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

{"title":"Lessons Learned From Carbon Capture and Storage Projects in South East Asian Depleted Reservoirs","authors":"Dou Yon","doi":"10.29118/ipa22-e-12","DOIUrl":"https://doi.org/10.29118/ipa22-e-12","url":null,"abstract":"The aging of oil and gas reservoirs in South East Asia (SEA) presents opportunities for their repurposing for use in Carbon Capture and Storage (CCS); to our knowledge, there are currently no operational CCS projects in SEA. Multiple CCS projects have been announced recently in SEA, targeting storage in depleted reservoirs. In this paper, we share technical lessons learned while working on CCS projects in SEA. The paper first provides an overview of engineering factors that should be considered for the transport and storage of CO2 in depleted reservoirs. We will then focus our discussion on four of the challenges faced while assessing these factors. Firstly, we highlight the impact that regional geothermal gradients have on storage capacity; particularly, we show that higher geothermal gradients due to the proximity to the ring of fire reduces storage capacity in reservoirs in SEA. Secondly, challenges surrounding the dynamic modelling of Carbon Dioxide (CO2) injection into depleted reservoirs will be discussed; the large difference between the composition of the injected gas and native reservoir gas necessitates the use of compositional dynamic models. In this regard, many depleted reservoirs either do not have dynamic models at all, or only have black oil models; both circumstances will require significant time and resource investments to construct compositional dynamic models. Next, we will discuss the reusability of regional gas pipelines for CCS projects; we discuss factors that may prevent a pipeline from being convertible for CO2 transport. Finally, we will discuss the challenge of managing CO2 phase transitions at injection sites. The phase transitions are a result of CO2 being transported at high pressures and then injected into depleted reservoirs with low pressures and high temperatures. We argue in the paper that the phase transition should be engineered to occur in the reservoir to minimize facilities costs.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"33 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":"128022643","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":"Integrated Formation Evaluation Workflow for Estimating Source Rock Hydrocarbon Potential","authors":"","doi":"10.29118/ipa22-g-80","DOIUrl":"https://doi.org/10.29118/ipa22-g-80","url":null,"abstract":"A complex reservoir usually requires tools and workflow which are beyond conventional formation evaluation techniques. In the case of source rock plays, the complex petrophysics are solved with the addition of advanced logging tools such as NMR for porosity and permeability determination, dielectric for fluid saturation, elemental spectroscopy for identification and quantification of minerals, and core data, ideally pressure core for petrophysical calibration. Formation evaluation for source rocks must be integrated with geochemical analysis to evaluate TOC and/or kerogen, geomechanics analysis to evaluate rock fracability and quantification of faults and natural fractures if present. TOC analysis can be done with standard logging tools with the DeltalogR or Schmoker methods, and the geomechanical analysis can be done with dipole or multipole sonic tools through anisotropy evaluation and elastic properties computations to help quantify areas where fracture conductivity is easier to achieve. Geochemistry and geomechanics log results require high quality core data to calibrate TOC and organic material maturity using pyrolysis or LECO combustion technique and to calibrate elastic properties using triaxial pressure test., Leak Off Test (LOT/XLOT), or microfrac/DFIT. This paper presents a proven workflow and lessons learnt from recent source rock reservoir evaluations using advanced logging tools. The goal of this presentation is to improve understanding on how source rock reservoirs must be evaluated to be completed and commercially produced, such as in emerging Indonesian Source Rock plays.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"115 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":"124166692","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":"Experimental and Numerical Study of Basic Discharge Coefficient (Cd) For Orifice Plate Meters Under Single Phase Fluid Flow","authors":"M. R. Ridlah","doi":"10.29118/ipa22-f-4","DOIUrl":"https://doi.org/10.29118/ipa22-f-4","url":null,"abstract":"Orifice meter’s accuracy is of great importance in fluid flow metering due to the monetary value of fluid transferred daily. The discharge coefficient of the orifice meter calculate for the irreversible losses in the system, which requires extensive experimental validation in accordance with the API standard. This paper presents the numerical simulation study as an alternative of experimental works for estimating the orifice plate’s discharge coefficient. In this study, numerical simulations performed under several orifice diameters with single-phase gas flow with multiple gas flow rates. Two different Reynolds Averaged Navier-Stokes turbulent models, i.e., SST k-ω and Realizable k-ℇ model, are employed to solve the upstream and downstream orifice differential pressure, based on which the corresponding discharge coefficient is generated. Experimental data points are employed to validate the numerical study, and its comparison studied statistically. Simulations of two orifices display in this study, i.e., 1-inch orifice with SST k-ω and 1.5-inch orifice with Realizable k-e turbulence model. It observed that the pressure increases slightly as the fluid approaches the orifice, and the pressure drops suddenly and continues to drop until it reaches the vena contracta. Moreover, due to the increased velocity of the gas passing through the reduced area of the orifice, the pressure gradually increases afterward. Compared with the experimental data, the numerical simulation under-predicts the discharge coefficient. However, the data discrepancy is less than 4% and 6% respectively. The pressure at 12-inch downstream of the orifice is obtained to investigate the pressure loss ratio. The pressure loss ratio is slightly over-predicted by the numerical simulation of 2% and 6% relative error respectively. Furthermore, user-defined functions that consider the effect of the turbulence model can be developed based on the contribution of this study to expand the numerical","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"49 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":"125101955","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":"Well Management Strategy Through Integrated Production Modeling: Study Case Well B-5","authors":"B. Khoironi","doi":"10.29118/ipa22-e-213","DOIUrl":"https://doi.org/10.29118/ipa22-e-213","url":null,"abstract":"In conventional wisdom, operators of oil or gas fields with sandstone reservoirs often produce their wells under pressure drawdown limit to avoid sand control failure. Tiffin et al. (2003) reported that the recommended pressure drawdown is ranging from 500 psi to 1000 psi depends on the experience and analogue data for wells with installed sand control. However in their research, they shown that pressure drawdown is not an appropriate approach to avoid sand production. They introduce the concept of flux limit to replace pressure drawdown limit since velocity of produce fluid through sand screen is the main variable affecting sand control failure. Similar flux limit application also studied by Procyk et al. in 2015. As an object of this study, B-5 is the third development well in B field. The field consists of shallow multi-stacked sandstone reservoirs. As an implication of its shallow depth and good reservoir quality, Sand production is expected on the B field as observed in surrounding analogue fields. To mitigate sand production, sand control of fracpack and gravel pack was installed under five inflow control valves (ICVs) in B-5 well. In total 11 reservoir were commingle in those five ICVs where Each ICVs is equipped with pressure and temperature gauge in both inside tubing and annulus. On this research, dynamic simulation model in B-5 is coupled with well and surface facility model. Well management strategy through integrated production modeling approach is carried out to take into account backpressure from each production interval. Flux limit on sand screen can be updated continuously by considering the gas flow rate and depletion on reservoir pressure. This integrated study is important to create strategy of ICV open and shut-in condition to safely optimize well production by avoiding sand production while cover widest production range as possible as required by gas demands.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"99 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":"131739219","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":"Pseudo 3D Seismic Generation From Multi-Vintage 2D and 3D Seismic Data for Hydrocarbon Exploration at Eastern Indonesia Basin","authors":"A. Abdullah","doi":"10.29118/ipa22-g-26","DOIUrl":"https://doi.org/10.29118/ipa22-g-26","url":null,"abstract":"Pseudo 3D seismic generation using existing 2D seismic lines and 3D seismic data has been conducted. We implemented several processes such as amplitude balancing, data selection, trimming, sampling rate equalization, and quality check for seismic tie among 2D lines that might be found due to acquisition geometry, processing, vintages, and difference of seismic instruments. Sample of amplitudes from the entire 2D seismic data were employed as ‘seeds points’ to be populated on the defined seismic 3D layout by applying robust geo-statistical method. Pseudo 3D seismic generation utilized Nearest Neighbor Algorithm combined with the Kirchhoff Demigration and Remigration guided by seismic horizons. The result of pseudo 3D seismic was qualitatively and quantitatively QC-ed using several approaches e.g. direct comparison of pseudo 3D seismic- 2D lines composite and section comparison in the adjacent location. Pseudo 3D result depends on the input data such as quality, distribution of input data, and distance between input data. The quality of pseudo 3D result is measured by the uncertainties map, lower uncertainty, higher confidence and vice versa.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"36 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":"130473278","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 Pulsed-Neutron Spectroscopy Logging as Crucial Data Input To Modify Reservoir Characterization Understanding: Case Study in Carbonate Reservoir, Indonesia","authors":"D. Kusuma","doi":"10.29118/ipa22-g-19","DOIUrl":"https://doi.org/10.29118/ipa22-g-19","url":null,"abstract":"Bukit Tua field is located in the north of Madura Island & its main reservoir are Kujung 1 & Kujung-2 which are consist of isolated patch reef with carbonate stringer. Pulsed-Neutron Spectroscopy Logging (PNL) was planned since this field enter next development stage, the formation oil/gas saturation & fluid contacts movement is crucial for development planning and behind casing opportunities. PNL can accomplish the objective since its building on the three types of nuclear reactions between neutrons and formation, four kinds of pulsed neutron logging modes are commonly utilized: sigma mode which based on the thermal neutron capture & primarily measure the time decay of the capturing process; C/O which based on the fast neutron inelastic scattering reactions; Ratio-Based Gas Saturation and 3-Phase Saturations. Sigma processing result can be specifically calculated from Sigma equation, but the C/O and Ratio-Based Gas Saturation and 3-Phase Saturation data processing need to apply the Monte Carlo models to eliminate the impact of the downhole environment to the log data. This paper introduces a novel pulsed-neutron log design that was successfully practiced in Bukit Tua, where it took the advantages from Sigma log modes to efficiently overcome the challenges of defining or to monitor hydrocarbon sweep and Gas-water contact movement. PNL was run in the Kujung-1 interval with activated sigma mode. This interval is known as a thick build-up platform carbonate with 95 feet TVT of gas column. Previous understanding was that the Kujung-1 reservoir was connected and there was no fault or facies compartmentation. There are 16 wells that penetrate this interval, consisting of 6 exploration wells, 6 non-producing wells and 4 producing wells. X1 well has produced since 2017, followed by X6 well in 2018. X11 well was drilled in 2020 and showed the GWC higher by 15 feet from the initial GWC. But surprisingly, two other wells (X8 & W2) drilled in 2020 and 2021 and penetrating the Kujung-1 interval showed original gas water contact but with pressure data below original pressure. To answer this anomaly, the surveillance PCINO team proposed to run PNL in two wells that are located in the X11, X6 & X1 area. X4 and X1 well were selected to represent a producing and non-producing well. PNL was run successfully in X4 and X1 wells, with three pass data that showed good repeatability. X4 is an oil well, and SGS data acquisition was run to confirm fluid annulus that will affect PNL data interpretation. X4 results show that the current GWC has risen by 17 feet, close to data from X11 which showed GWC higher by 15 feet. Meanwhile, X1 as producing well shows that the current GWC has risen by 23 feet, which is higher than the other data and possibly affected by water coning. Based on this PNL reservoir data, the previous understanding that Kujung-1 intervals are defined as connecting reservoir should be revised and thus will have implications for OGIP and reserve calculation.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"170 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":"121080991","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":"Metamorphosis of MPD Method in Managing Combined Risks of Wellbore Stability, Loss Circulation and Narrow Pressure Window in Highly ERD Carbonate Wells in Offshore East Java, Indonesia","authors":"M. Akbar","doi":"10.29118/ipa22-e-85","DOIUrl":"https://doi.org/10.29118/ipa22-e-85","url":null,"abstract":"Drilling into naturally interbedded depleted carbonate formation often causing various operational problem i.e loss circulation, wellbore instability and swab/surge risk during tripping operation. Given that challenging situation, specific Managed Pressure Drilling (MPD) method were successfully adopted to mitigate escalated issues with series of Novel and Methodical approach to ensure well objectives can be delivered successfully in ERD well located in Field X, East Java Offshore, Indonesia. MPD method were historically used in Field X starting from Phase-1 (2014-2015) and Phase-2 (2017-2018). In the last campaign of Phase 3 (2019-2021), the formation pressure has higher depletion due to nearby producing wells which causing higher risk of loss circulation as well as higher necessity of keeping wellbore stability. The careful steps were taken to tailor-made the MPD application specific to each of well condition which comprised of performing detail ECD management planning while minimizing loss circulation in the narrow mud window area & borehole collapse based on geomechanics analysis. These method(s) were successfully executed and were proven to deliver well objectives with contained risk and significant cost savings in Bukit Tua Phase 3 ERD carbonate drilling.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"63 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":"129739953","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":"Interval Prediction Of Crude Oil Price Using V@R-Asymmetric-Garch Model To Optimize The Petroleum Production Sharing Contract In Indonesia Via Gross Split Method","authors":"","doi":"10.29118/ipa22-bc-190","DOIUrl":"https://doi.org/10.29118/ipa22-bc-190","url":null,"abstract":"Forecasting crude oil prices is a critical factor in evaluating the potential risk of an oil and gas project. The price of crude oil tends to have volatile properties, so most investors are not confident in investing in oil and gas projects. A mistake in forecasting crude oil prices significantly impacted accuracy in evaluating a project proposed. One of the most used methods is point-prediction ARMA(p,q) model. However, this method could not capture the volatility of the crude oil price data, and point prediction is riskier to use because it is not robust, i.e., it tends to change due to the existence of extreme values. To solve these problems, instead of using the point prediction ARMA(p,q) model, we proposed an interval prediction called V@R-Assymetric-GARCH(p,q) model to predict the lowest and the most significant change in oil price probable to α-significant. The Asymmetric-GARCH is the modification of the conventional GARCH(p,q) model with the asymmetry distribution, and V@R (Value-at-risk) is the interval-prediction measure that is more robust than the point prediction. At the end of this study, the prediction values are used to calculate the economic quantities under the production sharing contract (PSC) scheme using Gross-Split Methods. The results presented in this paper can help investors or company management make better decisions in evaluating the potential of oil or gas projects.","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":"131153320","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":"The Role of ESG in Attracting Capital to The Petroleum Industry","authors":"S. Whitaker","doi":"10.29118/ipa22-bc-288","DOIUrl":"https://doi.org/10.29118/ipa22-bc-288","url":null,"abstract":"Environmental Social Governance (ESG) is having an increasing impact on investment decisions globally, this includes the oil and gas industry. This paper argues that our industry has a positive narrative for ESG conscious investors and financiers. The reasons for the industry’s positive ESG impact includes the important role of gas and LNG in the energy transition and the likely importance of Carbon Capture and Storage in reducing emissions. The industry also has a good track record in the areas of safety performance and social responsibility. The paper points out that this good performance needs to continue as projects enter the decommissioning phase. Finally we suggest that two existing frameworks - the Equator Principles and Indonesia’s PROPER system - can be used to assist the industry enhance its ESG performance.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"2 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":"133934904","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":"The Success Story of Optimization Gas Turbine Compressor and Generator Fuel Gas Pressure to Maximize Production in X Field","authors":"","doi":"10.29118/ipa22-f-108","DOIUrl":"https://doi.org/10.29118/ipa22-f-108","url":null,"abstract":"X plant with capacity 800 MMscfd has 2 major process plant, Inlet Compression system to lower the inlet pressure and gas plant to treat the raw gas to meet sales gas specification. The inlet compression consists of inlet cooling/separation and compression system. Currently, the inlet compression was operated with pressure 455, 420 and 400 psig at inlet header, separator, and suction compressor respectively. The condensate from separator flow to condensate stabilization system with pressure 380 psig. The flash gas in condensate system then used as fuel gas for gas turbine engine at 340 psig. There was a well drilling plan which require to shut-in one major well and lead to X production decrease to 670 MMscfd with inlet header pressure 455 psig. Reducing inlet header pressure couldn’t be done due to separator pressure requirement whereas allowing condensate can still flow to condensate system then become such a process bottleneck. Deep evaluation was performed to lower the fuel gas supply pressure of Turbines in purpose lower pressure in condensate system in term of gas hydrocarbon dewpoint, LHV, wobbe index, fuel gas valve opening, engine performance, acceleration time from light-off to idle speed, drop on speed/frequency during transient to maximum possible load. As study concluded, performance test was conducted and succeed to decrease the fuel gas supply pressure from 340 to 260 psig, then it is beneficial to reduce the inlet header pressure from 455 psig to as low as 375 psig. The optimization of HP fuel gas pressure can maximize production in X field from 670 MMscfd to 720 MMscfd with no additional capital cost during shut-in major well for new well drilling. Therefore, optimizing the fuel gas pressure of Gas turbine engine can maximize the well production.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"31 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":"132981919","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}