bluuebunny/crossref_metadata_2025_split huggingface dataset:
Innovative Approach on Maximizing Recovery and Sustaining Field Development in Sisi Nubi
Authors: Sjahbunan Putra , Handoko Bayu Setyo , Sianturi Julfree , Fatkhurroyan Bima , Jannatan Muhammad Ardhyan 
Published: October 2023

Abstract
Sisi and Nubi Fields are mature gas fields located in offshore Mahakam Delta, East Kalimantan Indonesia. These fields have been delivering 1.4 Tcf of gas and 33 MMstb of condensate, with total 77 development wells have been drilled and put on production until the end of 2021. By existing development scheme, the current development area is already saturated with wells, whereas most of other identified reservoirs are unreachable from existing facilities and most of them is even possibly having limited resources. This paper is intending to describe the application of innovative approach, by using data driven analytics and static-dynamic approach, in an integrated subsurface synthesis, which has successfully increased the field reserves, maximize recovery and prolonged its production life time,
Existing methodology on reservoir target identifications are mainly focused on integrated static-dynamic synthesis by using existing and new wells, through geomodelling approach and massive wells correlations. This approach would mainly focus on existing development area, gradually stepping out in full reliance on latest drilled wells data. Extending its study coverage for further development outside the wells perimeter (step-out), therefore, will only add risks and uncertainties due to lack of well control. As a consequence, further development has been slowed down waiting for static and dynamic data from available wells only.
The application of data sciences and machine analytics on seismic multi-attributes and wells data as input, provide insights on gas reservoir characterization within Sisi Nubi, expanding the coverage of gas identification outside current development perimeters. This method is called MAMA, Multi Attributes Machine Analysis. As it is able to successfully summarize the correlation between subsurface data, the subsurface synthesis, therefore, was concluded comprehensively.
North Sisi and North Nubi wells, as a continuation of field development project, have been successfully drilled in 2022 with outstanding results, especially in post drilling estimated reserves. Apart from MAMA method, there was an integrated static & dynamic approach, that has successfully lead to faster development, less risks (success ratio ~90%) and better Estimated Ultimate Recovery (EUR) predictability.
The application of data-driven analytics will surely be a revolutionary step in Mahakam or even in a wider petroleum industry. It would enable to locate any potential development area outside the current development perimeters, while giving higher possibility of success and better predictability, that in the end will significantly help any field development strategies.
The Journey Towards Effective Grievance Mechanism in Upstream
Authors: Che Arshad Afzariah Binti 
Published: October 2023

Abstract
The United Nations Guiding Principles on Business and Human Rights (UNGP BHR) provides a clear framework in managing the aspect of human rights for governments and business sectors. While the governments are responsible to protect the human rights, businesses must respect these human rights and ensure an adequate access to remedies for the affected stakeholders. A well-designed grievance mechanism is a pivotal element in promoting accountability and transparency, with all due respect to human rights within the Company.
This paper elaborates on the remarkable journey of PETRONAS Upstream in Malaysia, namely PETRONAS Carigali Sdn. Bhd. (PCSB) in building a robust grievance mechanism management for effective and legitimate compliance with host any authority requirements, comprehended by a unique and customized approach that others can replicate.
Holistic Approach of Inorganic Scale Inhibition Application in Extending Well Production Life
Authors: Mat Deris Nurul Asyikin Binti , Siew Caleb Jia Lih , Khoo Alan , Abd Rahim Mohd Adam Bin , Arief Saleh Fakhrul Amin Bin , Amsidom Amirul Adha Bin 
Published: October 2023

Abstract
Flow assurance problems such as inorganic scale formation in gas lifted wells have been common in field production lifecycle and presence of higher water production accelerates this occurrence. Production impairment is the consequence of scale formation that can be eliminated by preventive measures in scale management.
The most effective technique for mitigating downhole scale formation is through the application of scale inhibitor solution injected into the near wellbore of the formation. Chemical selection is crucial to ensure effectiveness and longevity of the treatment for it not only to be technically proven but also economically viable.
Through rigorous laboratory testing and field trials, scale inhibitor squeeze (SISQ) has been the proven solution to effectively increase the productivity and uptime in most of the gas lifted wells in Hibiscus Oil & Gas Malaysia Limited assets.
The SISQ injection dosage and duration were designed based on well production and reservoir properties, and it is injected into the wellbore via the bull heading technique. The treatment has become a routine activity and well candidates are identified through scale mapping exercise.
This paper presents the journey of SISQ implementation in Hibiscus Malaysia Limited's operating fields which includes the history of actual SISQ monitoring trends and the frequency of SISQ being optimized. The cost saving and well uptime will also be discussed in this paper.
An Optimum Cloud Based Approach to Timely and Secure After-Tax Economic Analysis and Decision Making
Authors: Meulengracht Chresten Steen , Poulsen Henrik Meidell 
Published: October 2023

Abstract
The requirement for computing power in economic decision making is normally underestimated. It is already recognized in the oil and gas industry that for geologic and reservoir engineering calculations parallel computing power is necessary to carry out simulations of millions of cells. This paper explores he actual requirements for parallel computing for economic analysis covering decision making at all decision gates, and the added benefits of running calculations and databases in a secure cloud solution.
Economic analysis for typical oil and gas project decisions requires extensive analysis of alternative scenarios and assumptions, and robustness evaluation such as identification of after-tax key metrics and break-even values. A specific project scenario analysis is then be added to the full analysis for exploration decisions, portfolio mergers and acquisitions (M&A) decisions or selection of optimum development scenario at front end engineering and design (FEED) stage or life-extension projects. A key challenge for economists is that other disciplines do not always recognize the complexity of the analysis involved and the time required to provide the necessary decision basis for investment in multiple-billion dollar projects. Economists need to be involved at an early stage of the work process and have access to powerful computing power provided by appropriate tools in the cloud. Economic analysis is usually the last step in a series of work steps leading up to making an investment decision by management. A framework for such tools in the cloud was developed and applied to several real-case decision gate situations, including exploration, concept select, field development including life extension/enhanced recovery projects and portfolio M&A activities. Other aspects of using this framework with respect to speed, security and user friendliness was also evaluated.
An appropriate framework for covering all requirements for timely and secure after-tax economic analysis and decision making was successfully developed and applied to several real cases. This framework allows economists to define inputs and receive results in a fast and timely manner. Traditionally the discipline of economic analysis has not been considered computer-intensive or manpower-intensive, but this paper demonstrates that cloud computing is necessary and provides significant benefits and allows economic analysis to be performed faster and more timely, and still be very secure.
This novel cloud-based approach to full and extensive economic analysis fulfills all requirements for fast, timely and secure economic decision making at all decision gates including exploration, concept select, field development incl. life extension/enhanced recovery projects and portfolio M&A activities.
Dump-Flooding Electrical Submersible Pump (ESP) Approach and Lessons Learned in Sustaining Production Cycle
Authors: Nasharudin Nirwanshah , Siew Caleb Jia Lih , Ibrahim Mohd Zulfadli , Alexander Euan , Bespalov Eugene , A’akif Fadzil Nurul Aula , Bakar Hasmizah 
Published: October 2023

Abstract
Water injection for pressure maintenance is common in the oil and gas field to ensure a reservoir’s energy does not drop beyond the limit which will jeopardize production over time. Most of the major oil companies utilize the produced water on surface for injection or treated seawater either as pressure support or as a sweeping catalyst to recover as much hydrocarbon possible.
Water dump-flooding is one of the less common methods of pressure maintenance as compared to surface injection. This method utilizes the shallower aquifer sand as the inflow to feed the deeper reservoir. As a mature field of water-flooding, downhole injection does fit the purpose in theory but there are many considerations which need to be addressed before embarking on this route.
Even though well intervention technology has advanced in recent years, most companies would rather keep well intervention as simple and quick to avoid increasing Operating Expenditure (OPEX) which will push further the job priority. This is due to the well's accessibility, especially for offshore settings with limited space and operating window duration, especially when weather is known to be the main showstopper. Subsurface issues such as sand migration, gas handling, reservoir souring and scaling may also contribute to the system's inefficiency, which may result in system failure. Installing an ESP especially with an inverted pump does need an extensive monitoring capability be it downhole or on surface. Lack of essential data handling will often lead to malfunction which results in an expensive operation of pulling and total workover.
The dump-flooding method was chosen as the field has an existing aquifer with no serious compatibility issues across different reservoirs. The idea was deployed considering the existing platform capability with minimum modification on surface whilst ensuring the reservoir is being supported continuously. Downhole sand control for the water source zone was necessary in the designing stage to mitigate formation failure based on its lithology that would interrupt the ESP efficiency. The supported reservoir requires constant pressure charging to sustain its production and realizing some of the future development plans.
This paper will talk through the process and challenges faced during the planning, designing, commissioning, and maintenance of the dump-flood ESP. The lessons learned are crucial to ensure the project is a success for supporting the reservoir with minimal operational obstacles during execution.
Strategic Approach Towards Technology Management and Implementation at Upstream Business
Authors: Tan Grace Ying En , Zulkifli Zuraida Wong , M. Noh Nurbalqis , Ismail Mohd Syahezat 
Published: October 2023

Abstract
This paper summarizes the strategic approach to support operationalization efficiency of technology implementation in PETRONAS Carigali. Technology agenda became one of PETRONAS main focus since 2016. Implementation of new technology allows for improvement in production efficiency and allows company to be competitive. With high number of technology project being introduced, an effective and efficient technology management process is required to ensure optimum resource utilization and to manage technology specific risks. As a wholly owned subsidiary of PETRONAS, PETRONAS Carigali was entrusted to reinforces the strategy for this renewing focus in technology.
Since 2018, a dedicated department had been established in PETRONAS Carigali, named Upstream Technology Management (UTM), with intention to facilitate the deployment of technology in Upstream, aligning to PETRONAS Technology Agenda. Fast forward to 2020, UTM was restructured to Technology Excellence (TEX) Unit with the main focus of ensuring compliance to proper process, governance and to support the operationalization efficiency of overall PETRONAS Carigali Technology. At presence, the implementation of technology at PETRONAS Carigali is guided by several frameworks, in which the two main documents are PETRONAS Technology Management System (PTMS) and Upstream Project Management Standard (UPMS). TEX monitors two categories of technologies: in-house produced and off-the-shelf, and they are overseen by two technical approval sittings: Technology Readiness Level Committee (TRLC) and Proprietary License Technology Assessment (PLTA). Technology Readiness Levels (TRL) are a concept used to gauge a technology's level of maturity. According to the projects' progress and the technical standards established, each technology is assessed against a set of criteria before being given a TRL rating. At the same time, risk assessments are conducted using PLTA to determine the HSE hazards and compatibility with the existing process, equipment, and system at the chosen asset or facility. The PLTA is endorsed by relevant discipline Technical Authority and approved by Head of Asset prior to deployment.
In this paper, the Burke-Litwin Model was used to assess the present technology management and implementation at PETRONAS Carigali's upstream business to find any potential gaps and areas for improvement. As a result of the assessments, proposed changes to address detected misalignments were put in place to strengthen PETRONAS' internal governance documents. The development of the Technology Deployment Framework is expected to aid overall technology management and implementation across the project life cycle. In conclusion, with the right technology project management approach, field application of technology may be more efficient to deliver result at pace. Others could apply the approaches and lessons learned for similar reasons.
A Pragmatic Approach in Well Stimulation at the Late Field Life of Retrograde Gas Reservoir with Condensate Banking, Liquid Loading and Scale Issues: A Meaningful Failure
Authors: Mohamad Ruzlan Nur Syaffiqa , Navaratnam Dharshana , Azman Mohd Fairuz , Ayub Nur Afiqah , Mohamed Arsyamimi , Kamarul Zaman Nur Hazrina , Bernard Caesarsokate , Salleh Khiril Shahreza , Bakar Rizal , Rosland Eadie Azahar 
Published: October 2023

Abstract

Objectives/Scope
Retrograde gas reservoirs with pressure below dewpoint are exposed to severe formation damage and liquid loading issues due to condensate dropout and accumulation in the wellbore. To make matters worse, high water gas ratio leads to another problem like scaling. Historically, methanol soaking, matrix acidizing and nitrogen unloading have proven to be successful in treating these recurring issues during the early years, but it becomes more challenging with aging wells. Therefore, this paper aims to document the undisclosed operational challenges, setbacks and lessons learned for better job planning and execution in the future.

Methods, Procedures, Process
Well performance decline indicates severe skin build up. Pressure survey confirmed the presence of liquid level and Held-Up-Depth (HUD) in the well. The downhole samples were found to be predominantly calcite based on solubility test and Scanning Electron Microscopy (SEM) conducted in the lab. It is critical to first break through the HUD, hence Coiled Tubing Unit (CTU) was deployed to increase the probability of success considering the zone of interest is located inside casing section in a highly deviated well with depth more than 2500 m-MDDF. The treatment program consists of a three-stage process, started with matrix acidizing, followed by methanol soaking to dissolve condensate dropout, and nitrogen unloading to establish flowback post treatment.

Results, Observations, Conclusions
Challenges arise when multiple acid soaking and jetting failed to penetrate the HUD. CTU milling operation then had to be deployed. During the milling process another setback occurred when the circulation failed to be established. Nitrified fluid was first used to establish the circulation yet proved unsuccessful as the reservoir depletion was severe. Loss Circulation Material (LCM) was proposed; but not planned for, hence delaying project execution due to readiness and delivery time. Nevertheless, combination of LCM and Nitrified fluid eventually managed to establish circulation. As the operation resumed, tool stuck occurred, resulted in parts of Bottom Hole Assembly (BHA) to be left in hole. Samples from milling bit that were sent for SEM analysis found to be metal of Iron Oxide, suggesting the casing section may have already collapse.

Novel/Additive Information
Series of unprecedented setbacks call for a pragmatic approach when dealing with an aging well. The conventional method of solving productivity issue need to be improvise with emerging issues of depleted reservoir and compromised well integrity. Advance method of using camera run to confirm HUD type is highly recommended to avoid surprises that would risk job execution.
Managing Safety Risk and Oil Spill During Pre-Breakthrough Steam Flood by Steam Early Detection with Artificial Intelligent
Authors: Triananda Ade Hamzah , Aji Muhamad , Wibawa Ramdhan Ari , Silaban Meita , Pasaribu Rinaldi , Rifani Ria Ayu 
Published: October 2023

Abstract
Delta Area-X is the newest steam flood project in Delta Heavy Oil Field in Riau Province of Sumatra, Indonesia. The area currently produces 12,000 BOPD from 450 oil producers and 145 steam injectors that are supported by high proactive optimization that consists of steam cyclic stimulation, chemical stimulation, and pump optimization. The steam flood life cycle is divided into three general phases: immature phase, transition/steam breakthrough phase, and mature phase. Delta Area-X is currently entering the transition period. The transition phase is the most challenging period because steam has broken through for some producers. Many producer failures experiencing sanding problems, holes in pipes, rapid production changes, scale problems, etc. These are the challenges to completely heat the project area. At this period, the team is supposed to maintain and continue steam injection, conduct cyclic steam in cold producers to connect steam zones, and mitigate steam breakthrough impact on producers by building a fluid level and pinch casing valve. Steam rate reduction in this phase may delay heating area. Delta Area-X has experienced several steam breakthroughs events that caused the production casing line to be cut out and cause oil spills. To prevent similar cases, similar events should be identified earlier to know which wells, where and when for later on leading preventive actions.
Identification started by integrating data from surveillance data from field such as artificial lift, field operation pressure and temperature survey and production performance trend. Artificial intelligence was introduced to the identification process by pattern recognition artificial lift surveillance data to determine indication of steam. The result of Artificial Intelligence combines with dynamic well condition drives condition to meet: gradually detection and sudden detection to oil producer. Since there are many wells operated in the area, an exception signal is required to alert engineers only on wells that has potential issues.
Since application of steam breakthrough signal, the team can quickly make recommendations to manage steam by installing chokes, size up casing choke, reduce stroke per minute (SPM), reduce stroke length (SL) or the most massive action: shut in well oil producer / steam injector. Managing the steam will help controlling the steam causing casing cut out or oil spill and in term of steam flood management, it will redistribute steam to other wells or redirecting steam growth in order to have good sweep efficiency. Since the implementation of this approach, the team has identified more than hundred wells that were captured by steam breakthrough signals, then it followed up with appropriate action that successfully prevented potential safety hazard.
Predrill Geomechanical Modelling and Operational Guidance Helped to Successful Horizontal Drilling - A Case Study from Madura Offshore PSC, East Java, Indonesia
Authors: Panjaitan Julianta Parlindungan , Nurdin Didin , Putranto Heru , Situmeang Andy , Sagita Romi , Chrislianto Renaldi Mikhael , Ghosh Amitava 
Published: October 2023

Abstract
A horizontal drilling is considered to be a challenging drilling operation and require a proper pre-assessment study including subsurface, geomechanics and drilling practice. This paper will be taking the case from East Java basin as one of the prolific basins in Indonesia which are hydrocarbon proven with existence of multiple faults. The prospect Meliwis-2 was planned to be drilled horizontally within such heavily faulted regime. The key drilling challenges in the study area are drilling through the overpressure shale sequences and passing through multiple faults in the carbonate reservoir zone.
A geomechanical model was built using - limited well data combined with regional geological knowledge. Additional drilling information from other wells from nearby field was also incorporated in this study. Based on the offset well(s) review, some of the key challenges were significant drilling problems which mainly occurred after drilling, such as pack off, tight hole while pulling out of hole (POOH) and problems with running casing and wireline logging. Gain and losses were also observed while flow check and POOH the bottom hole assembly (BHA) in reservoir sections. The model that was built at the offset wells was then applied to perform pre-drill wellbore stability and fault stability of the planned Meliwis-2 horizontal well to optimize the drilling plan and minimize non-productive times related to borehole stability. Then the model was subsequently updated during drilling using the actual drilling and petrophysical information gathered from this new well.
The outcomes and recommendations of this study was meticulously followed with the operational guidance by drilling team to complete the well. The well was successfully drilled horizontally with expected data acquisition without any drilling issues due to borehole stability eventhough crossing multiple faults. The well was tested successfully and fulfilled the hydrocarbon expectation. This effort contributed to successful offshore development campaign within tolerance timely execution, budget and no reported HSE events.