Ecuador
To start the process of digital transformation in the oil production operations carried out in the Ecuadorian Oriente Basin, the methodology proposed was based on "MIT Sloan School of Management" and established for all the processes of innovation and product creation, called RWW, "Real, Win and Worth". Real case studies in Ecuador will be discussed including not only production engineering analysis but also production operations in the field with a major focus on asset surveillance. Both activities require time-consuming tasks such as field trips and well-by-well analysis, showing the transformation in the way we operate leveraging the use of data, promoting remote operations, and automating the workflows used within the production engineering department. The starting point of this implementation was the well surveillance workflow, carried out at the field level because there was no mature SCADA system. Thus, the Edge was implemented with capabilities based on Internet of Things (IoT) technology to connect the different elements of the production chain. Currently, more than 400 pieces of equipment have been connected to a unified platform, including electro-submersible pumping equipment (ESP), wells with Beam Pumping (BM), injector wells, injection pumps, high-pressure injection equipment, multiphase flow meters and others, which allowed to the mature field to integrate data, perform real-time analysis and remotely control any equipment that is connected.
- Information Technology > Sensing and Signal Processing (0.97)
- Information Technology > Communications > Networks > Sensor Networks (0.60)
- Information Technology > Architecture > Real Time Systems (0.60)
- Information Technology > Communications > Web (0.50)
The complete paper investigates the relevance of wind and solar energy for the supply of artificial lift systems on offshore platforms in the Brazilian equatorial region. The scope of the authors' study encompassed a detailed technical and environmental assessment, with an emphasis on the integration of a 10-MW floating solar photovoltaic (FSPV) power system to meet demand for 10 pumps. The results obtained highlight the high viability of the system in meeting the demand of these pumps and ensuring an adequate and sustainable energy supply. The equatorial margin is an area in northern Brazil covering part of the sedimentary basins of the equatorial Atlantic. The region is home to important sedimentary basins such as the Amazon Basin, the Pará-Maranhão Basin, the Barreirinhas Basin, the Potiguar Basin, and the Ceará Basin, all known for their hydrocarbon reserves.
- South America > Ecuador > Orellana > Amazon Basin (0.99)
- South America > Brazil > Maranhão > South Atlantic Ocean > Maranhao Basin (0.99)
- South America > Brazil > Maranhão > South Atlantic Ocean > Barreirinhas Basin (0.99)
- South America > Brazil > Rio Grande do Norte > South Atlantic Ocean > Potiguar Basin (0.89)
The Talara Basin is a sedimentary basin that is located along the northwestern coastline of Peru that covers 11000 mi2. The basin is contained to the east by the uplift created by the La Brea-Amotape Mountains that divides the Talara from the Lancones and Sechura Basins. The La Casita fault and Paita High uplift creates its southeastern boundary. The northern limit is the Pillar of Zorritos, which is a basement uplift and fault zone. The basin is contained to the south by the Trujillo Basin and to the west by the Nazca Plate subduction zone[1].
- Phanerozoic > Paleozoic (1.00)
- Phanerozoic > Cenozoic > Paleogene (0.54)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.49)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.35)
- South America > Peru > Trujillo Basin (0.99)
- South America > Peru > Sechura Basin (0.94)
- South America > Peru > Progreso Basin (0.94)
- South America > Ecuador > Progreso Basin (0.94)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Abstract A study of the A/M2 limestone formation in the Putumayo and Oriente basins had as its objective estimating the oil production potential of the unconventional reservoir and the estimated resources from an exploration, appraisal, and pilot project. This approach is a paradigm shift for a conventional basin in which there is limited experience in tight or unconventional reservoir development. Despite being a calcareous shale, the A/M2 reservoir shows oil saturation and oil-prone characteristics, with most permeability values below 1 md, indicating the need for an unconventional approach. Vertical fractured wells showed production rates ranging from 50 to 150 B/D of 31°API oil. However, economic production presents technical, operational, and logistical challenges. This reservoir has been previously studied, evaluated, and developed in the Putumayo Basin near the Ecuadorian border with mixed results. Reserve reports and resource estimations from operators and government agencies and core data were reviewed to determine whether the reservoir should be classified as tight or unconventional based on the permeability to support the A/M2 reservoir potential in Ecuador. The study involved a comprehensive workflow for designing an unconventional pilot project, leveraging existing data and employing current practices from an Argentinean operator working in the Vaca Muerta formation as reference. This study serves as an initial step to evaluate the potential reserves in the A/M2 limestone reservoir. Using an unconventional hydraulic fracturing simulator, the fracture geometry for each phase was estimated and equipment, proppant mass, and fluids necessary for implementation were dimensioned. The simulation model used well logs, geomechanics data, and the results of minifrac and diagnostic fracture injection tests and fracturing results from two vertical offset wells, located in the already developed areas of the Oriente Basin. Finally, the production forecast and the expected recovery are estimated using simulation results obtained from an analytical reservoir model.
- South America > Ecuador (1.00)
- South America > Argentina > Patagonia Region (0.24)
- South America > Argentina > Neuquén Province > Neuquén (0.24)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.49)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.38)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.70)
- South America > Peru > Marañón Basin (0.99)
- South America > Ecuador > Sucumbíos > Oriente Basin > Block 11 > Bermejo Field > Tena Formation (0.99)
- South America > Ecuador > Sucumbíos > Oriente Basin > Block 11 > Bermejo Field > Hollin Formation (0.99)
- (13 more...)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- (4 more...)
Advancements in Applications of Machine Learning for Formation Damage Predictions
Abdulmutalibov, T. E. (Azerbaijan State Oil and Industry University, Baku, Azerbaijan) | Shmoncheva, Y. Y. (Azerbaijan State Oil and Industry University, Baku, Azerbaijan) | Jabbarova, G. V. (Azerbaijan State Oil and Industry University, Baku, Azerbaijan)
Abstract Reservoir damage is a critical a major concern within the oil and gas sector that has the potential to have a significant impact reduce reservoir productivity. Traditional methods of repairing formation damage are frequently requiring a substantial amount of manual effort and consuming a considerable amount of time. This study delves into the utilization of machine learning methods as a promising solution for predicting, mitigating, and managing reservoir damage. The study begins with a discussion of the various elements that lead to the occurrence of formation damage, including rock-fluid interactions, drilling operations, and production processes. It then highlights the limitations of traditional methods and emphasizes the need for data-driven approaches. Machine learning models such as support vector machines, regression analysis, and neural networks are introduced as tools for analyzing large data sets derived from reservoir modeling, wellbore data, and production history. These models identify key parameters and patterns associated with formation damage, which helps predict potential damage. Additionally, this research paper investigates the application of machine learning for optimizing drilling and completion strategies with the aim of reducing the likelihood of formation damage. It addresses the incorporation of real-time data monitoring and predictive analytics to enhance reservoir management methodologies. The paper presents case studies and practical implementations of machine learning aimed at mitigating formation damage. These examples illustrate the potential for enhancing reservoir performance, cutting operational expenses, and boosting hydrocarbon production. It also outlines challenges and future directions for research in this area, highlighting the importance of continued innovation in machine learning and data mining methods to promote the sustainable growth of the oil and gas sector. In conclusion, the application of machine learning for formation damage management represents a transformative approach to address a critical challenge in the oil and gas sector. This research contributes to the development of knowledge and practical implementation of machine learning methods to optimize reservoir performance while minimizing the effects of reservoir damage.
- Asia (0.68)
- South America > Ecuador (0.28)
- Africa > Nigeria (0.28)
- Overview > Innovation (0.66)
- Research Report > New Finding (0.48)
- Geology > Geological Subdiscipline (0.68)
- Geology > Rock Type (0.46)
- South America > Ecuador > Sucumbíos > Oriente Basin > Shushufindi Field > Napo Formation (0.99)
- South America > Ecuador > Napo > Oriente Basin > Shushufindi Field > Napo Formation (0.99)
- Information Technology > Artificial Intelligence > Machine Learning > Statistical Learning > Support Vector Machines (0.55)
- Information Technology > Artificial Intelligence > Machine Learning > Statistical Learning > Regression (0.48)
- Information Technology > Artificial Intelligence > Machine Learning > Learning Graphical Models > Directed Networks > Bayesian Learning (0.46)
The Best Scenario for Geostatistical Modeling of Porosity in the Sarvak Reservoir in an Iranian Oil Field, Using Electrofacies, Seismic Facies, and Seismic Attributes
Mehdipour, Vali (Department of Petroleum Engineering, Amirkabir University of Technology) | Rabbani, Ahmad Reza (Department of Petroleum Engineering, Amirkabir University of Technology (Corresponding author)) | Kadkhodaie, Ali (Earth Sciences Department, Faculty of Natural Science, University of Tabriz)
Summary The lateral and vertical variations in porosity significantly impact the reservoir quality and the volumetric calculations in heterogeneous reservoirs. With a case study from Iran’s Zagros Basin Sarvak reservoir in the Dezful Embayment, this paper aims to demonstrate an efficient methodology for distributing porosity. Four facies models (based on electrofacies analysis data and seismic facies) with different geostatistical algorithms were used to examine the effect of different facies types on porosity propagation. Both deterministic and stochastic methods are adopted to check the impact of geostatistical algorithms on porosity modeling in the static model. A total of 40 scenarios were run and validated for porosity distribution through a blind test procedure to check the reliability of the models. The study’s findings revealed high correlation values in the blind test data for all porosity realizations linked to seismic facies, ranging from 0.778 to 0.876. In addition, co-kriging to acoustic impedance (AI), as a secondary variable, increases the correlation coefficient in all related cases. Unlike deterministic algorithms, using stochastic methods reduces the uncertainty and causes the porosity model to have an identical histogram compared with the original data. This study introduced a comprehensive workflow for porosity distribution in the studied carbonate Sarvak reservoir, considering the electrofacies, and seismic facies, and applying different geostatistical algorithms. As a result, based on this workflow, simultaneously linking the porosity distribution to seismic facies, co-kriging to AI, and applying the sequential Gaussian simulation (SGS) algorithm result in the best spatial modeling of porosity.
- Europe (1.00)
- Asia > Middle East > Iran (1.00)
- North America > United States > Texas (0.67)
- Africa > Middle East > Egypt > Nile Delta (0.28)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.46)
- Phanerozoic > Mesozoic > Cretaceous > Lower Cretaceous (0.46)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.93)
- Geology > Sedimentary Geology (0.93)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.46)
- South America > Ecuador > Oriente Basin (0.99)
- South America > Ecuador > Napo > Oriente Basin > Napo Formation > Napo T Formation (0.99)
- Oceania > Australia > Western Australia > Perth Basin (0.99)
- (18 more...)
Technical Evaluation of the Use of Hybrid Energy (Solar and Offshore Wind) to Supply Artificial Lift Pumps on an Oil Platform on the Equatorial Margin
Silva, W. K. (Federal University of Pará Salinópolis) | Cunha, A. L. (Federal University of Pará Salinópolis) | Alves, A. C. (Federal University of Pará Salinópolis) | Gomes, V. J. C. (Federal University of Pará Salinópolis) | Freitas, P. P. (Federal University of Pará Salinópolis) | Restrepo, D. F. (Federal University of Pará Salinópolis) | Salinas-Silva, R. (Fundación de Educación Superior San José Bogotá) | Camacho-Galindo, S. (Fundación de Educación Superior San José Bogotá) | Guerrero-Martin, L. E. (Fundación de Educación Superior San José Bogotá) | Guerrero-Martin, C. A. (Federal University of Pará Salinópolis)
Abstract This article aimed to analyze the relevance of wind and solar energy for the supply of artificial lifting systems on offshore platforms in the Brazilian equatorial region. The scope encompassed a detailed technical and environmental assessment, with an emphasis on the integration of a 10 MW floating photovoltaic power (FSPV) system to meet the demand for 10 pumps. In addition, the study sought to evaluate the potential for solar power generation in the region, considering the abundant global horizontal solar radiation (GHI). The methodology employed involved a thorough evaluation of the energy required for the artificial lifting system, using nine steps as described by Centrilift. For the analysis of solar power generation, the System Advisor Model (SAM) developed by the National Renewable Energy Laboratory (NREL) was used. The meteorological data and wind potential were obtained from measuring stations of the National Institute of Meteorology (INMET). Through SAM, FSPV performance has been carefully modeled, considering different scenarios to determine the viability of the power solution. The results obtained highlighted the high viability of the 10 MW FSPV system to meet the energy demand of the 10 artificial lifting pumps. The simulations carried out in the SAM indicated a significant annual generation of electricity, with a high supply capacity and a good performance index, ensuring an adequate and sustainable energy supply over time. In addition, the analysis revealed the promising potential of solar power generation in the equatorial region, consolidating FSPV as the most appropriate option and with the best prospects for offshore platforms in this location. This study provides valuable information by highlighting the feasibility of floating solar energy as a viable energy solution for offshore platforms in the Brazilian equatorial region. The integration of the FSPV system was thoroughly evaluated, demonstrating the benefits of the abundant availability of solar radiation, as well as the modulation and scalability of the systems. In addition, the environmental impacts associated with both energy sources were identified, underscoring the importance of mitigating any possible negative effects. The study presents an in-depth and reasoned analysis, offering valuable guidance for future renewable energy projects in regions of similar characteristics.
- South America > Brazil (1.00)
- North America > United States (1.00)
- Energy > Renewable > Solar (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.47)
- South America > Ecuador > Orellana > Amazon Basin (0.99)
- South America > Brazil > Maranhão > South Atlantic Ocean > Maranhao Basin (0.99)
- South America > Brazil > Maranhão > South Atlantic Ocean > Barreirinhas Basin (0.99)
- South America > Brazil > Rio Grande do Norte > South Atlantic Ocean > Potiguar Basin (0.89)
Development of a New Digital Monitoring and Surveillance Platform in a Regulatory Agency in Latin America
Zarate, G. (Agencia Nacional de Hidrocarburos, Bogotá D.C., Cundinamarca, Colombia) | Tello Bahamon, C. C. (Sensia, Bogotá D.C., Cundinamarca, Colombia) | Vivas, P. (Sensia, Bogotá D.C., Cundinamarca, Colombia)
Abstract Hydrocarbons regulators and inspectors face technical and operational challenges in monitoring fields and assets. The remoteness of field locations, data governance and contractual rules make this task difficult to track. This paper presents the implementation of a monitoring platform designed by a regulatory agency in Latin America, the underlying technology, the process followed, and the results and benefits of this initiative. This monitoring platform was developed using various systems to support the data streams used in the overall process. During the first phase, the system architecture was defined to outline the main components of the monitoring platform, data flows and hierarchy. A data quality and standardization process were outlined to ensure consistency and validation of the data coming from the oil and gas assets. A production data management system was then integrated to collect, store, and display all production operations information and measurements. In addition, a Geographic Information System was embedded into the monitoring platform after a careful review of geo-referenced details of fields and wells for each of the operating companies. Finally, the user interface design included the definition of monitoring dashboards and various visualization screens.
- South America > Brazil (0.94)
- Asia > Middle East (0.69)
- North America > United States > Texas (0.46)
- Law (1.00)
- Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- South America > Ecuador > Sucumbíos > Oriente Basin > Shushufindi Field > Napo Formation (0.99)
- South America > Ecuador > Napo > Oriente Basin > Shushufindi Field > Napo Formation (0.99)
Electrical Conductivity of Pipeline Deposits Under Pressure and Their Impacts on Sales-Gas Pipeline Cathodic Protection Systems
Macario, Erwin (Department of Chemical Engineering, The University of Melbourne) | Carroll, Francis (APA Group) | Xu, Xiaoda (Origin) | Brown, Justin (Santos Ltd) | Stella, Dario (Jemena) | Kentish, Sandra E. (Department of Chemical Engineering, The University of Melbourne (Corresponding author))
Summary Natural gas pipelines are critical for safe and efficient energy transport across large distances. To maintain operational safety, pipelines use cathodic protection systems that minimize the rate of external corrosion. This work characterizes the effects of black powder deposits, a widely experienced operational hazard across the natural gas industry, on the failure of pipeline cathodic protection systems due to electrical “shorting” of isolation devices. Black powder sludgy deposits from coal seam gas (CSG) pipelines were analyzed, revealing electrical conductivity values within the range of 580 to 5400 µS/cm when under pipeline pressure. These values were used to calculate the internal resistances of monolithic isolation joints (MIJs), a type of electrical isolation device, to show that electrical shorting (internal resistance of < 100 Ω) can occur for black powder sludgy deposit thicknesses in the range of millimeters. To reduce the frequency of such shorting events, it is recommended that upstream dehydration systems be designed to reduce carry-over of triethylene glycol (TEG), that internal nonconductive coatings be applied to isolation devices, and that these devices are installed in ways that facilitate regular cleaning.
- North America > United States (1.00)
- Oceania > Australia > Queensland (0.15)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Midstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.46)
- Oceania > Australia > Queensland > Surat Basin (0.99)
- Oceania > Australia > New South Wales > Surat Basin (0.99)
- South America > Ecuador (0.93)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- (5 more...)
Implementing Selective Water Injection Strategy in Thin Reservoirs of a Mature Field in Ecuador
Paredes, L. A. (SLB) | Cornejo, P. I. (SLB) | Bermeo, P. D. (SLB) | Luzuriaga, K. R. (SLB) | Zamora, P. I. (SLB) | Anaya, J. D. (SLB) | Bonfanti, B. F (SLB) | Alba, E. G. (NOC - EP Petroecuador) | Garrido, J. M. (NOC - EP Petroecuador) | Mendoza, M. A. (NOC - EP Petroecuador) | Torres, W. N. (NOC - EP Petroecuador)
Abstract Cononaco is a mature oilfield located south of Block 61 in the Oriente Basin, Ecuador. The reservoir, Napo U, comprises two thin layers: U Superior and U Inferior. The objective of this study was to enhance recovery in U Superior by revitalizing the waterflooding patterns using four injector wells, while simultaneously pressurizing U Inferior. To accomplish this, a decision was made to employ a selective water injector well for both U Superior and U Inferior, utilizing a peripheral injection strategy to improve the displacement of trapped oil accumulations. Consequently, the chosen candidate well for this purpose was CNOF-064WIW, which satisfied the requirements and possessed the necessary resources. These requirements included minimal investment in existing facilities, good sand connectivity, and optimal rock properties for both reservoirs, as well as a peripheral location and favorable mechanical conditions to convert it into a selective water injector well. The collaboration among various technical disciplines such as subsurface, production engineering, and surface facilities has resulted in the development and implementation of a selective injection redesign. To ensure an adequate water supply for the expansion project in U Inferior and U Superior, as well as the addition of a selective injector well in the area, a novel redesign of the surface facilities was proposed. This proposal involved the reuse of the same water source well, CNOF-054WDF (aquifer water from the Hollin Formation, meeting all quality standards). This approach aimed to reduce costs associated with constructing a new injection plant, including the processing and water treatment facilities. Consequently, the well CNOF-054WDF (dump flooding – one string for water production and one string for water injection) was selected as the water source to serve both injector wells (CNOF-054WDF and the implemented selective injector, CNOF-064WIW). This was achieved through the redesign of a single pipeline to implement the selective injection system, thereby avoiding additional and costly expenses. The average injection rate for the selective injector is 2,000 barrels per day (BWIPD), with 40% allocated for U Superior and 60% for U Inferior. These allocations were based on measurements obtained from injection logging tools. Since the implementation of the water injection project in U Inferior through CNOF-064WIW in January 2022, the developed reserves through secondary recovery has been estimated in 0.154 MMBo up to the present date. Similarly, since the implementation of the water injection project in U Superior through the four injectors CNO-0021REWIW, CNO-007REWIW, CNOF-054WDF, and CNOF-064WIW in June 2019, the developed reserves through secondary recovery are estimated to be 1.68 MMBo up to the present date. Furthermore, the project resulted in a reduction of water cut from 90% to 70%, effectively displacing newly contacted oil banks in U Superior. In U Inferior, the reservoir pressure increased by around 300-600 psi, reaching a large area after water injection. Additionally, the selective injection equalized the reservoir pressure in both reservoirs, ranging from 2,000-2,200 psi, which has greatly benefited the commingled production in the area. The results achieved with this selective injector well have unlocked the opportunity for expansion into the southern portion of the initial study area. This project marks the first successful selective water injection project implemented in thin reservoirs (5-15 ft) in Ecuador. Its significance lies in the low investment required for its execution, as it only necessitated the redesign and reengineering of available resources to assemble a functional injection system for two independent reservoirs. The CNOF-064WIW selective water injector well effectively pressurizes and displaces oil from the east flank using a peripheral injection approach. This well contributes to the Cononaco field development plan and enhances oil production by achieving an adequate injection-production balance. The thin reservoir's nature benefits the waterflooding project's fast response, allowing for optimization and exploitation opportunities.
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.94)
- Water & Waste Management > Water Management > Lifecycle > Treatment (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- South America > Peru > Marañón Basin (0.99)
- South America > Ecuador > Orellana > Oriente Basin > Cononaco Field (0.99)
- South America > Ecuador > Napo > Oriente Basin > Napo Formation > Napo T Formation (0.99)
- (2 more...)