Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022最新文献

{"title":"Revealed Banyu Urip New Opportunity: Integrated Subsurface Approach Leads to a Potential Field Production Increase Through Infill Wells Program","authors":"I. Sulistyaningrum","doi":"10.29118/ipa22-g-90","DOIUrl":"https://doi.org/10.29118/ipa22-g-90","url":null,"abstract":"Natural declining of oil and gas fields are inherent. It also occurs in the Banyu Urip field. Banyu Urip has been producing since 2009. The field has produced more than 540 million barrel oil (MMBO) with peak production around 220,000 barrel oil per day (BOPD) in 2021, currently producing about 170,000 BOPD. The field’s decline is observed from increasing gas to oil ratio (GOR) and water cut in almost all of the producer wells. The aim of this paper is to describe our efforts to offset Banyu Urip’s production decline by developing a new infill drilling program which has been characterized through an integrated approach by incorporating available static and updated dynamic data. Banyu Urip has a luxury set of subsurface data which we use to support the reservoir characterization and field performance analysis. Static and dynamic data, including production data and hydrocarbon contact monitoring are acquired regularly. In 2017, seismic data reprocessing was conducted with recent technology to improve data quality for better structural and stratigraphic interpretation. Integrating all of the available data with new interpretations and insights provided a better understanding of gross rock volume, reservoir characterization, fluid contact movement, subsurface risks uncertainties, and hydrocarbon volumes. Ultimately, improved geologic and reservoir simulation models were constructed that lead to identification of potential un-swept oil in the Banyu Urip carbonate reservoir area. Mining the existing data and applying new insights regarding subsurface evaluation and reservoir performance analysis resulted in new opportunity identification. The un-swept oil potential is identified mainly in the eastern and western areas. Several infill wells are planned to be drilled in late 2024 onwards which could generate incremental oil production to offset current decline and support national oil production.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130601147","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Alternative Utilization of Side Product Sulfur as Eco Bitumen Sulfur Paving Blocks in Gundih CPP in PT. Pertamina Work Area","authors":"A. Z. Abidin","doi":"10.29118/ipa22-o-129","DOIUrl":"https://doi.org/10.29118/ipa22-o-129","url":null,"abstract":"Sulfur is a non-metallic chemical element in the form of a yellow crystalline solid with the chemical formula, and is formed from several types of natural and artificial chemical reactions. Commercial applications of sulfur processed products can be found in various aspects of life, for example in the use of processed sulfur as paving blocks. The Gundih Central Processing Plant (CPP) is capable of producing 14 tons/day of sulfur pellets. This amount comes from the high H2S content of the wells with a total concentration of 20,000 ppm and a volume accumulation of 14 MMSCFD acid gas. H2S is converted to sulfur using the thiobacillus microbe in the Biological Sulfur Recovery Unit (BSRU) with a sulfur product purity level greater than 95%. In 2018 sulfur production at Gundih CPP was recorded at 4044 tons which could potentially trigger serious problems from an environmental aspect. The use of sulfur as material for making paving blocks is an alternative solution in addressing the potential impact on the environment, as regulated by Government Regulation No.22 of Year 2021 concerning the Waste Management of Non-Hazardous and Toxic Substances (B3), and the high cost of handling sulfur by third parties. The design mix of sulfur paving blocks is 42% of 3/16” aggregate, 40% of sand, 11.5% of sulfur pellets, 1.2% of bitumen, and 5.3% of fly ash. Bitumen as a binder for sulfur pellets is fully suitable as a replacement for Ordinary Portland Cement (OPC) material, the mineral cement used for the manufacture of paving blocks and bricks. The mixing process and casting temperature must be considered because they affect the ability to bind sulfur with other mixed materials. Strength tests of sulfur paving materials have also been confirmed by external laboratories. Currently, sulfur paving blocks are used in building access to wells locations and in public roads in the Cepu Field area as a contribution from Corporate Social Responsibility (CSR).","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"39 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130608537","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"De-Risking Exploration Well in A Mature Basin, Jabung Block, South Sumatra Basin: Application of Avo Analysis in A Sub-Unconformity Play","authors":"L. K. Muhtar","doi":"10.29118/ipa22-g-308","DOIUrl":"https://doi.org/10.29118/ipa22-g-308","url":null,"abstract":"The Late Oligocene to Late Miocene reservoir as well as basement in Jabung block has been proven filled by hydrocarbon. One of the unexplored intervals in this block is the sub-unconformity (Pre-TAF) play as angular unconformity, which is older than the Lower Talang Akar Formation (LTAF). However, this play has many risks, for instance in the geometry and quality of the reservoir. To de-risk the play, this study proposes to characterize the reservoir by Amplitude Variation with Offset/Angle (AVO/AVA) method for a better understanding of reservoir conditions. Rock physics analysis and AVO forward modeling provide information about reservoir quality. Moreover, the AVO attribute gives reservoir geometry. This study finds that Pre-TAF play reservoir is categorized AVO class 2 with negative value in both intercept and gradient, which indicates good reservoir quality similar to LTAF oil and/or gas reservoir. Several channels are well identified by the P*G AVO attribute that is distributed from basement high in Southwest to basin depocenter in Northeast NEB field. As the result of this study to prove the potential of Pre-TAF play, we are proposing EXPL-Plan-1 well as a play opener to unlock hydrocarbon in this interval.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129268637","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Integrating Sedimentology and Petrography With Rock Typing and Flow Units: Implications for Low Contrast and Low Resistivity Reservoir Characterization","authors":"A. Surbakti","doi":"10.29118/ipa22-sg-211","DOIUrl":"https://doi.org/10.29118/ipa22-sg-211","url":null,"abstract":"The South Sumatra Basin is renowned as a prolific hydrocarbon area since the early era of oil. Resource discovery has declined since the early 21st century. The Talang Akar Formation (TAF) has been massively explored to seek new potential resources. There is an opportunity to look into more detail on the low contrast low resistivity (LCLR) part, which is included as the upper part of TAF. This study will provide an analogue model of the flow unit from outcropped TAF rocks in Air Batu regency. Field observations include outcrop modeling to capture sedimentation patterns, sampling on selected layers for petrographic purposes, facies characterization, geometry measurements from channel deposits, and flow unit modeling. We observed five facies’ associations, which are: transverse bar (Sp); overbank deposit (Fm); dunes (St); planar bed flow (Sh); ripples (Sr); and debris flow deposit (Gms). Petrographic analysis revealed that the samples have a laminar and dispersed shale distribution. The LCLR reservoir detects and controls porosity and pore size ranging from poor to excellent, as well as grain contact. The difference in the facies is any kind of porosity. The facies of transverse bar, dunes, and ripples show very good to excellent porosity with low shale content and are characterized as high-flow units. Yet, the other facies show medium percentage porosity but the interconnection between pores is poor to good, and these have medium to low-flow units.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"480 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123059059","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Santan Delta Evolution and Its Implication to The Petroleum System in North of Kutei Basin","authors":"H. Lie","doi":"10.29118/ipa22-g-250","DOIUrl":"https://doi.org/10.29118/ipa22-g-250","url":null,"abstract":"The presence of delta between Mahakam Delta and Sangatta Delta has been discussed before by several authors in Kutei Basin. However, there is no detailed information of its location and stratigraphic successions. Our recent sequence stratigraphic studies, utilizing multi vintage seismic and well-based data in East Kalimantan & Attaka Working Area, provide new insights into the evolution of Santan Delta and its implication to the petroleum system in our working area. The Santan Delta might have been overlooked as a potential sediment source for reservoirs in the north of Mahakam Delta. Since the 1970’s, more than 50 MMBOE of hydrocarbons have been produced in this area from Late Miocene – Pliocene deltaic reservoirs. Santan Delta development started in early of Late Miocene which was indicated by fluvio-deltaic sedimentation prograde to the east. Kuching High to the west of the delta started to undergo uplift. Santan Delta development achieved peak sedimentation at the end of Late Miocene – Early Pliocene which was indicated by the presence of significant deltaic facies. It also pushed the carbonate sedimentation to the shelf margin area. Later in Late Pliocene, the presence of Santan Delta started to diminish which is shown by presence of shelfal carbonates that retrograde or backstep to younger shelf margin in this area. The stratigraphic succession of the Santan Delta deposited in Late Miocene – Pliocene became important to better understand source rock, reservoir, and seal distribution in its surrounding deltaic, shelf, slope, and deep-water environments.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126579911","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"2D Basin Modeling of The Carnian and Ladinian Source Rock of West Timor Basin","authors":"T. Setyowati","doi":"10.29118/ipa22-g-220","DOIUrl":"https://doi.org/10.29118/ipa22-g-220","url":null,"abstract":"Basin modeling is used to gain a better understanding of the interaction between the elements and processes of the petroleum system in the study area. The modeling used in this research is two-dimensional (2D). The modeling is using the Temis2D software ver. 4.0.2, and validate modeling outputs with data from laboratory measurements such as Vitrinite Reflectance (Ro) and Temperature (BHT). This study was located in the offshore between the Timor Island and Australian boundary, which passes through the Ashmore Platform and Bena Basin. The source rock in the model is interpreted as being deposited from the Middle Triassic to the Early Jurassic or from the Ladinian to before the Aalenian age. Deposition of organic material is modelled in the basin-deep or deep areas at each age of deposition. Burial history models in the study area illustrate simply the history of rock sedimentation influenced by tectonic events that occurred during the initial sedimentation of the oldest sedimentary rocks (Top Tatarian at 259 Ma) to the present (0 Ma). In this area, the Ladinian shale maturity level is at peak to late mature (0.8–1.1% Ro). In the NW area, which is close to the trough, Ladinian shale has a post mature maturity level (0.9-1.5% Ro). Carnian shale in the SE-NW region has early to peak mature maturity (0.6-0.8% Ro). Aalenian shale is at an immature to early mature level (0.5-0.7% Ro) in this composite line. Current Transformation Ratio models show that kerogens in the Ladinian shale source rock in composite line (SE-NW) have been 50% to 100% transformed into hydrocarbons at the trough area. The kerogen transformation ratio in Carnian shale rock at the trough area has changed from around 20% to 70% to become hydrocarbons, while Jurassic shale in the trough (NW) area has changed by around <10%, while it has not changed in other areas.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention &amp; Exhibition, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116092015","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application of Borehole Image-Based Porosity Analysis in Carbonate Reservoirs to Assist in Permeability Calculation and Its Integration With Resistivity Inversion to Distinguish Productive Vuggy Zones and Tight Zones","authors":"E. Priyanka","doi":"10.29118/ipa22-g-227","DOIUrl":"https://doi.org/10.29118/ipa22-g-227","url":null,"abstract":"The “C” carbonate in Bukit Tua Main, KP Field, Northeast Java Basin is characterized by highly heterogeneous porosity distribution. By performing carbonate heterogeneity analysis using the input of borehole image log in well X-2, different porosity types were distinguishable, from matrix-porosity-supported zones to secondary-porosity-supported zones. The latter can further be distinguished according to the secondary porosity types. In this well, the predominant secondary porosity types are connected vugs, with subordinate solution-enhanced bed boundary and isolated vugs. Solution-enhanced bed boundary and connected vugs are typically the porosity types that are expected to contribute better to permeability. When compared with effective porosity calculated from conventional openhole logs (density-neutron), zones with an abundance of solution-enhanced bed boundary and/or connected vugs showed relatively higher effective porosity values (i.e., up to and exceeding 20%). Therefore, the study interval can be divided into vug-dominated zones and matrix-porosity-dominated zones to ensure that appropriate permeability equation is applied accordingly, depending on the textural (pore) characteristics. Permeability measurement during pressure buildup analysis from well testing was performed. Separately, permeability calculation throughout the interval was also performed using empirical equations for vug-dominated or karstified limestone that was derived from core porosity and core permeability relationship in Bukit Tua. By excluding the zones that are not supported by either solution-enhanced bed-boundary or connected vugs and, at the same time, have relatively lower porosity (i.e., below the average porosity of connected-vug- and solution-enhanced bed-boundary-dominated zones that possess relatively high porosity), a similar mean permeability value was obtained between the two methods. This confirms that because a borehole image-based heterogeneity analysis result could distinguish vug-dominated zones from matrix-porosity-dominated zones, appropriate permeability equations can be applied to those intervals with different textural characteristics, which results in a reliable permeability log as evidenced from the similarity of mean value with the direct permeability measurement. Both porosity heterogeneity analysis and calculated permeability logs indicate that the “C” carbonate has several zones of interest mainly supported by connected vugs and solution-enhanced bed boundary with permeability values ranging from 50 to 200 mD. In addition, when borehole image log is combined with another log such as the resistivity inversion, the two are useful to indicate which vuggy zones may have vugs connected further into the formation vs. those that are tight despite the presence of vugs. Zones with resistivity inversion showing green to cyan veins spectrum; i.e., moderately high conductivity, are typically consistent with zones that have an abundance of solution-enha","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention &amp; Exhibition, 2022","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116114385","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Onshore Kutai Basin Pore Pressure Synthesis and Hydrocarbon Accumulation","authors":"I.Y. Tribuana","doi":"10.29118/ipa22-g-20","DOIUrl":"https://doi.org/10.29118/ipa22-g-20","url":null,"abstract":"Hydrocarbon accumulation in the Kutai Basin's deltaic system appears to be related to pore pressure profiles, with the largest accumulations occurring mostly between 60 - 140degC bottom hole temperature. This interval is the \"Accumulation Zone,\" which extends from the hydrostatic pressure regime to the top of hard overpressure zone. The zone occurs due to the chemical cementation, which lithifies the rock grains and creates an inner sealing system that traps hydrocarbon effectively at the said temperature range. Below the Accumulation zone, the \"Expulsion Zone” exists starting from the temperature of 140degC, which corresponds to Ro = 0.6 (Hydrocarbon Maturity), situated on hard overpressure and has very low mobility (< 1 mD/cP). A \"Loss/depleted Zone\" could occur well below the Expulsion Zone, with excessively hard overpressure and close to fracturing pressure. These conditions will make forming a slip fault/fracture easier, leading to drainage to reach a pressure-stress balance. Finding an ideal complete zone of such systems in the present state of the onshore part of the Kutai Basin is difficult due to existing erosional events after uplifting, except for Nilam Field. However, by reconstructing the erosional event, it is possible to comprehend the zone system and explain the relationship between pore pressure, temperature, and mobility to today's hydrocarbon accumulation, where higher erosion intensity tends to result in lower hydrocarbon accumulation.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention &amp; Exhibition, 2022","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124894646","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Integrated Multidisciplinary Approach in Water Flooding Project Design for Future EOR Plan in Mature Oil Field Development","authors":"E. Suwito","doi":"10.29118/ipa22-e-32","DOIUrl":"https://doi.org/10.29118/ipa22-e-32","url":null,"abstract":"As an oil field gradually enters the maturation phase, which is indicated by the increasing high water–cut, it will face unprecedented challenges in further improving its oil recovery. Various techniques for tapping the potential hydrocarbons can be implemented, including water flooding as a stepping-stone prior to entering the Enhanced Oil Recovery phase. The successful implementation of water flood depends on the strong foundation of the project design. Any business decision that generates profits and meets the economic standards of the company should be defined precisely during the project design. The workflow consisted of coordinating each diverse element of design in the project. These activities required an iteration process by combining data and coordinating all key personnel from different expertise who worked as one team to plan and design the project: subsurface engineering, production and operation engineering, project and construction engineering, and also drilling and well intervention engineering. During the process study, all team members gathered and brainstormed their ideas based on their disciplinary background. This collaboration played an important role in gaining a holistic approach, by linking valuable information and available technology in technical design, project economic analysis, and also project risk mitigation identification. Ultimately this integrated multidisciplinary approach was useful to address technical and business issues related to water flood project design, in order to achieve the most optimal scenario of water flood project: the most efficient injection (at the right location of a healthy sweet spot reservoir) with the lowest project costs by maximizing the use of existing facilities. This water flood concept design has contributed to engineering decisions towards the EOR phase, as well as maximizing the project value.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention &amp; Exhibition, 2022","volume":"208 1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114254165","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Prediction Project Task Completion Using Supervised Machine Learning Method: A Conceptual Approach","authors":"M.R.A Yudhi","doi":"10.29118/ipa22-f-104","DOIUrl":"https://doi.org/10.29118/ipa22-f-104","url":null,"abstract":"Project schedule forecasting is a core enabler of successful project management. Accurate schedule prediction leads to better resource management and ultimately, more value gained from the investment made for the project. The higher the complexity of the project, the higher the importance of having an accurate schedule prediction to minimize the risks associated with the project. The Field X Expansion Project of Company Y provided an excellent case study of the successful pilot implementation of supervised machine learning to predict the completion of the project tasks, which gave more precise results compared to the existing conservative approach. The Field X Expansion Project was designed to increase the total daily production from the gigantic Field X reservoir. The project’s cost was in the multi-billion dollars range, making it one of the highest investments of the decade in the oil and gas industry. Therefore, it is crucial to complete the project on schedule and within the budget to maintain its economic value. However, there were multiple challenges in the project that brought uncertainties and complexities to the schedule prediction, which cannot be solved using the conservative approach, such as the challenges in the project terrain and geography, the weather, and the mobilization of project logistics from around the globe. The conservative approach utilizing the off-the-shelf project management software has attempted to forecast past projects schedule more accurately. With this software, each project task and its estimated duration serve as inputs for the software to calculate the estimated project completion. To the team’s disappointment, the result showed overall schedule accuracy of only 40%. Moreover, using this method, the software can only calculate the estimated completion of the whole project, not the completion of the individual tasks. Although useful, it can still be improved. The software has been able to accumulate historical data from many previous projects utilizing this approach to be used as a data source for further improvement. With the advancement of data science technology and the immense amount of accumulated data from previous projects, there is an opportunity to leverage more advanced analytics methods such as big data analytics and machine learning to predict task completion with higher accuracy. This paper discusses the big data analytics approach to predicting individual project task completion. The method involved pulling the task data from the project management software database and analyzing the impact of various variables and features of the project on the completion of the individual project tasks that ultimately affected the project schedule. The features with the most significant impact were then used as predictors to forecast the completion of each project task. Applying this method to the Field X Expansion Project, the task completion can be predicted with 98.6% accuracy and 90% Receiver Operating Ch","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention &amp; Exhibition, 2022","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121772294","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}