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Results
Abstract Measuring HSE performance is vital when dealing with the implementation and execution of multiple Drilling Contractor HSE programs to ensure expectations are achieved throughout each rig contract life cycle. The HSE rig ranking program works as an HSE measuring tool by effectively consolidating eleven (11) leading and lagging key performance indicators (KPIs). KPI's such as total recordable incident injury rate (TRI-IR) and the Lost time Incident Injury rate (LTI-IR) as well as incident potential and inspection performance and compliance are all amalgamated into an all-inclusive scoring system with unprecedented results. Measuring, monitoring and benchmarking the health, safety and environmental performance of drilling contractors and their contracted rig fleet through this structured and comprehensive rig ranking program has organically spawned not only growth in behavioral based safety but also promoted a more robust HSE culture. The rig ranking methodology applied has facilitated greater contractor HSE oversight, resulting in not only healthy contractor competition but also substantial HSE performance improvements among the various drilling contractors and their respective rig fleets due to reductions in injuries, near misses as well as the severity of incident occurrences and improved adherence to established HSE requirements. Combining both lagging and leading indicators into a single Rig HSE performance score requires the efficient exploitation of both current and historical data and the HSE trends of each individual contracted rig and accurately weighting the impact of each of the 11 leading and lagging KPIs to arrive at a single representative score for each rig on contract. Each drilling contractors’ fleet of rigs is scored and benchmarked monthly and shared discreetly to contractor management team in an effort to provide a better understanding of their fleets HSE performance among their competitors and within their organizations. This rig ranking methodology identifies both high and low performance rigs, resulting in targeted intervention of low performance rigs and allowing for best practices of high-performance rigs to be cascaded downward to the lower echelons of the rig ranking scale. HSE practitioners engaged in site visits are equipped with a greater understanding of a rigs specific HSE improvement needs. As a result, the HSE rig ranking system facilitates a tailored site specific HSE message as opposed to broad, general safety improvement engagement. Since the inception and deployment of the HSE rig ranking program in 2018 a 240% increase in rigs performing in the Excellent range was achieved by October 2021 and behavioral based safety reporting increased over 255%. Recognition is also a key component of the rig ranking process and is incorporated communicate the achievements demonstrated and improvements made as well as sustained performance. The HSE Rig Ranking Program has contributed to fewer incidents, safer operations and is a recommended method of monitoring contractor drilling HSE performance.
Abstract Although polymer flooding technology has been widely applied and achieved remarkable effect of increasing oil. Yet the "entry profile inversion" phenomenon occurs inevitably in its later stage, which seriously affects the development effect. The dispersion system is a novel flooding system developed in recent years. Due to its excellent performance and advanced mechanism, it can slow down the process of profile inversion, and achieve the goal of deep fluid diversion and expanding swept volume. The dispersion system consists of dispersion particles and its carrier fluid. After coming into porous media, it shows the properties of "plugging large pore and leave the small one open" and the motion feature of "trapping, deformation, migration". In this paper, the reservoir adaptability evaluation, plugging and deformation characteristics of dispersion system in pore throat is explored. On this basis, by adopting the microfluidic technology and CT tomography technology, the research on its oil displacement mechanism is further carried out. Furthermore, the typical field application case is analyzed. Results show that, particles have good performance and transport ability in porous media. The reservoir adaptability evaluation results can provide basis for field application scheme design. Through microfluidic experiments, the temporary plugging and deformation characteristics of particles in the pore throat are explored. Also, the particle phase separation occurs during the injection process of dispersion system into the core, which makes the particles enter and plug the large pore in the high permeability layer. Therefore, their carrier fluid displace oil in the small pore, which works in cooperation and causes no porous media and the distribution law of remaining oil during displacement process are analyzed. It shows that, particles presents the motion feature of "migration, trapping, and deformation" in the porous media, which can realize deep fluid diversion and expand swept volume. 3D macro physical simulation experiment shows that, particles can achieve the goal of enhance oil recovery. Finally, the dispersion flooding technology has been applied in different oilfields, which all obtained great success. Through interdisciplinary innovative research methods, the oil displacement mechanism and field application of dispersion system is researched, which proves its progressiveness and superiority. The research results provide theoretical basis and technical support for the enhancing oil recovery significantly.
- Asia > China (0.46)
- North America > United States > Wyoming > Sweetwater County (0.40)
Abstract Mangala is a large low salinity, high quality fluvial oil field reservoir in India with STOIIP of over one billion barrels of waxy and moderately viscous crude. Aqueous based chemical EOR has been identified as the most suitable technique to improve recovery over waterflooding. The objective of this paper is to describe the ASP formulation development journey for Mangala which involved more than 30 corefloods till date with evolution of formulation design changing over time. The final selected formulation has been successfully tested in upper layer of Mangala field during pilot and is being planned to be used in full field. Initial formulation design was done using IFT (interfacial tension) and adsorption measurements approach. Later the formulation design was done using classic phase behavior approach which allowed quick and robust evaluation of large number of chemicals in a short duration. Typically, the formulation development involves phase behavior tests, aqueous stability test, salinity gradient design, dead oil and live oil coreflood on long linear synthetic and reservoir core plugs. A successful formulation shall have low viscous microemulsion phase, solubilization ratio greater than 10 (ultralow IFT), very low residual oil saturation, good thermal and aqueous stability, low adsorption, low chemical concentration and fewer components among many other parameters. Initial formulation basis IFT measurements was selected and tested under multiple corefloods (IPTC 12636). Later, basis the phase behavior approach, another formulation consisting of 0.3% surfactant and 0.3% co-solvent was formulated (SPE 129046). For Mangala, solubilizing paraffinic waxy crude required usage of large carbon chained Alkyl Benzene Sulfonate. Formulation with hydrophobic surfactant required addition of a hydrophilic surfactant and a co-solvent. Co-solvents, though improve electrolytic strength, add significant chemical cost and are some-times unstable. Finally, a highly hydrophilic alcohol alkoxy sulfate was selected to substitute the role of co-solvent but still maintain enough electrolytic strength. The formulation consisted of 0.3% surfactant, 3% alkali and 0.25% polymer in soft water which was used during a successful pilot (SPE 179700). The formulation has been further optimized to reduce the overall chemical quantity (SPE 200445) to 0.25% surfactant and 2.5% alkali. Additionally, formulation has been validated on other layers of Mangala field under high pressure live oil phase behavior and live oil reservoir coreflood. This paper discusses ASP formulation development approach, technical requirement, development journey of formulation for successful Mangala ASP pilot, optimization efforts undertaken to reduce the chemical usage and validation of formulation for other layers of Mangala reservoir. This paper also briefly discusses lab quality control guidelines that is being developed for large scale procurement of chemicals for full-field ASP floods.
- Geology > Mineral > Sulfate (0.34)
- Geology > Sedimentary Geology > Depositional Environment > Continental Environment > Fluvial Environment (0.34)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Rajasthan Block > Mangala Field > Fatehgarh Formation (0.99)
- Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Rajasthan Block > Mangala Field > Barmer Hill Formation (0.99)
- Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Block RJ/ON-90/1 > Mangala Field > Fatehgarh Formation (0.99)
- Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Block RJ/ON-90/1 > Mangala Field > Barmer Hill Formation (0.99)
Arthit CO2 Membrane Optimisation to Tackle Greenhouse Gas Emission Issue
Pechvijitra, Pimpisa (PTTEP) | Watanakun, Kantkanit (PTTEP) | Assavanives, Boonyakorn (PTTEP) | Tantiviwattanawongsa, Mongkol (PTTEP) | Rakdee, Sukit (PTTEP) | Wuttikiangkaipol, Eakamol (PTTEP) | Binhayeeniyi, Alawee (PTTEP) | Ammaro, Songwut (PTTEP)
Abstract One of the most pressing environmental concerns in the Oil and Gas industry is greenhouse gas (GHG) emissions. Therefore, PTTEP (Company A) has committed Net Zero emissions by 2050. At the Arthit field in the Gulf of Thailand, the majority of hydrocarbon loss to flare is mainly from the CO2 membrane where the permeate stream is continuously and directly emitted via the acid gas flare. To align with our company's vision, the most practical approach to reduce GHG emissions at the Arthit field is to decrease the amount of hydrocarbon loss to flare by increasing %CO2 in the CO2 membrane permeate gas because CO2 contributes to greenhouse gas emissions much lower than hydrocarbon at the same emission flow rate. To minimize hydrocarbon loss, it is essential to maximize %CO2 in the permeate gas by optimizing the CO2 membrane performance. However, it has to ensure that the heating value of the permeate gas is sufficient for complete combustion. Thus, the more selective CO2 membrane model is required by adopting the newest technology. At the Arthit field, the new membrane product is selected as its selectivity is better than the existing models. With the new membrane, it is a challenge to further investigate the optimal configuration, specifically to the Arthit field's current operating conditions, in terms of the feed flow rate, the permeate pressure, the inlet temperature, and the sequence of the preceding dehydration unit. The investigation to optimize the CO2 membrane is successful according to the results from the intensive trial tests as follows:"Flow Allocation Optimization" determines which CO2 membrane banks should be operated with the new membrane element product. The results indicate that hydrocarbon loss from the existing and the new membrane element models are dependent on the flow rate. Operating too low flow rate compounds hydrocarbon loss. "Permeate Pressure Optimization" reveals that the lower permeate pressure results in the higher %CO2 in permeate, but the higher permeate flow. Too low and too high permeate pressures aggravate hydrocarbon loss. "Inlet Temperature Optimization" indicates that increasing the feed temperature exacerbates hydrocarbon loss. It is necessary to keep the inlet temperature at the minimum, but the margin must be maintained to prevent hydrocarbon condensation. "Dehydration Unit Sequence Adjustment" pinpoints that the extended cooling time attenuates GHG emissions as it reduces the spikes from the heating steps that worsen hydrocarbon loss from the high temperature. Auspiciously, hydrocarbon loss is reduced from 4.66 to 3.58 MMscfd and from 5.55 to 4.73 MMscfd for low and high nominations, respectively. In other words, 39,000 tCO2e/year of GHG reduction is achieved. Furthermore, the revenue of 33.40 MMUSD will be gained until the end of concession. In order to drive Company A one step closer its milestone, it is crucial to keep GHG emissions from each operating field at the minimum. Since both of the Arthit field and the Greater Bongkot South field, the other offshore gas field in the Gulf of Thailand, have a CO2 membrane unit at a processing platform, the CO2 membrane optimization project at the Arthit field can be further applied to the Greater Bongkot South field and other offshore gas fields to minimize hydrocarbon loss and ameliorate the adverse effects of global climate change.
- Asia > Thailand > Gulf of Thailand > Arthit Field (0.99)
- Asia > Thailand > Gulf of Thailand > Bongkot Field (0.94)
Artificial Lift Optimization with Data Based Predictive Approach for Pre-Emptive Changeovers of Jet Pump in Polymer Flooded Field
Kumar, Manish (Cairn Oil & Gas, Vedanta Limited) | Varma, Nakul (Cairn Oil & Gas, Vedanta Limited) | Badhe, Saurabh (Cairn Oil & Gas, Vedanta Limited) | Pawar, Sachin (Cairn Oil & Gas, Vedanta Limited) | Chauhan, Shailesh (Cairn Oil & Gas, Vedanta Limited) | Bohra, Avinash (Cairn Oil & Gas, Vedanta Limited) | Savelyev, Anatoly (Cairn Oil & Gas, Vedanta Limited)
Abstract Mangala field is one of the largest discovered group of oil fields in Barmer Basin, Rajasthan, India. The fields contain medium gravity viscous crude (10-40cp) in high permeability (1-5 Darcy) sands. Currently the field is on polymer flood to improve the sweep efficiency during enhanced oil recovery. As expected, polymer breakthrough was observed in producer wells. However, this has resulted in challenging well interventions due to polymer/scale depositions in the wellbore and Downhole artificial lift equipment. This issue has surfaced due to mixing of produced polymer with scales, wax and various bivalent ions. Major concerns due to polymer deposition included, fouling of artificial lift system, decrease of well uptime and decreased efficiency of jet pump (type of artificial lift). Reverse jet pumping, where power fluid is pumped through annulus and production is taken through tubing, is the most common method of artificial lift for the field. During jet-pump redressing, polymer deposition has been observed in the Body X-over (Reservoir liquid path), check valve assembly, throat and spacer nozzle to throat inside jet-pump. Continuous chemical injection was tried and proved to be a technical success, but it was not cost effective. Hence data-based predictive approach for pre-emptive changeovers of Jet Pump was developed. The developed model is "intelligent". It learns from every newly logged event and auto correct its approach of marking the risk levels of a well. The well intervention history of over 1000+ well interventions in 170+ oil producers were recorded. The recorded data was then studied for sensitivities such asnumber of interventions viz. – wire scratcher run and Jet pump retrieval / installation runs Observations on severity of polymer/scaling issue Chemical soaking requirement of chelating agents such as EDTA, DTPA for dispersing polymer, Well downtime Histories of slickline fishing events, stuck BHAs. The data was then analyzed and used to create a well intervention risk matrix which in turn classifies all 170 wells into low, moderate and high-risk wells. This approach also sets a predictive timeline for individual well failures. The model/approach is intelligent enough to learn from operational history and auto-corrects itself every time a new event is logged. This paper addressesFormation of agglomerated polymer lumps due to scale formation inside well completions. Deposition of polymer layer inside completion equipment and production tubing Detailed stepwise analysis of over 1000+ well intervention in oil producers producing oil and polymer mixed water. Basis of logic for creating a predictive sheet for Jet Pump change outs. Predict optimal Intervention frequency for every well to de-risk jet pump change slickline intervention Determination of critical wells which have severe deposition issues Tracking of rigless units’ efficiency and planning, especially highly mobile slickline unit Optimize production from field Plan for chemical soaking in tubing of wells where polymer and scale deposition are predicted. This paper gives a new approach to those E&P companies who are producing their field on Jet pumps and are using Polymer flood as recovery mechanism. The use of this approach from day zero in such fields would help to create a customized analytical approach for the field and hence reduce production downtime.
- Asia > India > Rajasthan > Rajasthan Basin > Rajasthan Field (0.99)
- Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Rajasthan Block > Mangala Field > Fatehgarh Formation (0.99)
- Asia > India > Rajasthan > Rajasthan Basin > Barmer Basin > Rajasthan Block > Mangala Field > Barmer Hill Formation (0.99)
- (2 more...)
Fostering and Sustaining Employees’ Happiness in the Oil, Gas, and Energy Industry: the Role of Organizational Chief Happiness Officer in Implementing Happiness Initiatives and Programs
Alzain, Hassan (Saudi Aramco) | AlGhazal, Rym (Saudi Aramco) | Abu Qurain, Ali (Saudi Aramco) | Karkadan, Mona (Saudi Aramco)
Abstract The well-being of employees is catching momentum among various demanding industries across the world, underlying the importance of introducing and maintaining effective happiness initiatives to foster successful employees ’engagement with their line management to work better together and build loyalty to the workplace. This paper, therefore, aims to detail the strategic benefits of happiness initiatives along with the expected business benefits on long-term basis. A happy employee is defined as a productive and loyal employee. When an employee is happy, they tend to display greater engagement with their job. Similarly, studies have shown that when an individual feels "heard" and that their voice matters, their levels of morale are higher. Moreover, when equipped with the right tools to cope with a stressful environment, a worker's level of productivity and the quality of their work improves. The data collected at the end of each initiative is an important reference and resource for companies with a high number of employees across various specialties. This paper will provide the background of the importance of happiness initiatives, as well as making the first steps towards cultivating a culture of happiness in the more traditional industries, especially including the oil, gas and energy industry. The concept of a happiness initiative, especially in relation to international best practices, is currently not widely applied in traditional industries with evidence on the lack of a true sense of happy and productive engagement across different employees ’levels and contractors. Elevating happiness across organizations is, therefore, essential, as indicated by the fact that good mental health and well-being are core needs for any business to succeed in the post-COVID-19 era. Happiness at work is a relative, attainable concept that can be fostered and sustained in a more professional context, where organizations can play a vital and critical role in the research, establishment, and advancement of workplace happiness policies and frameworks on strategic basis that will positively result in tangible and non-tangible business benefits. This paper will outline mechanisms, best practices and the role of "Chief Happiness Officers" in leading tailor-made happiness initiatives to address organizational-specific needs and emerging issues.
- North America > United States (1.00)
- Asia > Middle East > UAE (0.28)
- Asia > Middle East > Saudi Arabia (0.28)
- Health & Medicine > Therapeutic Area > Psychiatry/Psychology (1.00)
- Health & Medicine > Consumer Health (1.00)
- Energy > Oil & Gas (1.00)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility (1.00)
- Health, Safety, Environment & Sustainability > Health (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (1.00)
- Management > Professionalism, Training, and Education > Communities of practice (0.69)
Utilizing Digital Enabler to Attain Excellent Safety, Security, Health, and Environmental Performance
Tiengtrong, Wannoptida (PTT Exploration and Production Public Company Limited) | Suwannaposi, Rachamon (PTT Exploration and Production Public Company Limited) | Klunngien, Chagun (PTT Exploration and Production Public Company Limited)
Abstract This paper explains how digital enabler can help an organization enhance the Safety, Security, Health, and Environmental (SSHE) awareness of employees and contractors and compliance with SSHE requirements. The unique features of digital enabler are creatively designed to provide a set of solutions for managing SSHE data that meet the needs of the oil and gas industry. It is an innovative digital solution that helps the organization achieve excellent SSHE performance. The PTTEP digital enabler, iSSHE, is developed to support the SSHE management system and respond to current and emerging SSHE challenges. It can help an organization collect, manage, and analyze SSHE data to prevent incidents while maintaining operations, complying with regulatory changes, and improving sustainability. Reporting SSHE data is just the beginning. With iSSHE, on the other hand, we can shift our focus from reactive compliance with applicable requirements to proactive performance management with an integrated SSHE management approach. The goal of iSSHE is to ensure SSHE data and resources are well-collected, managed, and shared across business units to fuel forward-looking results for continuous SSHE performance improvement. This integrated approach connects stakeholders, information, and insights across the entire risk value chain. iSSHE solution combines a responsive, configurable, and intuitive cloud-based platform. It enables better decisions and optimizes SSHE performance. Adopting SSHE digital technology transforms all SSHE-related information and implementation by replacing non-digital or manual processes with digital ones. The key benefits of utilizing digital enablers to support the SSHE management system are as follows: Reducing the scope for errors in data reporting Saving time while increasing productivity Improving SSHE performance Connecting employees and contractors across different departments and locations in the organization Standardizing and centralizing SSHE data Lessening risks and building safety awareness Helping manage regulations and stay compliant Serving to predict future performance with analytics of historical data Driving insights that enable better and more sustainability decisions
- Government > Regional Government > Asia Government > Thailand Government (0.49)
- Energy > Oil & Gas > Upstream (0.49)
Abstract Consistent ethane recovery in the Natural Gas Liquefication (NGL) process is critical to achieve financial objectives of the NGL processing facility. Joule-Thompson (JT) effect in combination with various processes such as cascade-refrigeration or Residue-Split-Vapor (RSV) are being used in the industry to maximize the ethane recovery from the feed gas varying in the degree of 75% to more than 95%. Identifying the transient conditions and ensuring precise and accurate control throughout is of utmost importance. The transient conditions are categorized as start-up or a scheduled shutdown of the plant, and an upset of the plant. Any of these transient conditions may drive the plant in unstable state which would impact the ethane recovery drastically. This paper discusses a control algorithm that was developed to identify the transient states and to provide an accurate and stabilized control to keep the recovery above the target threshold. During the startup, a typical NGL plant will start its operation in JT mode and will slowly transition into a cooling mode by introducing turboexpander for example. During the shutdown mode, the plant slowly returns to JT mode by shutting down the turboexpanders. During the upset, the turboexpanders can accidently trip to force the plant in an unstable state. In transient states, an accurate control is required to precisely transfer the feed gas volume from turboexpanders to JT equipment or vice versa in a timely manner to minimize the impact such as loss of production or total plant trip. The proposed control algorithm predicts an upset in advance, captures the actual flow of the feed gas passing through the equipment prior to an upset and transforms the captured flow into an equivalent percentage opening of the backup equipment (in case of JT mode, the percentage opening of the JT valve and in case of turboexpander mode, the percentage opening of the Inlet Guided Vanes (IGVs)) to ensure the plant mass balance is maintained. The set point tracking feature of the algorithm ensures that when the normal Proportional Integral Derivative (PID) control is resumed the transfer of control is bump less to avoid any overshooting or undershooting of the overall plant pressure.
AWR-26 Topside Reuse Project
Boonthieng, Somsak (PTT Exploration and Production Public Company Limited) | Pairachavet, Nuntawatt (PTT Exploration and Production Public Company Limited) | Soraphetphisai, Witoo (PTT Exploration and Production Public Company Limited) | Poungthip, Wuttipong (PTT Exploration and Production Public Company Limited) | Sinthumongkhonchai, Chananwath (PTT Exploration and Production Public Company Limited) | Petcharoen, Charkorn (PTT Exploration and Production Public Company Limited) | Assadornithee, Puwadon (PTT Exploration and Production Public Company Limited)
Abstract Wellhead Platform AWP-26 was originally developed under PTTEP Arthit Phase 2C, completed installation in 2014 and started a production from 2016 to serve gas plateau and to sustain the Arthit production. Upon depletion of AWP-26 in 2019, PTTEP Arthit Asset realized the opportunity to relocate the AWP-26 to the new prospective location in order to maximize reservoir production. In 2021, the first PTTEP Topside Reuse Project has been put into the offshore execution stage where we proud to present in this paper. The main objective of the project is to convert the originally topside design AWP-26 to suit with new prospective location and renamed to AWR-26. The topside is reused where the subsea structure (so called "jacket") is newly built as to suit with new water depth and soil parameters at the new location. The existing jacket and subsea pipeline were left as is for future decommissioning. While waiting the existing jacket to be decommissioned, tentative in 2026-2031, it is important to install navigation lights system to warn the marine to avoid collision of the remaining jacket structure. The minimal and fit for purposed structure platform is then designed (so called "navigation aid platform") was fabricated and installed onto the existing jacket for safe marine operation. It is not so simple just to relocate and make use of the existing topside to suit with the new prospective location, there were tremendous activities to be considered, starting with engineering design to make the existing topside design to be technically compatible with new process parameters of the new prospective location. Following by the early stage for preparatory works in collaboration within an internal PTTEP parties (Project Construction, Arthit Asset, Arthit Operation & Maintenance and Logistic Team), for the activities including but not limited to; platform plug and abandon, removal of flowlines, preservation of Booster Compressor, collecting the base line inspection data for piping system, platform structural integrity check, etc. In addition, to ascertain the overall weight of topside was within the safe margin and clearly defined the Centre of Gravity (CG) for the topside lifting purpose, all the vessels, tanks, containers, associated piping including the sludge removal were performed.
- Government > Regional Government > Asia Government > Thailand Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract Effective August 2021, Malaysia Assets Reset has launched Clustered Maintenance Planning and Execution (CMPE) department towards value focused asset management. To align with the department aspiration to continually generating optimum cashflow as well as staff upskilling, this study focuses on one of CMPE key result areas, with its main objective is to steer frontline maintenance work practice to value-generation perspective. Cost-Benefit Analysis (CBA) process is used in this study to analyze which maintenance tasks to proceed and which to forgo. It is performed by comparing the cost of frontline maintenance versus outsourcing for a maintenance task over a period of time. Elements taking into consideration for the cost calculation are materials, special tools, additional cost required to ensure internal resources competent to perform the job, outsourcing contract rate (on annual basis), and logistics associated costs. Currently, CBA assessment has been performed by CMPE on 15 potential maintenance tasks which was previously executed via outsourcing. Based on the cost saving/cost incurred derived from Frontline Maintenance versus outsourcing, 14 of the tasks are classified as cost-effective. Taking into consideration of clustered planning and scheduling, each planner are required to further assess on the perspective of manpower availability and re-strategize on manpower arrangement to execute the maintenance task via frontline maintenance. This CBA assessment not only resulted to an increase of 29% total planned frontline maintenance activities in 2022 versus pool of activities performed in 2021 but also contributed to additional technical skill sets to perform value-added maintenance tasks. The assessment via CBA has added value-generation perspective in identifying cost-effective and feasibility of the activities selected. By performing this study, it has supported towards achieving the company End State Aspiration.