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

{"title":"Rig Hours Optimization Using Plug Modification on Fracturing Job in Sangasanga Field","authors":"Taufik Hidayat","doi":"10.29118/ipa22-e-225","DOIUrl":"https://doi.org/10.29118/ipa22-e-225","url":null,"abstract":"Sangasanga Field is one of 22 fields in PT. Pertamina EP with oil production target of 5670 BOPD in 2019. The Field well work plan includes 32 wells workover and 77 well intervention which are expected to support the achievement of production targets in 2019. One of the jobs to support well intervention is to test tubing before cementing and fracturing process. In the tubing test process, there are activities that contribute to high loss time, namely circuit unplugging. Objective of this paper is to find an alternative solution to minimize the activity of running in and pulling out the circuit to open the plug by modifying the plug using a TH pump shoe (tubing pump) and a TH pump mandrel (tubing pump) and a series of fishing tools: on and off (fishing neck), pony rod 7/8” with guide sucker rod so that the circuit is in the middle of the fishing jar to help release both the plug and sinker bar. The working method is the shoe and pump mandrel that have been plugged in run together with run tubing, a pressure test is carried out per 20 joints to the depth according to the program, after the final pressure test is carried out, then the fishing tool circuit to the sandline is connected, then run sandline until plug peak. On-off combined with a pony rod and rod guide will ensure the fishing tool is in the middle of the inner diameter of tubing, then it will latch into the plug and conduct tension sandline so that the jar will work and the plug modification tool will release from shoe. Modification of these tools reduces the pull-in work and is tested on 4 wells, the result is that it can reduce the tubing pull-in time for 12 hours also generate efficiency in rig rental costs and diesel costs of $1,550/well. With this innovation, it can accelerate the operation of the rig work so that it can potentially increase the well production in the Sangasanga Field.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"35 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":"134112169","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":"Abating Carbon Emissions in Jack Up Rig Operations: A Case Study in Offshore East Java, Indonesia","authors":"J. M. Lumbantobing","doi":"10.29118/ipa22-e-70","DOIUrl":"https://doi.org/10.29118/ipa22-e-70","url":null,"abstract":"The oil and gas drilling industry contributes to the release of greenhouse gases (GHG), especially carbon emissions from the combustion of fuel, and waste from its activities. It is rare to measure the quantity of these emissions. Going forward, it may become a legislative requirement to do so. This paper provides several approaches to measure and reduce carbon emissions from drilling activities to support the Glasgow Climate Pact at COP26 in November 2021 to keep alive the hope of limiting the rise in global temperature to 1.5˚C. Carbon emissions are analyzed based on the API Compendium of Greenhouse Gas Emission Methodologies for The Oil and Natural Gas Industry, 2009. The authors provide practical equations to implement in offshore drilling activities and establish workflows to estimate carbon emission of CO2, N2O and CH4 from stationary combustion of rig engines and from marine vessels. Supported by SANGEA Software (SANGEA™ is a GHG emissions calculation tool owned by the American Petroleum Institute), total carbon emissions for Field X from jack up rig operations from September 2021 until March 2022 was calculated at 2,328 tons CO2e/ month, and total emissions from production and drilling operations was calculated at 8,791 tons CO2e/ month. Appreciating the significant ± 26% carbon emissions contribution from drilling activities will drive improved well engineering, operations optimization, fuel efficiency and low carbon footprint utilization through digitalization/automation. Unrecorded emissions from vented sources (well testing, completion and unloading) and indirect emissions controlled by other parties such as land transportation, helicopters and electricity imports in workshops will be part of the discussion. Additionally, this paper proposes administrative workflows to support the initiative through frequent fuel consumption records and through development of a roadmap to reduce carbon emissions from continuous drilling campaigns. The novelty of this paper is focusing on offshore drilling activities to abate carbon emissions in jack up rig operations. Knowing the portion and magnitude of carbon emissions from drilling activities will drive efforts to reduce carbon emissions and to support Net Zero Carbon Emission aspirations in the oil and gas industry.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"49 4","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132089865","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":"Impact of High-Performance Water Based Mud (HPWBM) Usage to Geological Data Acquisition: Case Study Suban Field South Sumatra","authors":"Budi R. Permana","doi":"10.29118/ipa22-g-35","DOIUrl":"https://doi.org/10.29118/ipa22-g-35","url":null,"abstract":"Thick shaley overburden sections such as the Telisa Formation are one of the main challenges for drilling wells in the Suban Field. Prior 2012, water-based mud (WBM) was used to drill this formation, with KCl additive, resulting in low rate of penetration (ROP) and shale stability issues which requiring several bits run to successfully drill the section. Subsequently, starting 2015 synthetic oil-based mud (SOBM) was used in drilling campaign to improve drilling performance. However, the costs of SOBM are high and cuttings handling is more environmentally risky. For continuous improvement, a high-performance water-based mud (HPWBM) was designed to have a better drilling performance at lower cost and is more environmentally friendly. Several HPWBM laboratory tests were conducted by utilizing shale cuttings from several Suban wells. In general, the clays mineralogy in Suban overburden sections are predominated by kaolinite and illite. Consequently, the HPWBM formula need to be designed to handle the behavior of the clay minerals that tend to be dispersed. Based on lab results, NaCl, KCL and Polyamine need to be added to the HPWBM system. With HPWBM, the drilling ROP was predicted to have better performance than WBM but less than SOBM. This ROP prediction was used to design real-time logging data transmission while drilling (LWD). During drilling execution, the actual ROP exceeded the prediction. However, this high ROP resulted in intermittent real-time data transmission. Therefore, real-time LWD data selection needs to be carefully adjusted for the next sections. The use of HPWBM is also impacting the quality of gas readings that experienced distortion due to absorption. The absorption is caused by chemical components in HPWBM increases as the carbon component in hydrocarbon gas increases. However, the magnitude of absorption is lower than absorption in SOBM. Thus, interpreting gas logs should be done with caution.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"3 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":"132138540","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":"Revealing New Hydrocarbon Potential in Mature Basin, A Case Study From North Madura Platform, East Java Basin, Indonesia","authors":"A. Wijaya","doi":"10.29118/ipa22-g-236","DOIUrl":"https://doi.org/10.29118/ipa22-g-236","url":null,"abstract":"Several basins in Indonesia have been explored and produced for more than 10 decades. With the country’s aspiration of 1 million BOPD oil and 12 billion SCFPD gas production by 2030, efforts in enhancing recovery from existing reservoirs/fields and further exploration in mature and frontier areas have become critical. The East Java Basin has a long exploration history with a total of approximately 700 exploration wells drilled, resulting in more than 4 billion BOE of hydrocarbon resources from 143 fields, thus this area is considered a mature basin. To further explore a mature basin, it is crucial to get additional new data, improve on the available data, and promote new ideas. A case study from the North Madura Platform, East Java Basin which has a series of seismic reprocessing conducted through the years, has been developed to support exploration and exploitation activities. The latest seismic FWI PSDM reprocessing completed in 2020 has enhanced seismic resolution and shown better visualization of carbonate body identification in deeper interval, hence this helps in resolving structural uncertainty. Further innovative G&G studies and improved exploration techniques have opened new hydrocarbon potential within this area. A collaborative and holistic approach has been applied as guidance in decision-making to streamline the strategy process. In early 2021, a wildcat exploration well was drilled and succeeded in marking an important milestone with the discovery of a new pool in a very thick oil-bearing carbonate build-up with very good reservoir quality from deeper Late Eocene Ngimbang Carbonate Play. The discovery has successfully unlocked the vast potential available in this mature basin. The recent oil discovery in the North Madura Platform, East Java Basin, is a success story that should spark an increase in exploration campaigns in this basin as well as in other mature basins in Indonesia.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"24 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":"122825131","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":"Wettability Alteration on Sandstone Reservoirs Containing Clay Minerals By The Addition Anionic Alkyl Ethoxy Carboxylate Surfactant","authors":"","doi":"10.29118/ipa22-e-298","DOIUrl":"https://doi.org/10.29118/ipa22-e-298","url":null,"abstract":"With the increasing number of maturing fields, surfactant injection as an alternative EOR technique is essential to mobilize the remaining oil. The presence of clay in the sandstone causes the polar components in the oil to be adsorbed on the rock surface, causing a tendency towards wettability towards oil-wet. Therefore, the oil potential remaining in the reservoir, which is the target of surfactant injection, is more significant in oil reservoirs with oil-wet characteristics. For this reason, surfactants are needed that can alter the surface properties of oil-wet to water-wet and the ability of these surfactants to reduce IFT. The wettability alteration mechanism is one thing that needs to be understood more deeply, considering the critical function of surfactant injection in the EOR method. Studies on the effect of adding surfactants on sandstones containing clay minerals of certain types and concentrations need to be developed to assist the application of the oil recovery process at an advanced stage. Laboratory experiments are carried out by measuring the contact angle of sandstone samples conditioned according to reservoir characteristics with several concentrations of clay interacting with fluid. The measurement results show that the initial condition of the sandstone containing montmorillonite clay is water-wet, while the sandstone containing kaolinite clay is oil-wet. The presence of surfactant solutions gives a wettability alteration effect on sandstones containing montmorillonite clay to become more water-wet and sandstones containing kaolinite to be water-wet. Surfactant solution with a concentration of 1wt% gives a more significant wettability alteration effect than surfactants with the attention of 2wt%. The interaction of sandstones containing clay minerals with surfactant solution shows that the addition of surfactants can reduce the interfacial tension between oil and water. In contrast, surfactants with a concentration of 2wt% can reduce IFT greater than surfactants with the attention of 1wt%.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"4 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":"124021492","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":"Test Analysis of a 2D Seismic Survey With Finer CMP Interval","authors":"Z. Xuewu","doi":"10.29118/ipa22-g-119","DOIUrl":"https://doi.org/10.29118/ipa22-g-119","url":null,"abstract":"Finer bin size or CMP interval normally means higher cost for a seismic survey, which makes sense for 3D projects because of very large equipment investment and difficulties of recording crew organization. However, the increase of active channels seems not to increase much cost for a conventional 2D seismic project in Indonesian jungle where the large portion of the cost is from line clearance, bridging, drilling and damage compensation. A test 2D line with 10 m receiver interval (RI), 60 m source interval (SI), 720 active channels and bunched geophone was acquired versus the production parameters of RI 30 m, SI 60 m, active channels 240 and arrayed geophone. The results demonstrate that flexible indoor arrays produce better effects than infield arrays where surface inconsistences exits. Data sets with RI of 20 m and 30 m with nominal full fold of 60 extracted respectively by picking one trace every two and one every three were processed. The comparisons of brute stacks with CMP interval 5 m, 10 m and 15 m demonstrate finer CMP interval can mitigate spatial aliasing and hence, improve denoising and S/N ratio. Instead of geophone array, the test data were also processed with nominal full folds of 120 and 180 by enlarging CMP intervals to be 10 m and 15 m. The comparisons indicate higher fold coverage can significantly improve seismic imaging with no negative impacts from geophone array. A trial with RI 10 m, CMP interval 15 m and SI 120 m was processed with nominal full fold 90. The purpose of such test is to seek a possible alternative of 2D geometry with dense receiver but sparse source for areas where the number of source holes is desired to be less. This paper intends to discuss ways for 2D seismic surveys cost-efficient and environmentally-friendly.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & 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":"128706705","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":"Asset Tagging and Line Number Automation: A Cloud-Based Application System Used for Identification and Registering of Tag and Line Numbers of Equipment, Components, Device, and Valves","authors":"H. Qonitah","doi":"10.29118/ipa22-f-13","DOIUrl":"https://doi.org/10.29118/ipa22-f-13","url":null,"abstract":"All equipment in a facility, plant or pipeline system shall be identified with unique labels and tag numbers in a consistent manner. EMCL has used a Computerized Maintenance Management System (CMMS) to locate information, track repair histories, develop historical cost indices, and other predefined requirements. This software is intended for managing maintainable items starting from planning, purchasing, and maintaining until reporting. However, for non-maintainable & new items, it is difficult to track using CMMS. This paper will explain how EMCL builds a cloud-based application to register tag and line numbers of equipment, components, devices, and valves in order to comply with the company's guidelines requirements and simplify the process by implementing the guidelines’ algorithm so that no manual validation is required. The metadata of the application is enriched which enables the tag number and line number connected to each other so that users can easily find what pipes or devices are connected before and after the specific equipment. In addition, each tag or line number has detailed information including a hyperlink to the referenced documents i.e. P&ID and Data Sheets as well as the status of the Critical and Equipment Strategy. Besides the technical aspects, this paper will also highlight the importance of having an automation system for identification and registering of tag and line numbers for equipment, component, device, and valves for maintainable or non-maintainable items. Finally, the paper will conclude with the benefits of the system due to the cost efficiency, productivity, and collaboration enhancement among the cross-functional team.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"22 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":"117186015","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":"Online Leak Sealing Using Modified Composite Repair to Stop Minor Leaking on Piping","authors":"I. P. Ariseputra","doi":"10.29118/ipa22-f-257","DOIUrl":"https://doi.org/10.29118/ipa22-f-257","url":null,"abstract":"In general, the composite repair only effective as leak sealing if the system shut down (offline condition). Composite repair for leak event required sufficient curing time without any pressure presence to get best performance, If the curing time is not reached, the optimum bonding of the composite material with the pipe surface will not achieved so it will tend to leak again. Meanwhile, for critical lines may trigger total shutdown for entire field. Asset integrity engineering team seek the solution to close the leak as quickly as possible, safe, relatively cheap and without any shut down platform. Composite repair was chosen with some modification by fabrication venting pad as patched material on pipe leak surface. This venting nipple pad will localize the leak and relocate the hydrocarbon release to a safe area using temporary hose waiting composite curing time achieved. This repair was executing with very minor preparation and without any welding or hot work activities. Repair was done without any safety issue, no shutdown and all activities categorizes as cold work.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"27 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":"114280013","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":"Damage Mechanism Analysis and Risk Assessment of Pressure Vessel Absorber, LP Flash Column, Rich Solution Heater at CO2 Removal Plant Unit","authors":"L. P. Leuvinadrie","doi":"10.29118/ipa22-o-25","DOIUrl":"https://doi.org/10.29118/ipa22-o-25","url":null,"abstract":"Field-X is one of the largest gas contributors, where gas customers are companies that contribute to the sustainability of the economy. X-field natural gas has a high CO2 content of 23%, the CO2 removal operation is intended to reduce the CO2 content so that it has a high heating value. This is because CO2 with levels> 5% can affect the heating value gas, toxicity and is very corrosive, especially for customers to further process the product. In the gas purification process in field X, the Absorber pressure vessel, LP Flash Column and Rich Solution heater have a major role in the CO2 absorption process. The analysis results show that the actual damage mechanism of the pressure vessel with the standard amine treating on API RP 571 has a difference, especially the damage mechanism of amine corrosion in the three pressure vessels and chloride stress corrosion cracking on the LP Flash Column. The highest corrosion rate value is 0.604 mm / year in 2020 due to an increase in the amount of HCO3- in the form of acid condensation (HSAS) which can react with Fe due to changes in process temperature through the corrosion rate model Y = -0.0556x + 4,6359 (head) and Y = -0.0161x + 1.3682 (shell) in the pressure vessel. From the criticality matrix, there are 2 pressure vessels at the risk rating for medium and 1 pressure vessel for high medium, so that the inspection / maintenance response that needs to be done is corrective maintenance at intervals every 6 years and the scope of the inspection is in the medium category. Polynomial model Y = 0.0007X2 - 0.0099X + 3,7452 (head) and Y = 0.0005X2 - 0.0842X + 3,3876 (shell) as a prediction model for amine corrosion rate at temperatures ranging from 40 to 1300C shows the difference in the graph between the actual and the API RP 581 standard is because the prediction standard of corrosion rate is used for amine treating in H2S and CO2 systems while the actual polynomial graph is used for prediction of corrosion rate for amine treating in CO2 system without H2S.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"52 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":"116215662","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":"Solvent Stimulation as a Solution for Heavy Oil Production in B Structure Pertamina","authors":"R. Alfajri","doi":"10.29118/ipa22-e-188","DOIUrl":"https://doi.org/10.29118/ipa22-e-188","url":null,"abstract":"The production of heavy oil requires more effort than normal. The low API degree, high viscosity and high pour point make it quite challenging to produce wells with this type of oil. B Structure in PERTAMINA is facing this problem. The oil has 15-200deg API, 10-300 cp viscosity and 115degF pour point. Producing wells in this structure results in either low production rate or water coning. Altering the oil characteristic by pumping a suitable chemical might be a solution to this problem. Laboratory tests were performed to find the right chemical that can alter the oil characteristics in this structure. The thinking was to utilize a hydrocarbon-based chemical, thus a mixture of xylene and diesel as the main ingredient was chosen. Solubility tests with oil from B Structure showed that the mixture could dissolve the asphaltene and paraffin content. A dose of surfactant, mutual solvent, and potassium chloride was added into the mixture to condition the formation. Compatibility tests with brine from B Structure were conducted with neither emulsion nor sediment forming. The laboratory tests of the mixture showed promising results. Stimulation jobs using the solvent mixture were performed on three wells in B Structure: well B-26, B-122, and B-121. The problem in wells B-26 and B-122 was the same, which was a sudden increase in water cut after performing well service. Well B-121 lost production after water shut off activity. Stimulation was performed using the bullhead method with 6 feet of penetration into the formation and a minimum of 60 minutes soaking time. The best result out of these three treatments was from well B-121: the oil production before treatment was 25 bbls per day and it improved post-treatment to 175 bbls/day, with a decreasing trend in water cut. An improvement also happened in well B-122: oil production pretreatment was 21 bbls/day and it improved to 76 bbls/day. As for B-26 well, improvement was less than the others, producing 18 bbls/day oil from 10 bbls/day pretreatment. All wells were produced with artificial lift and still had more than 300 meters of pump submergence, which opened the door for further production optimization. The success from these stimulation jobs provided a solution for heavy oil production in B Structure in PERTAMINA. Stimulation was further conducted in the next 7 wells and a total 8 out of 10 wells have delivered satisfactory results including 2 newly drilled wells. With this new-found success in aromatic solvent stimulation, this solution to the problem has now been selected as the standard treatment in producing heavy oil in B Structure PERTAMINA.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"16 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":"114775243","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}