bluuebunny/crossref_metadata_2025_split huggingface dataset:
Intelligent Detection of SEM Mineralogy Using Dynamic Segmentation Algorithm in Geothermal Sedimentary Reservoir: Case Study with Quantification of Quartz Overgrowth
Authors: Andaru Arkanu , Sausan Sarah 
Published: October 2023

Abstract
Quantifying quartz overgrowth in sedimentary geothermal reservoirs can provide vital information about reservoir quality and drilling success rates. The traditional process, which involves manual inspection of numerous Scanning Electron Microscope (SEM) images, is tedious and time-consuming. This paper introduces an automated approach using computer vision and random forest algorithms to streamline the process, providing a more efficient method for noise reduction, multi-level thresholding, machine learning (ML) model training, and application to SEM images for quartz overgrowth detection.
Our approach employs a dynamic segmentation algorithm that integrates noise suppression, multi-level auto-thresholding, and dynamic overlaying. This enables automatic mineral identification from lower-quality images, accommodating varying brightness and contrast levels. Additionally, the algorithm effectively handles overlay shifting in cathodoluminescence (CL) and backscattered electron (BSE) images. We use a Random Forest technique to train the algorithm using comprehensive ground truth data and CL image features like Gabor, Canny Edge, and Roberts Edge. The resultant ML model helps refine the image segmentation predictions, acting as a more precise mineralogy predictor.
Our model training achieved an encouraging 75% accuracy score, demonstrating its effectiveness in distinguishing between quartz grains and overgrowth, as well as identifying porosity and other minerals. However, due to the vast data size, further model improvement necessitates additional training data and usage of a High Performance Computing (HPC) cluster. After training, the model showed enhanced detection capabilities, particularly a reduction in false porosity detections associated with internal cracks. Future improvements could involve applying morphology detection principles and allowing user input for parameters like overlay shifting. The program was designed for easy use by individuals with minimal coding experience, and further development into a web app is suggested for increased accessibility.
In summary, this method significantly enhances the efficiency and accuracy of mineralogy analysis using SEM images, providing a quick and accurate method for geoscientists to determine mineral composition.
Fracturing New Wells in Mature Field – Tenares Tight Sand Development Evolution of Kotabuana Field Infill Drilling Initial Completion
Authors: Yogasugama Mario Andre , Prasetio Mario Hadinata , Nataliawati Nurul Ayu , Putra Rendy Maylana , Kusumaningsih Hapsari Wahyu , Sutyastomo Dwiyanto , Irfan Muhamad , Makmun Areiyando 
Published: October 2023

Abstract
Since the Tenares infill drilling campaign started in 2021, Fracturing has become Kotabuana field new well primarily Initial Completion (IC) method. The design was set based on the best practice that evolved throughout time since 2018, starting with typically 1300 bbls fracturing fluid, 80,000 lbs of proppant with a typical 7 PPA pumping schedule. During the execution campaign, the fracturing initial completion design and execution was improved by evaluating the post job result correlation towards well property and production result.
A key factor in the successful fracturing job is the fracturing model. In improving the fracture modelling, Temperature log was run to validate the 1D Mechanical Earth Model (MEM) by seeing the change in temperature post mini fract to detect the fract height growth. By doing so, the risk of having a premature screen out could be minimized, improving the overall job effectiveness. The necessary additives was also introduced to control the height growth.
The type and volume of fracturing fluid and proppant was also improved according to the lessons learned to gain improvement and progression on the optimal fracture design in each execution. Start with one and two-size proppants to get optimal conductivity and decrease fracturing fluid gel loading which can reduce residual fracturing gel. The job performance also highlighted in the aggressiveness of fracturing that compare the PAD ratio used in the execution towards the design by increasing the amount of proppant injected and pad cut. This progression makes the pumping execution reach up to 130.000 lbs of proppants and stage 12 PPA pumping schedule.
Numerous improvements were observed during the IC fracturing process. During the sand clean out operation, a more direct approach to the cleaning up operation was employed by maintaining the pressure in the string annulus during 4 of 5 screen-out occasions which successfully reduces the needs for Coiled Tubing Unit (CTU). There are also accumulative works and efforts which successfully optimized the cycle time of fracturing operation by year of execution. Another improvement was the decisive action to conduct re-fracturing execution when a premature screen-out was encountered, improving the total cycle time and workflow.
The Fracturing result has been proven to stimulate the productivity index (PI) of the well with a fold of production. Some key lessons learned during the executions were documented which highlight the importance of several key aspects such as temperature log utilization to validate 1D MEM, proppant tapering strategy in pumping schedule, well placement towards the fracturing design and the existence of injector well to provide pressure support in sustaining the well production.
Challenging the AWCA Annular Wash Cement Assurance Acceptance Norm
Authors: Damasena Edwin 
Published: October 2023

Abstract
Annular Wash Cement Assurance (AWCA) has been used for several years as a cost-effective tool for Permanent Abandonment (P&A) of oil/gas wells to remediate cement behind casings in lieu of Section milling to establish a rock-to-rock barrier. In order to verify AWCA result in the annulus, originally the cement in the casing is drilled out and the casing re-log with a bond log then a cement plug re-set in the casing. With experience gained in AWCA, Companies become more and more bolder and accept the performance of the AWCA without further annulus verification. A Qualification matrix, also called Verification Matrix (VM) is used instead to justify avoiding cement drill out – cement bond log and cement plug re-set in the casing.
One of the criteria of the VM is a ‘track record’ as per NORSOK, is a minimum of three successful AWCA jobs. The definition of "successful" means verification of the annulus cement by drilling out (cement) followed by a bond log. Ref. NORSOK D10-2021 EAC Table 61.
The following AWCA jobs with similar parameters as the track record jobs (casing/lithology/fluid etc) are verified without drill-out and bond logging, i.e non destructive verification, claiming that the track record guarantees the AWCA will be satisfactory.
Other Companies do not establish track record at all, instead they use the VM as the only verification means.
The VM matrix is non other than a table comparing the job design & operational parameters vs the actual data.
The paper discusses possible short comings with the use of VM alone to justify avoiding drilling out and logging the annular cement to verify it's integrity.
Recent events have shown cases where Sustained Casing Pressure (SCP) develop several years after the AWCA job.
Also, several cases are known where the AWCA job performance were given the thumbs up passing the VM with flying colours, however when the cement was drilled out and a cement bond log ran, it shows evidence the annulus void of cement or poor cement bond.
The reluctance to do destructive verification is understood as it seems to be such a time waste. Not only do you need to drill the plug you just set, you also will need to run a scraper and wait a minimum of 48 hrs before logging the cement in the annulus. Once all done, you will need to reset the cement plug in the casing then wait for cement to harden to verify the cement barrier by tagging and pressure testing.
An alternative verification process is proposed to verify the annulus barrier as a proper barrier.
Hyperbaric Welding and Wire Arc Additive Manufacturing for Downhole Applications in the Oil and Gas Industry
Authors: Leon Escobar Sharen Monserrat , Walzl Alexander , Ravi Krishna , Prohaska Michael , Stockinger Martin , Richardson Ian Malcolm , Fateh Nazanin , Hönig Stefan 
Published: October 2023

Abstract
A large and increasing number of wells must be abandoned or repurposed in the next decades. Additionally, there are many wells to be re-entered and repaired due to problems and conditions such as casing leaks, corrosion, annular communication, patch placement, zonal isolation, closing perforations, etc.; therefore, the development of more efficient and cost-effective methods to address these issues is paramount. The main objective of this research includes the proof of concept (POC) of a Wire Arc Additive Manufacturing (WAAM) process under hyperbaric conditions for downhole applications in the Oil and Gas (O&G) industry. This POC will enable the development of a potential downhole WAAM technology that could place corrosion-resistant steel barriers as well as closing holes in the wellbore. Well plugging and abandonment (P&A), and well integrity re-establishment operations are costly and often associated with a low probability of long-term success. Available conventional technologies and techniques mostly use cement as a plugging material. However, steel has several advantages over cement, such as a higher tensile strength, enabling stronger structures with less material; cement is a brittle material while steel is ductile, steel can also resist higher thermal loads. Additionally, steels can be engineered to withstand harsh environments and resist corrosion. Corresponding lab-scale experiments, simulated in an autoclave solely constructed for the proof of concept of hyperbaric WAAM, are carried out to investigate the fundamentals of this process and material properties for downhole applications. The general project description, laboratory set up and design, including process requirements such as voltage, current, shielding gases, and material properties, are presented. With this proof of concept, an alternative technology will be enabled with the potential to revolutionize wellbore P&A. Once this POC has been proven, the deployment method will be assessed. It is foreseen that some of the benefits of developing such tool will be the introduction of rigless or with smaller workover units P&A operations. Additionally, an entirely new way of applying additive manufacturing is proposed to solve compelling challenges in the O&G industry.
Characterization of Reservoir Properties Calibrating with Production Data for Carbon Capture and Storage in the Depleted Gas Reservoirs - An Integrated Assisted History Matching Approach for Reservoir Simulation
Authors: Tripoppoom Sutthaporn , Doungprasertsuk Chonlada , Pongthunya Potcharaporn , Prasertbordeekul Taweewat 
Published: October 2023

Abstract
One of a key responsibility for oil and gas industry is to ensure the balance between energy sustainability and minimizing the net carbon footprint to the environment. PTTEP, Thai national oil and gas company, has aligned this goal to achieve net zero greenhouse gas emission in 2050. Therefore, the scope of this project is to utilize carbon capture and storage (CCS) technology by injecting CO2 into the depleted reservoirs in the Gulf of Thailand.
To evaluate the feasibility of the project, the simulation model was required to mimic the physics behaviors, including free gas structural storage, residual trapping, soluble gas in water and mineralization, when the CO2 was injected into many layers of depleted reservoirs. This is to obtain the optimized scenario for CO2 injection. However, the key step for reservoir simulation is the history matching by calibrating the model with production data.
First, the static model was built by integrating geological understanding, well data, logging data and petrophysical interpretation, core data, and quantitative interpretation (QI) from seismic data. Then, the subsurface uncertainties were captured and transferred to dynamic model for history matching step. The sensitivity analysis was performed to understand causes and effects and determine the significant uncertain parameters. Then, the assisted history matching was performed to explore the possible solutions using evolutionary algorithm. Lastly, multiple realizations of history matching solutions were obtained.
From sensitivity analysis, the key parameters to be calibrated with production data and routine shut-in bottomhole surveys are gas-water contacts, porosity and permeability correlation and relative permeability endpoint parameters. From history matching solutions, we narrowed down the range of uncertainty of uncertain parameters during history matching. The pressure, gas and water production could be matched. Obtaining the calibrated model from history matching is the critical step because this will determine the feasibility of the project in terms of injection strategy and CO2 storage volume.
This study was the first history matching task performed for Thailand CCS project. The practical and robust history matching workflow used in this CCS project could be set as a milestone and provides the guideline how to implement assisted history matching technique for any future CCS projects.
Low-Cost Approach to Significantly Reduce Operational Cost and Improve Facility Reliability in Banyu Urip Acid Gas Removal Unit (AGRU)
Authors: Wijaya Vicky , Kaswan Sutrisno 
Published: October 2023

Abstract
Acid Gas Removal Unit (AGRU) is used for fuel gas (FG) production in Banyu Urip Facility, Indonesia. AGRU was operated at the 50% design capacity due to low FG demand with several operation limitations due to AGRU Wet Surface Air Cooler (WSAC) poor performance. This condition led to off-spec fuel gas production with higher H2S and high temperature which adversely impacted fuel gas compressor (FGC) reliability. Consequently, frequent problem in FGC interrupted FG supply to Gas Turbine Generator (GTG) and lead to excessive diesel consumption to substitute FG for electricity generation in the facility. This causes a high operational cost. Additionally, the facility could not be pushed to operate in higher rate for production optimization. The WSAC improvement then became critical to sustain FG supply and reduce operational cost.
Debottlenecking study to improve AGRU system performance was performed resulting in several improvement initiatives. Based on the study, significant heat transfer deterioration was observed at the WSAC 1st stage due to higher operating temperature compared to the 2nd stage. In addition to this, some required design improvements were also identified based on learning from historical failures such as water sprayer upgrade to anti-clogging type, motor and fan replacement for better induced draft cooling, and plenum material upgrade for better corrosion resistance. Therefore 1st stage bundle replacement with upgraded design was progressed.
Post tube bundle replacement and combine with the chemical treatment, the AGRU WSAC heat transfer performance was increased by 75% and GTG diesel consumption was reduced substantially by ~70%. This contributed to $1M annual operational cost saving with project investment at only $650K. This fit for purpose project is more beneficial compared to the whole WSAC replacement which costs $2.4M.
This condition also provided flexibility to run more GTG to produce more power for the facility. Additionally, by allowing more gas to be processed in AGRU, it helped the facility to optimize oil production.
Downhole Drilling Tool Services Personnel Multi-Skill Implementation in Indonesia
Authors: Noviasta Bonar , Permanasari Devita 
Published: October 2023

Abstract
In a standard conventional oil & gas service, each specialized downhole drilling tool service requires dedicated personnel to execute the field operation. This includes but is not limited to measurement while drilling (MWD), logging while drilling (LWD), directional drilling (DD), casing while drilling (CWD), underreaming service, loss circulation management tool service, drill bit performance service, and many others. In a complex drilling bottom hole assembly (BHA) deployment, multiple skilled-personnel presences at the rig site are required which consequently increases the service cost, the personnel safety risk, and the drilling performance risk caused by multiple chains of communication. Additionally, smaller rigs with less person on board (POB) capacity might become a limitation for multiple services to be deployed. From the environmental sustainability perspective, more personnel cause higher carbon emissions from the drilling operation.
The Multi-skilling approach for the downhole drilling tool services workforce is the solution for future Oil & Gas operation sustainability. The integration capability of the oilfield service company enables the workforce training matrix to be designed adapting the drilling challenges. The cross-training framework was made available in the forms of base-workshop training checklists, online web-based or virtual instructor-led training, offline courses, and on-the-job training. The multi-skill training pathway for each individual is also tracked and monitored, to ensure all downhole drilling service personnel are equipped with sufficient competency.
The multi-skilling was successfully deployed in several projects in Indonesia. A land operation in East Kalimantan executed the DD & MWD operation with fewer personnel by having MWD cross-trained to DD to cover the night shift alone (supported by remote operation), contributing to 25% more personnel-efficient operation. An offshore project in East Kalimantan also completed the drill bit performance service - Directional Drilling – Logging While Drilling – Underreaming While Drilling – Loss Circulation management tool services in an integrated approach with personnel multi-skill, contributed to 42% personnel efficiency by deploying only 4 personnel instead of 7 persons in a conventional way.
Success Story of a Novel Completion Technology of Hybrid ESP-Gas Lift System Trial
Authors: Pramana Harris , Mario Cio Cio , Nugrahanto Anang , Hakim Arief Lukman , Eviany Ameria , Murtani Anom Seto 
Published: October 2023

Abstract
Selection of the most suitable production technologies; namely the type of lift to be used, to the design and implementation for well conditions has been one main responsibility of petroleum engineers. In an especially limited offshore field, not all methods are applicable as platform spaces, operating costs, and system reliability are needed to be considered. System reliability, for instance, entails well production profile to meet the acceptable operating range and to perform within specific run life to be rendered economic.
Ujung Pangkah offshore field, located within Pangkah PSC Block off the northeastern coast of Java Island has been discovered in 1998 and carries on production since 2007. Having a typical gas cap with an oil rim, carbonate reservoir; Ujung Pangkah field has since been developed with commingle completion targeting both separated layers of oil zone and gas zone, utilizing only gas lift as its main artificial lift method. Concern for alternative lifting methods has arisen since 2019, due to the limitation of gas lift injection capacity that is no longer adequate for the current and future development wells at that time. Considering this challenge, Saka Energi Indonesia decided to perform ESP (Electrical Submersible Pump) trial on 2 wells.
By design, the proposed completion will be of a hybrid ESP-Gas Lift, possessing both ESP components and typical gas lift components. ESP is decided to be the next artificial lift method to be applied because currently there are unused electric capacities from Gas Turbine Generators. To satisfy the acceptable range of ESP design criteria, both wells are equipped with AGH (Advanced Gas Handler)/Gas Separator, along with a gas vent line to produce this separated gas through the annulus. To fulfill the required dual-barrier-policy in offshore conditions, these wells are using specialized, feed-through-ESP hydraulic packer that enables ESP cable and gas vent line to be passed through. To ensure these wells reach the economic limit of ESP installation, this hybrid completion design is used; utilizing ESP as the main artificial lift and gas lift as a backup so that the well can still be produced with gas lift when ESP experiences failure.
On the implementation side, the installation of ESP with backup gas lift on 2 wells has been successfully improving production, each up to 4.5 times and 1.5 times its previous oil rate pre-installation. Despite the first ESP being out of commission, ESP run life has been satisfied and the relative economic limit for the installation has been reached. In addition, the well can still be flowed with a backup gas lift system while waiting for pulling operation, which significantly extends the well run life and overall boosts the well's economic value.
Preserving Business Resilience - AI Driven Drilling Automation as the Engine of Change for Sustainable Performance
Authors: Khazali-Rosli Khairul Amir , A Murad M Syazwan , A Mokhti M Ridzuan , Jamal Jasrudin , M Zurhan M Syahmi , Mat Noh Nurfitrah , Kereshanan Marlene , Abdul Rashid Khairul Asyraf , Zuan Ting Shui , Herrera Carlos , Goodkey Brennan 
Published: October 2023

Abstract
Today’s demand for sustainable and affordable energy in a volatile business environment is challenging the conventional manual drilling operation. Digital and automation opens the possibility to achieve higher levels of performance and consistency while paving the way towards net zero. To realize this possibility, for the first time in Asia Pacific, a technology collaboration project was initiated to deploy an automation system that could be integrated into the rig control together with another automation application to complement the overall drill-a-stand workflow.
An automation system that is integrated into the rig control system to control the top-drive, drawworks, mud pumps, and auto-driller to autonomously execute drilling activities was introduced in this project. Using its artificial intelligence engine, the system automatically mapped and executed the required activities such as ROP optimization, stick & slip mitigation, shocks & vibration and stringer mitigation and telemetry downlinks to achieve the user requested goal. This paper will focus on two points, the first will be the technology employed and its integration with another digital provider and an OEM, its impact on processes and user adoption, procedural adherence, and its role in improving operational efficiency and performance. As this is the first of its kind, the second focus point will be the continuous process and technology enhancements introduced during the project based on the result and user feedback e.g., reducing multiple handovers between different applications.
After 10 months of operations, over 10,000m were successfully drilled with automation. A very high level of adoption has been a catalyst for continuous improvements in procedural adherence and operational efficiency in the project. Ultimately, this has contributed to an increase in operational safety, rate of penetration (ROP) and an increase in downlinking efficiency and drillers’ time utilization. The results achieved will be exhibited to communicate the specific areas for amelioration and to highlight the potential that drilling automation can unlock for the industry.