bluuebunny/crossref_metadata_2025 huggingface dataset:
Comparative Environmental and Economic Assessment of the Zahle Wastewater Treatment Plant in Lebanon under Different Scenarios. (c2022)
Authors:   ,   Lebanese American University, Ghosb Dit Ghosn Michelle
Published: March 2023

Assessing the environmental impacts of wastewater treatment plants (WWTPs) is a growing concern that needs to be addressed. Although several studies have been published on the environmental performance of WWTPs, few have been reported from developing countries, especially in Lebanon. In this study, the environmental and economical performance of an oxidation ditch-based secondary treatment technology in Zahle, Lebanon, was evaluated using life cycle assessment (LCA) and life cycle cost (LCC) in conjunction with computer modeling. The current plant was calibrated and validated using GPS-X v. 8.0 software and three hypothetical scenarios were suggested and compared with its current state. The first scenario (S1) included adding anaerobic sludge digestion. The second scenario (S2) included using extended aeration. The third scenario (S3) included using a five-stage Bardenpho (FSB) process. For this purpose, a series of LCAs were performed using SimaPro 9.3.0.3 together with the ecoinvent 3.8 database, and the ReCiPe midpoint (H) and endpoint (H/A) methodologies. A functional unit of 1 m3 of treated wastewater was used as a basis. The WWTPs costs were estimated using the CapdetWorks v4.0 software. Further, LCA was monetized using external costs. The analysis revealed that the environmental categories were primarily influenced by energy consumption. The current plant had a global warming effect of 0.678 kgCO2 eq/m3. Normalized results showed that the first scenario was the most environmentally friendly alternative in the human carcinogenic toxicity impact category quantified as follows: S2 < S0 < S3 < S1. Normalized results also showed that freshwater ecotoxicity and human carcinogenic toxicity were the main impact categories. The economic evaluation revealed that the addition of anaerobic digestion led to more expenses, while S0 process was found to be the most cost-effective. The descending order concerning environmental costs was as follows: S2(0.171$/m3) > S0(0.159$/m3) > S3 (0.147$/m3) > S1 (0.117$/m3). Considering the collective evaluation, scenario S1 was chosen as a potential enhancement for the Zahle WWTP (ZWWTP). This study emphasized the importance of the environmental impact assessment in the wastewater treatment (WWT) sector and contributed to the growing body of literature related to WWT in Lebanon. Further research is needed to provide a clear data collection process that will increase the modeling precision of an existing plant and accurately reflect the outcomes.
Saberes de inovação pedagógica de formadores de professores
Authors: Domingos Silvio Duarte , Chamon Edna Maria Querido de Oliveira
Published: March 2023

O objetivo do artigo foi conhecer os saberes docentes que estão relacionados às práticas de inovação pedagógica na graduação em Pedagogia. Implementou-se uma pesquisa qualitativa, alinhada à abordagem processual da Teoria das Representações Sociais (MOSCOVICI, 2012). Participaram 23 professores de Pedagogia de uma universidade privada, na cidade do Rio de Janeiro. Os dados foram coletados por meio de entrevistas semiestruturadas e submetidos à análise de conteúdo (BARDIN, 2011), com apoio do software IRaMuTeQ. Os resultados mostraram que as representações sociais dos sujeitos sobre inovação pedagógica se objetivam em “mudança”, “metodologia ativa” e “aluno” e se ancoram na dualidade “pedagogia tradicional versus pedagogia nova”.
КРИСТАЛЛИЧЕСКИЕ СТРУКТУРЫ ПРОПИОНАТОВ АММОНИЯ: (NH4)[HProp2] и (NH4)Prop (Prop- = C2H5COO–)
Authors: Кендин М.П. , Цымбаренко Д.М.
Published: March 2023

Взаимодействием водного раствора аммиака с пропионовой кислотой получены два кристаллических соединения – (NH4)HProp2 и (NH4)Prop (HProp = C2H5COOH), для которых методом РСА расшифрованы кристаллические структуры. Оба соединения кристаллизуются в моноклинной сингонии (пр. группы C2/c и P21/n, соответственно) и состоят из чередующихся ионов NH4+ и Prop– (или водородосвязанных пар Prop–H∙∙∙Prop–), сочлененных водородными связями в трехмерный каркас. Структурная особенность соединения (NH4)HProp2, заключающаяся в позиционном разупорядочении «кислых» атомов водорода между карбоксильными группами пропионат-анионов, была исследована методами максимальной энтропии и квантовохимического моделирования. Аналогично гомологичным карбоксилатам аммония, (NH4)Prop чрезвычайно неустойчив в атмосферных условиях, в то время как «кислая» соль (NH4)HProp2 стабильна при хранении и может быть использована для дальнейшего синтеза пропионатов металлов.
Stability of Co-amorphous Solid Dispersions: Physical and Chemical Aspects
Authors: Aher A.A. , Shaikh K.S. , Chaudhari P.D.
Published: March 2023

Drug amorphization is one of the major approaches in pharmaceutical sciences to improve the solubility and dissolution rate of poorly water-soluble drugs. Amorphous solid dispersions are widely discussed approach to convert the drug into an amorphous state but due to its high energy state, the system tends to recrystallize upon storage. Co-amorphous system is a single-phase low energy system that falls under the glass solution, a type of solid dispersion. Being low-energy state and single-phase, co-amorphous dispersions are more stable than amorphous solid dispersions. In co-amorphous dispersions, the homogeneous single phase is formed only with low molecular weight co-formers, so the amount of co-former required is relatively low and this reduces the bulk of the system. This aspect of co-amorphous dispersions makes it popular over the amorphous solid dispersions in the area of solid dispersion researchers. This review provides an overview of co-amorphous dispersions and their recent advances. Particularly, this review will discuss various factors (physical and chemical) that affect and provide the stability of the co-amorphous dispersions formulation.
El Chimborazo entre las aproximaciones científicas y culturales de Alexander von Humboldt (1802-1805) y Edward Whymper (1880-1892)
Authors: Aguirre Negrete Patricio
Published: March 2023

Este artículo analiza las representaciones científicas y culturales de Alexander von Humboldt y Edward Whymper sobre el Chimborazo. En el caso de Humboldt, se estudia el perfil que elaboró de la montaña para escenificar la distribución vertical de las plantas y la naturaleza como una totalidad, en 1805. En cuanto a Whymper, se estudia su ascenso al nevado en 1880, su trabajo fisiológico y cartográfico en los altos Andes del Ecuador. Ambas representaciones son vistas como modelos de creación de lo natural, donde intervienen encuadres científicos, estéticos y artísticos. Se comparan esas experiencias y su influencia en la exploración científica y el montañismo del siglo XIX.
Juramento Constitucional y elecciones gaditanas en el Corregimiento de Otavalo, 1813
Authors: Guerra Pabón Lenin
Published: March 2023

El artículo estudia cómo se desarrollaron en Otavalo las ceremonias de publicación y jura de la Constitución Política de la Monarquía Española; y la forma en que se llevó a cabo la instauración del cabildo constitucional de Otavalo y los comicios. En esta población, la Constitución fue recibida como la manifestación de la nación española ante la ausencia del rey. Sin embargo, el vínculo el texto constitucional y el monarca ausente dieron al momento gaditano otavaleño un fuerte aire fidelista.
El voto femenino: un episodio de la guerra cultura Estado-Iglesia. Ecuador, 1928-1929
Authors: Orquera Polanco Katerinne
Published: March 2023

El artículo evalúa la forma en que la historiografía ecuatoriana ha estudiado el acceso al voto de las mujeres alfabetizadas en el Ecuador, aprobado por la Asamblea Constituyente de 1928-1929. Ofrece una revisión crítica de los estudios sobre el tema y una nueva lectura sobre las razones por las que se otorgó el derecho al voto a las ecuatorianas alfabetizadas, quienes fueron las primeras en sufragar en América Latina. Con este objetivo, se estudia el contexto político marcado por una guerra cultural entre la Iglesia y el Estado, que tuvo como uno de sus principales componentes la participación de las mujeres en el espacio público.
Silvia Benítez Arregui, Voces de mujeres de la plebe en el Hospicio de Quito 1785-1816
Authors: Mejía Román Diego
Published: March 2023

s. r.
Preguntas comunes, respuestas distintas: un debate con Pablo Ospina sobre la formación del campo político y estatalidad en Ecuador del siglo XX
Authors: Coronel Valeria
Published: March 2023

s. r.
Comentarios sobre el Estado transformista en el Ecuador
Authors: Vega Ugalde Silvia
Published: March 2023

s. r.
Carlos D. Ciriza Mendívil, Naturales de una ciudad multiétnica. Vidas y dinámicas sociales de los indígenas de Quito en el siglo XVII
Authors: Mamani Fuentes Francisco
Published: March 2023

s. r.
Claudio Creamer, El salario mínimo en la industria ecuatoriana. Debates precursores entre 1934 y 1935
Authors: Luna Andrade Sebastián
Published: March 2023

s. r.
Minimizing Potential Operational Risk, Schedule and Cost Impact Through Early Quality Assesment of Local OCTG Mills: The Dilemma of Achieving Production Target and Overcoming Supply Chain Challenge in Indonesia
Authors: Idris M.I
Published: March 2023

Tubulars are part of the backbone in Oil and Gas industries, especially in drilling operations as it serves as structural support, conduit, protection, pressure isolation and well barrier. Although generically the cost of tubulars could be ranging around 9-10% of the total well cost (based on PC Ketapang II Ltd. Operation), it is an integral part of the well that protects the company’s millions of dollars investment throughout the life of the well. As such, it is crucial to ensure company able to procure and utilize acceptable quality of tubulars for its operations to minimize potential operational risk, schedule and cost impact.Indonesia has many capable local mills that are certified by American Petroleum Institute (API) and recognized by the host authority as registered in Buku Data Kemampuan Nasional Industri Penunjang Migas Nasional Tahun 2021 by SKK Migas(1). However, the process and assessment result for these mills to be registered was not easy to be accessed to identify any gap with operator's standard. In order to support the aspiration by host authority to utilize local products, specifically to support the local pipe industries, the oil and gas operator as the investor shall also fulfil internal requirement to assess the pipe manufacturers in Indonesia, specifically. The assessment was conducted successfully and shows that the local mills in Indonesia have Quality Management System (QMS) and QAQC process that meets both international standards and company internal requirement. By having this assessment process, the potential risk can be minimized and local supply chain challenge can be mitigated to contribute in Indonesia Government’s aspiration towards 1 Million BOPD and 12 BSCFD target in 2030.
Optimizing PSC With New Approach of Dynamic Split Determination to Mitigate Uncertainty in The Development Phase
Authors: Adriansyah Y.F
Published: March 2023

It is commonly realized that in the development phase of oil fields the project still holds numerous uncertainty factors that will affect its economic value in the future. The main uncertainties associated in the development phase are production forecast, capital and operating cost and oil price. Deviation of these parameters to the actual conditions could deteriorate the project cash flow and possibly cause the company to decide to terminate their exploitation project. This paper proposes an alternative methodology of fiscal adjustment of Production Sharing Contract (PSC) to overcome uncertainties in the development phase. The concept is to apply the dynamic split to the existing fiscal term, which is determined by simple linear regression of Internal Rate of Return (IRR) and gradient of cumulative Profit/Cost (P/C) which represent probable range of uncertainties related to the project. From the regression, an equation is developed to calculate the additional (or deduction) of contractor split in each year to normalize the IRR to the ‘mean’ value or other agreed value when the deviation occurs. Contractor will get additional split if the actual contractor profitability tends to bring low IRR, otherwise host government will get additional benefit if the actual profitability tends to bring higher IRR. The application of this fiscal optimization method could minimize the standard deviation of contractor IRR. It will solidify the confidence of contractor to continue to run the business. From the case studied here, the standard deviation of contractor IRR histogram is compressed by 38.9% compared to the current PSC fiscal terms. As it could balance the tradeoff between contractor and government in terms of uncertainties, it is expected to be the alternative solution to stimulate upstream industry investment.
Application of SPE SRMS and Certification of CO2 Storage Capacity
Authors: Billingsley B
Published: March 2023

Assessment and certification of CO2 storage “capacity”, which is analogous to an oil or gas “reserve”, is an increasing focus area for those seeking storage and the investment community. The Society of Petroleum Engineers (SPE) 2017 CO2 Storage Resources Management System (SRMS) provides a classification framework to assess CO2 storage quantities which is likely to become widely adopted. Guidelines to support the SMRS are needed and expected during 2022. As companies in Indonesia seek recognition of carbon storage projects the complexities of the 2017 SRMS are discussed through theoretical and actual case studies. Specific technical issues with saline aquifer storage and depleted gas field storage differ but can largely be solved. However, the commercial requirements to mature “storage resources” to “capacity” are more complex. Both are discussed in this paper. A key criterion is the commerciality test required to move “contingent storage resources” to “capacity”. The commercialization pathway of CO2 storage projects will vary significantly between direct air capture (DAC), emissions reduction and third party CO2 disposal. In addition, the legislative framework in the host country or the investors country may have implications on what can be claimed as “capacity”. Developing the Indonesian Carbon Capture and Storage (CCS) sector depends on understanding current definitions of “capacity” and how future guidance, or investor requirements, may develop. The SRMS provides not only a framework for classification and certification, it can also be useful to expose successful strategies on the route to commercialisation.
The Role of ESG in Attracting Capital to The Petroleum Industry
Authors: Whitaker S.
Published: March 2023

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.
Probabilistic Technique to Estimate Duration of Rig-Less Gravel Pack Completion for a Better Planning
Authors: Sinaga R.
Published: March 2023

The operator has been utilizing a hydraulic workover unit to perform gravel pack completion in its offshore fields since 2019. Managing all fleets in the company's premises to meet the annual company's objective is quite complex and involves many stakeholders. Time and cost estimation for each campaign can be critical factors to predict and to arrange the work loads of each fleets. Taking immediate data from previous wells can create another issue since the types of job are different one to another. Hence, it is required to generate a probabilistic technique to estimate the duration which represents the workloads per campaign as much as possible. This paper discusses development of a probabilistic method to predict the time and cost of the rig-less gravel pack completion. Post data and facts are enhanced through statistical iteration to create a tool for estimating the duration. After all, the model has been beneficial to be used in the following projects of the rig-less gravel pack.
Continuous Liquid Unloading of Gas Well With High Gas/Liquid Ratio Production Using Electric Submersible Pump
Authors: Saputra M.N.W
Published: March 2023

A-Field, located in West Java, Indonesia, produces oil and gas under depleted reservoir pressure. Several wells require continuous liquid unloading prior to gas production. For some wells, dewatering is also required on a weekly basis, which is very challenging to execute even in a rig-less operation using coiled tubing or a slickline swab job. Thus, artificial lift methods were assessed to produce gas. An electric submersible pump (ESP) was selected as the artificial lift method because of the availability of the asset and the resources to manage it with a high gas/liquid ratio (GLR) and low bottomhole flowing pressure. The ESP was designed to unload the water during startup and maintain the fluid level in the well at a specific depth to produce gas through the annulus. The selected ESP has enhanced shaft strength to accommodate a sudden torque spike; high-temperature motor, oil, and elastomer used to run at a low rate; a higher-rated thrust bearing; cable with lead insulation protection; downhole sensor; and a gas handler, gas separator, and overstaged pump combination. The ESP was completed with closed-loop variable speed control, a gas-lock-protection (GLP) algorithm, and remote surveillance 24/7 to optimize production and prevent abnormal operating conditions. A small gas compressor at the surface was also installed to ensure that the annular pressure operates at the lowest level possible and to prevent excessive gas from entering the ESP. The installed ESP has been operating in a very high GLR environment for more than 223 days. This project demonstrates that current ESP technology can help operators produce gas in harsh environments, especially in mature fields with depleted reservoir pressure, limited lifting options, and frequent liquid unloading, or can be used to mitigate uncertainty when a gas zone with low pressure is opened for production during a well intervention.
First Application in Indonesia of Production Data Acquisition Using Logging Down Tractor Conveyance: Field Application in Anoa Field, Natuna
Authors: Simatupang A.R.J
Published: March 2023

The Anoa field is a mature field producing mainly from Lower Gabus Sand formation as the oil producer since 1990. In 2000, the field was converted into gas producers, supplying gas to GSA1 scheme. The field comprises of two major fault-separated lobes, referred to as East Lobe and West Lobe, with the smaller Central Lobe in between. Two platforms were built to drain the hydrocarbons: Anoa platform and West Lobe platform. A-22ST3 is a horizontal oil producer from B2 sand formation of Central Lobe Area with a total rate of 59 BOPD with 1079 BWPD (95%WC). The B2 sand has been watered out and oil rates are expected to continue declining. Meanwhile, the A-22 ST3 has un-perforated behind pipe in the Lower Gabus A and B1 sand within potentially un-drained Central Lobe faults block. There was no well producing from this A/B1 Central Lobe. It’s expected that these sands are isolated and have not been drained by existing producers. However, the A sand is located above the production packer and requires work-over to access the opportunity while B1 sand can be perforated thru-tubing using e-line tractor or CTU. Challanges in data acquisition/ survillance at Anoa field particularly in A-22ST3 was mainly programmed in busy and packed of well services activity for cost optimization, then the most well intervention method need to be chosen. The surveillance plan was proposed to obtain reservoir pressure properties from A and B1 sand, well deliverability, and production allocation post workover operation. Considering cost optimization, rigless operation was the safest and the most efficient menthod with e-line operation combined with Well Tractor with Logging while tractoring mode. Not only save more than 8 hours operation than coiled tubing conveyance or a heavier intervention method, eline and well tractor invtervention enabled less people involvement in operation thus minimize safety risk and person on board accommodation management.
Challengeable Hydraulic Fracturing In Sultanate of Oman (Achieving Better Hydraulic Fracturing Results in Challenging Reservoirs)
Authors: Riyami A.A
Published: March 2023

Picking a well candidate, having a proper design, and doing an effective post-job evaluation are major factors in achieving the best hydraulic fracturing results. Different fracturing techniques have been implemented in the Khaleel reservoir to enhance the fracture permeability. The well candidate targets are vertical and deviated cased-hole wells suffering from low production rates. A comprehensive procedure for selecting and ranking candidate wells for hydraulic fracturing has been developed. The procedure includes assessing the impact of key properties such as fracture height, depth of oil-water contact, the thickness of the oil column, and distance to faults. In addition, the lessons learned from previous appraisal campaigns have contributed to achieving optimum fracture geometry in future campaigns. Post-fracturing job techniques have been established with the operation guideline of the gradual start of pump production parameters to avoid backflow of proppant from formation to wellbore. A comprehensive strategy with the field operations team has been introduced as part of a good surveillance program to achieve well production targets. After obtaining production data, the team has conducted a comprehensive post-job evaluation on each aspect to improve the design by performing different techniques during pumping, modification of proppant concentration, and combining proppant size and chemical composition. This is part of several techniques that have been assessed along the process workflow. The improved workflow flow processes are highlighted and implemented for future selected wells of upcoming campaigns.
Increase Gas Well Reliability Through The Installation of Temporary Modular Portable Clamp-On Electric Heat Trace to Avoid Ice Block / Icing Wellhead At Start Up
Authors: Abidin A.Z
Published: March 2023

The gas well has many safety devices installed on wellhead such as pressure sensors, which have set the High-High (HH) set point parameters which can cause SDV to close. The “HH” often occurs due to icing on the wellhead when opening the well for the first time. The icing phenomenon occurs due to the sudden and excessive release of heat when the gas first flows which causes cold around the choke. Besides that, the presence of water in the fluid causes the formation of an ice blocking and the gas flow stops. This is the main reason for active safety devices and dead wells. Temporary Modular Portable Clamp-On Electric Heat Trace is an innovation in the form of a tool that functions to avoid icing on the wellhead when the well is first opened. The main equipment needed includes a heat trace cable and clamp modification housing. Initially, the power source from the portable generator is connected to the Heat Trace, after which it is installed in the wings tube when the well is first opened, the heat generated in the device will minimize the sudden release of heat when the gas starts flowing. This is done to prevent the formation of ice blocks around the choke area and the wellhead wings tube that can block the flow of gas. The result : Remove icing. Easy operation because it uses a heat source from VAC electricity, small power heat trace (20 W/meter) and a maximum temperature of 60 Celsius, so doesn't require heat sources such as steam or hot oil. Does’nt require major modifications such as pipes modification (double pipes) or tapping for glycol injections because the installation is only temporary, namely 20-30 minutes before the gas well start-up and then can removed again. Cheap cost (25$/30 meters)
Sequential Shrinking Particle Swam Optimization (SSPSO) and Hierarchical K-Means Clustering Methods to Improve Probabilistic History Matching and Forecast
Authors: Nopranda T.
Published: March 2023

This paper followed a probabilistic modeling workflow to incorporate reservoir uncertainty by inputting a range of values for each parameter instead of one deterministic value. This workflow aims to find several equiprobable history-matched models to capture the probable reservoir conditions and then find the production forecast range. Artificial intelligence algorithms, i.e., Particle Swarm Optimization (PSO) and k-means clustering, are utilized to assist during the modeling. PSO is one of the optimization methods that aims to find the minimum objective function. In reservoir modeling, the optimization method is used to minimize the objective function of the difference between the model’s calculation and the historical data. In the probabilistic approach, our objective is to find several unique history-matched model variants from the range of inputted data. However, the optimization algorithm such as the PSO tends to converge or be trapped into one solution and may ignore other probable variants. This paper proposes additional procedures to capture the uncertainty range better. To capture more variants, the PSO is modified by introducing a process that reruns the PSO but shrinks the search area. This new shrunk area is chosen based on the density of variants in the whole search area from the previous run. The new search area improves PSO’s probability of finding the missed variants. Another improved process is adding a hierarchical k-means clustering method to filter similar variants. By introducing this process, all variants are clustered into several groups. Some representatives from each group are picked to be carried over into the forecast step. The improved workflow is applied first to the analytic functions and then to the actual oil fields. This study shows that introducing sequential shrinking in Particle Swarm Optimization (PSO) and hierarchical clustering procedures can improve the capability of the probabilistic method to capture the range of production forecast.
Solvent Stimulation as a Solution for Heavy Oil Production in B Structure Pertamina
Authors: Alfajri R.
Published: March 2023

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.
Combining Gas Lock Prevention Module, Electric Submersible Pump, and Selective Perforation Strategy to Overcome Gas Production on Key Outstep Well in Depleted Conglomerate Oil Reservoir
Authors: Sarwono A.W
Published: March 2023

C field has been produced for more than 30 years, mainly from the conglomerate layer as the main oil layer producer. This main layer in the existing area was depleted in most of producing layers including the conglomerate layer. Thus, optimization in the existing wells to produce more oil become harder. Outstep drilling to find new potential area become the preferable option to give additional reserves and production. CMT-20 well, which was drilled as outstep well in a conglomerate layer in 2020, was a key well and would justify the next outstep development area. This well-produced oil from the conglomerate layer with high gas solution amount (GOR ~ 700 scf/stb). Produced with ESP become the only option, since the gas lift in the field is restricted and the other pumping method was unavailable.To maintain the production of this key well, dealing with the gas production is a must. Thus' a selective perforation strategy to reduce the gas amount production was chosen. Also, the Gas Lock Prevention Module (GLPM) was installed in ESP to prevent gas production in the later time (which was predicted with reservoir simulation and material balance analysis) due to the expanding secondary gas cap (weak water drive reservoir). Then, the specific pump parameter should be maintained to avoid the ESP problem. Using that combination, CMT-20 successfully produced with the average oil rate of 450 bopd and 6 months lifecycle and keeps producing until today. Before this solution, the CMT-20 lifecycle was less than a month. Therefore, the selective perforating strategy beyond the petrophysic concern and the combination with GLPM in ESP are needed to maintain the production of this key well. This method will still be used on the next development well and outstep well that targeted conglomerate layer as a default mode. There will be 3 more outstep wells that will be drilled in the upcoming year.
Well Management Strategy Through Integrated Production Modeling: Study Case Well B-5
Authors: Khoironi B.
Published: March 2023

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.
An Integrated Multidisciplinary Approach in Water Flooding Project Design for Future EOR Plan in Mature Oil Field Development
Authors: Suwito E.
Published: March 2023

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.
Alkyl Ester Sulfonate for Chemical Flooding With Light Oil in An Indonesian Sandstone Reservoir
Authors: Siregar G.
Published: March 2023

One method utilized in chemical enhanced oil recovery (cEOR) to boost oil production is surfactant flooding. Surfactants work by reducing the Interfacial Tension (IFT) at the interface between oil and water or when the wettability changes from oil-wet to water-wet. Sulfonate surfactants, such as Alkyl Ester Sulfonate (AES), are the most frequently applied surfactants for cEOR. This study aims to investigate AES for chemical injection screening. The study was carried on AES with various concentrations 0.1%, 0.3%, 0.5%, 1.0%, 1.5% and 2.0%.at room and reservoir temperature (60ºC). The IFT is used to determine the ability of surfactant to lower the oil/water IFT to 10-3 dyne/cm. Moreover, the IFT that was used to estimate the critical micelle concentration (CMC) for deciding the proper concentration and the concentrations that were chosen are moving on to the following testing step. Phase behavior test were conducted to determine the Winsor Type of surfactant solutions. The test conducted in a period time (210 days). Thermal stability test, adsorption test, and injectivity test of AES are used to determine the stability of surfactant solutions. Based on the surfactants screening, the IFT test showed two lowest (AES) concentrations, 0.3% and 0.5% yield IFT 1.0E-02 and 6.4E-03 dyne/cm, respectively. From behavior analysis, 0.3% and 0.5% inflict Winsor type III in the third and second days consecutively. The AES is in this phase until the 90th day and change to Winsor type I in the 120th to 210th day period for both concentrations. For thermal stability test, the IFT value was degraded in reservoir temperature, the IFT value of 0.5% decreased from 10-3 dyne/cm to 10-1 dyne/cm after 210 days. The adsorption test showed 2,669 µg/gr and 5,226 µg/gr of AES is adsorbed for 0.3% and 0.5% respectively. Injectivity test indicates that residual resistance factor (RRF) at injection rates of 0.2, 0.5, and 0.8 cc/min were 1.17, 1.29, and 1.41. RRF close to 1 clarifies that there will be no plugging after surfactant injection.
Recovering Lost Oil Reserves in Sandy Wells Using a Resin Injection Approach: Mutiara and Pamaguan Field - Indonesia Implementation
Authors: Mahardhini A.
Published: March 2023

Gas and oil production play a significant role in maintaining company sustainability, directly impacting profitability. Amid a gradually increasing oil price trend, combined with a company production sharing contract, the economic benefits for oil sales are significantly higher than gas, demanding operations focus on lifting oil instead of gas. Many uncertain variables make it difficult to achieve the full potential of the reservoir's oil production, with sand production contributing a large part of this. It is a condition in which the sand matrix is produced together with reservoir fluids, leading to production system damage and an operational threat to safety. The sand issues are caused by poor cementation of the reservoir (widely known as an unconsolidated reservoir), combined with a rate of production fluid that exceeds a value (may vary for different reservoirs) known as the critical rate. The simplest solution to avoid sand issues is drawdown pressure management from the reservoir into the wellbore to maintain the production fluid rate below the critical rate. However, this solution is often ineffective due to the dynamic behavior of the reservoir and production system environment. From a production point of view, this solution also negatively impacts the oil production delivery commitment and reserves if the well cannot flow continuously below the critical rate. This results in mandatory sand production prevention measures being implemented. In the Mutiara and Pamaguan fields, sand issues are prevented using a mechanical solution by installing a sand screen in the wellbore. Although this method is the most economical one, due to the limitations of sand screen size and selection, sand can still pass by the screen or cause plugging around the screen. Since this method only filters the sand downhole, sand deposition below the sand screen is still very likely, leading to the eventual covering up of open perforation intervals. Recently, another method has been implemented to prevent sand production using resin injection into the reservoir, with the objective being to enhance sand consolidation. This method has proved an economical way to treat sand problems without harming either the production or clearance in the well. This paper will give a better understanding of the sand problem and the benefits of this type of resin injection for treating sand problems based on a campaign of four oil wells in a mature field with its associated complexity. This sand consolidation treatment successfully recovered lost oil reserves totaling 215 Mbbl of oil.
Enhanced Vertical Flow Profile Determination of Fractured Basement Wells Using Temperature Log Interpretation
Authors: Faisal A.
Published: March 2023

The use of production logs in oil/gas wells provides valuable information to determine the contribution intervals and the productivity of each interval. In the fracture basement reservoir, determining the contribution interval remains a challenge. In general, the determination is based mainly on the information from drilling loss and the interpreted fault depth from the seismic, which are qualitative and rough estimates of the fault damage zone that contributes to flow. Spinner-based production logs are the most common method to interpret producing intervals but have several drawbacks that make them not always applicable in the following conditions: 1. High-angle trajectory and big bore size that could lead to an apparent down flow phenomenon; and 2. Rough and erratic wellbore surface of open hole completion which creates uncertainties and complicates interpretation, etc. An alternative method to spinners is the application of temperature logs. In recent years temperature logs have demonstrated that it can be a more suitable tool for running in fracture basement reservoirs because it can overcome potential problems with the wellbore environment, completion types, and produced fluids. The temperature derivative can be used to extract the information about sink/source at the wellbore, while the thermal modeling is used to quantify the flow. This paper describes the methodology used for the interpretation of temperature logs and highlights the capabilities that enable the user to dig deeper and gain a better understanding of the production intervals and quantify the contribution of each interval. The results are used to optimize field production with optimizations such as water shut-off, additional perforations, or further use for the drilling strategy to determine the landing depth of an infill well or may be widely used as an analog for exploration wells of similar fractured basement reservoirs.
Abating Carbon Emissions in Jack Up Rig Operations: A Case Study in Offshore East Java, Indonesia
Authors: Lumbantobing J.M
Published: March 2023

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.
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: Akbar M.I.
Published: March 2023

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.
Bioreactor for Carbon Capture: Model and Explanation
Authors: Angkasa M.A.G.
Published: March 2023

Currently, there are several alternative measures to reduce carbon emissions. One of them is by utilizing the reactions of organisms that can process carbon into certain substances. This process is in a vessel called a reactor, so it is often also referred to as a bioreactor. Laboratory-scale trials have often been carried out, but finding out how the role of several parameters in the success of reducing carbon content is also important to consider, before being carried out on a larger scale or further to be developed. So, it is necessary to make a model that can perform the sensitivity of several parameters that affect the effectiveness of the work of the bioreactor. This model is made by accommodating all thermodynamic equations and reaction kinematics, so it is hoped that it will be able to give a clearer picture of how the bioreactor works and the opportunity to develop.