing blowout remediation.
Study on Enhanced Oil Recovery Using Microorganism Generating Foam in Presence of Nanobubbles
Authors: Ito Miu , Sugai Yuichi 
Published: October 2021

Abstract
Both high cost and environmental load of surfactant are issues to be solved in foam EOR. Moreover, it is difficult to control the injection of surfactant and gas so that the foam is generated in only high permeable zones selectively in oil reservoir. The authors have found a foam generating microorganism and hit upon an idea of the microbial foam EOR which makes the microorganism do generating foam in oil reservoir. The mechanism of the microbial foam generation and culture condition suitable for the foam generation were studied in this study.
A species of Pseudomonas aeruginosa was used as a foam producer in this study. It was cultured in the medium consisting of glucose and eight kinds of minerals at 30 °C and atmospheric pressure under anaerobic conditions. Because P. aeruginosa generally grows better under aerobic conditions, the microorganism was supplied with oxygen nanobubbles as the oxygen source. The carbon dioxide nanobubbles were also used as a comparison target in this study. The state of foam generation in the culture solution was observed during the cultivation. The surface tension, surfactant concentration, protein concentration, polysaccharides concentration and bacterial population of the culture solution were measured respectively.
The foam was started to be generated by the microorganism after 2 days of cultivation and its volume became maximum after 3 days of cultivation. The foam generation was found in the culture solution which contained both oxygen nanobubbles and carbon dioxide nanobubbles whereas little foam was found in non-nanobubbles culture solution. The foam generation found in the culture solution containing carbon dioxide nanobubbles was more than that in the culture solution containing oxygen nanobubbles. Both gas and protein concentration increased along with the formation of the foam whereas surfactant and polysaccharides were not increased, therefore, the foam was assumed to be generated with gas and protein which were generated by P. aeruginosa. It was found that the carbon dioxide nanobubbles were positively charged in the culture medium whereas they were negatively charged in tap water through the measurement of zeta potential of nanobubbles, therefore, the carbon dioxide nanobubbles attracted cations in the culture medium and became positively charged. Positively charged carbon dioxide nanobubbles transported cations to the microbial cells of P. aeruginosa. Among cations in the culture medium, ferrous ions are essential for the protein generation of P. aeruginosa, therefore, the positively charged carbon dioxide nanobubbles attracted ferrous ions and transport them to the microbial cells, resulting the growth and metabolism of P. aeruginosa were activated.
Those results suggest that the microbial foam EOR can be materialized by supplying the microorganism with carbon dioxide nanobubbles or ferrous ions.
Automation & Digitalization Implementation – A New Normal in Oil & Gas Industry: A Success Story
Authors: Mario Cio Cio , Pramana Harris , Eviany Ameria , Nugrahanto Anang , Nasrudin Nasrudin , Murtani Anom Seto 
Published: October 2021

Abstract
Nowadays automation and digitalization in oil & gas industry have become a new normal practice to replace traditional workflows. The implementation of automation and digitalization is driven by the need to automate the repetitive and low-cognitive tasks, so it allows engineers to spend more time on high-cognitive and high-level analytical evaluations or studies, and to finally lead up to smarter decisions. One of the solutions is by developing and implementing "fit for purpose" automation tools which consist of various data analytics inside the tools.
Saka Energi Indonesia, as the operator of Pangkah PSC, has developed and implemented automation and digitalization in Ujung Pangkah field. Located in northern side of East Java, the field's reservoir consists of multi-layered carbonate oil and gas zone, which is being produced through horizontal and directional wells. Solutions of automation and digitalization have been developed for the Ujung Pangkah field to minimize loss opportunity, increase oil production and reduce the field decline rate. With some collaboration efforts from Subsurface, Operation and IT Department Team, some automation tools have been developed and implemented in Ujung Pangkah Field, which are as follows:
Exception Based Surveillance (EBS) tool: An automation tool to identify real-time well problems & opportunities. Auto Gas Lift Rate Allocation (GALAA) tool: An optimization tool to automate gas lift rate allocation. SAKA Well Opportunity, Register, Define and Select (SWORDS): An automation tool to evaluate well opportunity portfolio. Well Model Update Automation: A tool to update well model automatically for every individual well.
By implementing the automation solutions, various repetitive tasks can be completed significantly faster and more efficiently. Saka engineers have more time to perform high-cognitive analytical evaluations on other technical areas. Ujung Pangkah field oil production decline rate has been successfully decreased from 21%/year to 8.6%/year after the automation solutions have been implemented in 2018.
Ujung Pangkah success story of automation & digitalization implementation will be used as a reference for managing other Saka assets in different fields. The new automation solutions are a faster and a more efficient way of optimizing existing field production and it will give positive impacts exponentially with increasing well numbers.
Study on Fracture Conductivity of Mahu Sandy Conglomerate Tight Oil Reservoir
Authors: Yang Liu , Gao Jingwei , Chang Shilei , Wan Qianbing , Liu Canhua 
Published: October 2021

Abstract
Objectives/Scope: Effective development of tight oil and gas depends on the generation of artificial fractures, and continuous and efficient development of tight oil and gas requires the use of proppants to maintain the diversion effect of artificial fractures. At present, the microscopic mechanism of damage to fracture conductivity of sand conglomerate reservoir is not clear.
Methods, Procedures, Process: Taking the sandstone conglomerate in Mahu sag as the research object, the experimental study on the fracture conductivity of the sandstone conglomerate in Mahu sag is carried out. First, the stress sensitivity analysis of the sandstone conglomerate is performed on a pore scale using a self-made permeability measurement method, then, the fracture width, pressure and flow rate are measured under the condition of fracture scale to analyze the change law of conductivity during fracturing fluid injection.
Results, Observations, Conclusions: The results show that the permeability of gravel decreases with the increase of confining pressure, and the stress sensitive damage is strong. After a cyclic loading condition, permeability will not recover to the initial value, causing irreversible damage to the pore and roar. As the fracturing fluid continues to be injected, a large amount of proppant becomes embedded in the fracture and leads to a decrease in conductivity. The whole diversion curve can be divided into two stages. In the first stage, the diversion damage is great, and in the second stage, the diversion damage decreases somewhat. The damage of conductivity is closely related to the content of clay minerals.With the increase of clay mineral content, the conductivity damage rate increases rapidly, especially the existence of illite and Aimonite mixed beds can significantly improve the conductivity damage rate.
Novel/Additive Information:The results provide a solution for the optimization of proppant concentration, the improvement of tight oil production and the study of gravel diversion damage mechanism in the Mahu area.
Additive Scale Removal Based on Noncorrosive Organic Acid for Handling Silica and Carbonate Scale in Oil and Gas and Geothermal Wells
Authors: Pasarai Usman , Wahyudi S. Panca , Haans Arie , Widiantara IGN , Saroyo Budi 
Published: October 2021

Abstract
The silica and carbonate scale that forms along the production pipeline is a significant problem in the oil and gas and geothermal industry because it disrupts production operations. Silica and carbonate scales on the inside of the pipe cause blockage of flow and an increase in pressure. Failure of downhole settlement equipment will reduce the production capacity of the well, and the maintenance burden will increase.
The main objective of this research is to test the reactivity of an environmentally friendly non-corrosive organic acid system based on vegetable fatty acids and carbohydrates with high dissolution efficiency for the treatment of silica and carbonate scales in geothermal and oil and gas fields. This paper provides information on laboratory analysis in terms of analysis of the composition of scale samples obtained through XRD analysis, acid system developed testing for dissolution efficiency at 50°C and 100°C for 1 hour, compatibility and stability testing, and testing the corrosive impact on coupon metal AISI CS-1019 samples at 100°C for seven days in a closed aging cell.
Testing the concentration of the new organic acid system in high dissolution efficiency and low corrosion effect was carried out through laboratory-scale studies before being applied to field-scale operations. The results showed that the dissolution efficiency of the scale sample against the developed organic acid system (100% concentration) at 50 and 100°C for 1 hour showed reactive effect. Reduction rate of silicate-07; silicate-29; silicate-L1; silicate-KB1; carbonate-A3 at 50°C were 7.825%; 3.823%; 6.177%; 2.014%; 8.211%, and at 100°C were 12.884%; 0.631%; 15.047%; 0.103%; and 32.909%. The newly developed organic acid system demonstrates stability and compatibility with formation waters with low formed solids, and it has a pH of 6. The results of the corrosion rate test were carried out without an inhibitor at 100°C for seven days and gave a yield of 77.340 mils per year, while other commercial additives gave a yield of 2,525.120 mils per year. The new eco-friendly organic acid system has a good effect in helping dissolve silica and carbonate scales, safe for production equipment, and lowers high maintenance costs.
Keywords: Organic Acid Scale Remover, Silica and Carbonate Scale, Environmentally friendly
A Numerical Simulation Study of CO2 and N2 as Cushion Gas in an Underground Gas Storage
Authors: Tang Kang , Liao Xinwei , Zhao Xiaoliang , Li Haojie , Li Xiaoxiao , Wang Xiaochen , LI Jiehan 
Published: October 2021

Abstract
Underground gas storage (UGS) is a beneficial economic method of compensating for the imbalance between natural gas supply and demand, which is currently considered an important part of the gas chain. To reduce the capital investment of gas storage, the use of alternative gases as cushion gas is a good choice. However, the mixing of different gases in the UGS challenges the application of alternative gases(N2and CO2) as cushion gas. In this paper, we first conduct the thermodynamic analysis of two alternative gases, namely, N2and CO2. The feasibility of these two gases as cushion gas is discussed. Secondly, a gas storage located in Eastern China is selected. Based on the physical properties of the reservoir, a simulation model with coupled diffusion mechanism is conducted. Finally, the effect of molecular diffusion, gas category and ratio on the dynamic operation of UGS is studied. In addition, the CO2storage capacity under different operating parameters was also analyzed. This study provided a scientific basis for the efficient operation of UGS and the geological storage of CO2.
Challenging Horizontal Well Abandoned with Innovative Plug Setting Technique and Tailored Slurry Design
Authors: Simmadorai Dinesh , M Ariffin M Syafiq , Patil Mayank , Franke David , Noh Aizat , Lau Chee Hen , Kumar Avinash Kishore 
Published: October 2021

Abstract
Setting multiple plugs across a horizontal well can be a challenge. One way to do this is using the "pump and pull" methodology to achieve the objectives set out by the project team. Tailoring of the cement slurries and the execution of cementing operations for the successful deployment of multiple cement plugs using this method to achieve a dependable barrier across a horizontal reservoir section will be reviewed and discussed. A development well in Malaysia lost a bottom hole assembly (BHA) in their 8.5" hole section. This resulted in the requirement to abandon a long horizontal section along with the requirement to spot a 2,100 ft continuous cement plug on top of the BHA to abandon the well.
The main challenge for setting a cement plug across a horizontal section, is cement slumping and stuck pipe, which might result in repeating cement plug jobs or non-productive time having a negative impact on well economics. To achieve isolation objectives in the first attempt, this long continual plug was broken up amongst four smaller individual plugs "stacked" on top of each other. The first 3 plugs were designed to each be 600 ft in length followed by a 340 ft plug. To avoid cement slumping, a cement support tool was deployed above the BHA before the first plug in the horizontal section. The first three plugs were placed in the horizontal open hole section and the fourth plug was placed at an inclination of 75 degrees, all using the "pump and pull" method.
The pump and pull method is a common practice for worker operations with coil tubing and this similar technique can be applied in ERD drilling operations to aid in the homogeneous and accurate placement of cement plugs. However, for this job, the pump and pull placement method was preferred to aid in the homogenous and accurate placement of cement slurry through the horizontal open hole section. Detailed job calculations, the slurry design which was tailored for this application along with detailed operational procedures which resulted in the successful placement of all plugs on the first attempt under challenging well conditions will all be discussed.
The approach utilized here resulted in the successful placement of a 2,100 ft continuous plug which isolated the BHA and saved the project valuable rig time. Similar approaches can be used in other areas to achieve successful results in first attempts to help well economics.
Hanging Screen Evaluation to Unlock Marginal Sandy Reservoir: Case Study of Peciko Gas Field, Indonesia
Authors: Hidayat Danny , Marindha Rantoe , Nugroho Triantoro Ade , Hidayat Reyhan , Rusdi Runi Kusumaning 
Published: October 2021

Abstract
Peciko Field currently produces gas from multilayer sand-prone shallow reservoirs. Therefore, it needs sand control method to unlock these marginal reservoirs through low-cost intervention. Hanging screen has been reviewed as an alternative solution to minimize sand control cost while maintaining its robustness to maximize the recovery. This paper will present and evaluate the hanging screen installation and performance from subsurface to surface elements in Peciko field.
Hanging screen implementation in Peciko will be evaluated in terms of ease of installation to its performance during production phase. Peciko wells are equipped with real-time monitoring system including Acoustic Sand Detector. Therefore, sand problems could be easily identified. Any indication of screen failure will be confirmed by checking the surface equipment like chokes and intrusive probes. Further intervention to retrieve the screen and perform visual check at surface can be executed to extend the verification. Filter size, placement method, clean-up, and sand sieve result will be gathered to identify the root cause and determine the best method to apply hanging screen as reliable sand control method.
Nine installations in 2019 conclude that screen plugging, liquid loading, and combination of both are main issues in production phase. With three plugging cases from well Fx and E2x, it was found that excessive drawdown pressure triggers high gas velocity in perforation tunnel and causing excessive sand production that plugged the screen. These cases also prove that self-unloading by choke movement can lead to plugging if the drawdown pressure and gas rate are not monitored carefully. Commingle production in Ax becomes an issue in lifting performance when reservoir pressure declines and liquid was produced from several reservoirs. Limiting drawdown pressure gives smaller gas rate to lift the liquid and make the well died from liquid loading easily. Massive sand production in well E2x and E2y cause an increase in Top of Sediment (TOS) and lead to inaccessible screen even with multiple bailing attempts. A series of screen design, choke configuration, proper clean-up and continuous monitoring are critical steps to be performed prior and after screen installation to maintain production lifetime. With average stakes of 0.2 Bcf per well, hanging screen has proven to produce 67% of the well reserves in shallow reservoirs. This value creation led to the conclusion that hanging screen is an economically-feasible-sand control method to be implemented in Peciko.
High Shut-in Pressure: Good News or Bad News? Maximising Value through Limited Data
Authors: Sutoyo Handita Reksi Dwitantra , Nurhajj Diniko , Anindyajati Anak Agung Iswara , Febrianto Dwi Hudya , Kristianawatie Nova 
Published: October 2021

Abstract
Early production of gas reservoirs is usually associated with a volumetric gas driving mechanism with no water production. Aquifer activity is minimal as well during the early life of the reservoir. In this paper, we will discuss about the good engineering practices based on several shut-in pressure data to observe and maximize marginal gas field value. We will also discuss about the possibility of water drive behavior in this field.
Shut-in pressure data plays an important role in determining the in-place and reservoir dynamics of the gas reservoir. High shut-in pressure usually indicates high gas reserves. On the other hand, it shows a very strong water drive existence. The study takes place on a sandstone gas reservoir with an abnormal pressure regime on it. Production performance was then analyzed using the rate transient analysis (RTA) to determine its properties and gas in place and crosschecked with shut-in pressure data. From these steps, we can determine the trend of both static and flowing material balance (FMB) analysis to predict the reservoir dynamics.
During the early life of production, it is clear that volumetric reservoir plays an important role in the reservoir dynamics since it produces no reservoir water. However, after 1 year of production, it starts to produce reservoir water. Monitoring starts when the first shut-in pressure shows a quite unexpected value. It puts a sense of both high gas reserves and aquifer activity. After applying all the pressure and production data on FMB and p/Z plot, it shows that both high gas reserves and aquifer activity exist in this field. The results of this study change the development strategy of this field, preventing doing major investment on high capital expenditure (CAPEX) with low results due to high aquifer activity. We can conclude that good reservoir monitoring and analysis combining several analytical methods can enhance our insight into reservoir dynamics.
Combining FMB and p/Z, geologist starts to compare aquifer volume based on geological data and found to be similar with the results coming from analytical data. 3D reservoir simulation also confirms similar results based on those analyses.