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Collaborating Authors
Well Operations and Optimization
Abstract Water drive is the most important recovery mechanism for oil production. In time, water breakthrough occurs in high permeable layers, leaving oil behind in unswept layers. For 1999, the worldwide daily water production associated with oil production has been reported as 33 million m or roughly 3 barrels of water for each barrel of oil. Therefore water production imposes an ever increasing burden on our industry. Brightwater is one of polymers that were developed to control water production and enhance sweep efficiecy. This microgels polymer is characterized by swelling if they are exposed to a high temperature. The main advantage of this product is that it can be deployed by adding directly to the injection line. No rig or coiled tubing is needed. This paper present and analyze the first trial of using Brightwater as a shut off technique in Egypt. The main objective is to improve the sweeping efficiency of the water flooding in Belayim oil field by shutting off the water production. The study analyzed the flooding pattern in Petrobel Company and selected the suitable pattern. The selected pattern includes an ideal pattern of two wells. The layer between these two wells is highly heterogeneous, its permeability is 150 md and the thief zone permeability is 600 md. As a result, early breakthrough has been met after 180 days of injection start and the water cut increased to 86 ﹪. Based on reservoir condition, the suitable Brightwater grade have been selected. The performance of the Brightwater has been discussed. The treatment results were successful in the short run but in the long run, it is not much economic since the water cut starts to increase again. Heterogeneity and permeability direction are very important in applying Brightwater as the production rate of the offset well has been increased as a response of treatment indicating that the plan was not prepared enough for that treatment.
- Geology > Mineral (0.46)
- Geology > Geological Subdiscipline (0.46)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (0.41)
- South America > Argentina > Patagonia > Golfo San Jorge Basin (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Bradford Field (0.99)
- Asia > Indonesia > Sumatra > Riau > Central Sumatra Basin > Rokan Block > Rokan Block > Minas Field (0.99)
- (11 more...)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Conformance improvement (1.00)
- Production and Well Operations > Well Operations and Optimization > Produced water management and control (1.00)
ABSTRACT Faster simulation time continues to be a major industry priority for real-time application of integrated optimization asset modeling. Simultaneously, model sizes are rapidly becoming computationally more expensive. A new parallel simulation solution has been developed to quickly solve the largest and most complex modeling studies. This paper shows the benefits of the new parallel technique applied to a real case optimization. The described production optimization tool has the ability to integrate in a unique environment a whole production system, from wellbore to export and storage. A powerful evolutionary algorithm searches for the optimum field configuration that maximizes production. The tool computes the "fitness" of each solution, combines their properties in order to obtain new candidate solutions, and then selects the best individuals to allow the evolution of the population and detect the optimum. A master machine creates the individuals to be tested and multi-thread computation on a large number of simulation nodes allows to drastically reduce run times. The parallelism has been developed and applied to a complex integrated production optimization case study in order to prove the benefits of the novel architecture in terms of computational efforts. The tool was applied to the largest onshore oil field in Europe, with a very complex gathering network, and a large process plant composed of five treatment trains comprising acid gas removal and sulphur recovery unit. Comparison between the traditional and the parallel simulation architecture applied to the integrated production model of this asset shows a significant reduction in run times, decreasing from days to hours. These drastically reduced computational efforts have allowed the new simulator to include heavy computational methods to build more accurate models. Furthermore, the integrated production optimization tool has been developed to become an enterprise solution with an end-user friendly graphic interface linked to a common database for data handling and storage. This paper describes an innovative parallel simulation approach for an integrated production optimization tool. Reduced computational efforts and the possibility to build more accurate models are the main advantages of this tool, together with a newly developed friendly user interface. The benefits introduced by the novel parallel computational method developed for the tool guarantee real-time support to field production optimization even for the largest and most complex models.
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Production and Well Operations > Well Operations and Optimization (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
- (2 more...)
ABSTRACT In this paper, an innovative workflow to allocate commingled oil production is explained. Despite many attempts in past years (Hwang et al., 2000 and Zhao-Wen et al., 2016), allocating production in commingled wells, i.e. assessing the relative production from multiple pay zones in different wells, is still a big issue, in particular when the end member oils are not available or budget for PLT (Production Logging Tool) campaigns is limited. Our approach overcomes the problem of having end member oils through a wise combination of experimental geochemical analytical techniques and unsupervised state-of-the-art Machine Learning computational methods: in particular, data coming from high-resolution chromatographic methods have been processed in an original way, by identifying and exploiting all the smallest chemical differences among samples. Our approach was successfully tested in a blind way (i.e., without knowing a priori the exact composition of the oils in the mixtures), using both synthetic mixtures and real commingled oils. The synthetic mixtures were prepared using end member oils produced from different levels but chemically almost indistinguishable the one from the other. The real commingled samples were collected at wellhead. The case studies took into account very different situations in term of oil composition and geographical provenance. When possible, the results were compared with the results coming from industrial standard software (in case of availability of end members oils). The precision of the proposed method ranges from 3% (2 end member oils) up to 6% (4 end members oils) and for this reason our approach can be proposed as a cheap, advanced and accurate tool for Reservoir Management best practices. INTRODUCTION During an oil commingled production, fluids coming from different productive levels/wells are mixed. Monitoring and allocating contributions of different fluids are key aspects to optimize production: in particular, allocation refers to the practice of splitting wellhead-measured quantities of commingled oils coming from the different sublevels/wells of a reservoir. A clear identification of the production streams in terms of individual contributions in a single well, multi-well and multi-plants production scenario (see fig. 1) can facilitate timely decisions and interventions during all phases of development and management of an oilfield.
- North America > United States (0.47)
- Asia > Middle East (0.28)
- Asia > Middle East > Oman > Ad Dhahirah Governorate > Arabian Basin > Rub' al-Khali Basin > Safah Field (0.99)
- Africa > Middle East > Egypt > Western Desert > Obaiyed Field (0.99)
- Reservoir Description and Dynamics > Fluid Characterization > Geochemical characterization (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- Production and Well Operations > Well Operations and Optimization (0.94)
Take on Challenges in Deep-Water Production Optimization: A Real Successful Application of an Innovative Integrated Modelling Tool
Brioschi, S. (Eni Upstream & Technical Services) | Montini, M. (Eni Upstream & Technical Services) | Cerri, P. (Eni Upstream & Technical Services) | Scaramellini, S. (Eni Upstream & Technical Services) | Bianco, A. (Eni Upstream & Technical Services) | Masi, S. (Eni Upstream & Technical Services)
ABSTRACT The current oil price scenario is strengthening industry's attention towards a more efficient exploitation of resources. Low rates of return and marginal new field economics enhance the need for existing assets production optimization, especially for deep-water applications. This paper shows the results obtained from a real application on a deep-water asset of an innovative tool for the integrated production optimization of surface facilities based on a genetic algorithm. The described tool, coupled with its fluid-dynamic check workflow, has been applied to investigate the optimum configuration of the asset. The presented tool integrates well performances, gathering system calculation, and process plant simulation in order to optimize the field configuration with a global perspective. Conflicts and interactions between variables, constraints, and operational limitations are balanced and solved holistically by the optimization tool. The tool computes the "fitness" of each solution, combines the properties of them in order to obtain new candidate solutions, and then selects the best individuals to allow the evolution of the population and detect the optimum. The optimum configuration identified by the tool has been tested with a fluid-dynamic simulator in order to check its stability and identify the best operating procedure to reach the optimized configuration. The integrated production optimization tool has been applied on a FPSO with the aim to increase the production of the assets respecting all the operative and flow-assurance constraints typical of a deepwater application. The subsea network consists of seven oil wells connected to an FPSO with two identical parallel flowlines. Subsea manifolds allow to produce each well either through a flowline or the other. Furthermore, additional four wells are connected through a separate flowline to the same FPSO. Wells re-routing is treated by the tool as an optimization variable, allowing to explore all the possible available network configurations simultaneously. Additionally, a fluid-dynamic check workflow was implemented, in order to define the best procedure to switch from the current configuration to the optimized one, respecting all system constraints also during transient conditions. Finally, the optimization actions identified by the tool has been implemented successfully in the field. The paper describes an innovative approach for production optimization on a deep-water application. The integrated production optimization tool was able to explore all the possible network configuration simultaneously, thanks to the limited computational efforts required by the tool. Field application showed its benefits in terms of production enhancement, respecting all system constraints without running into any flow-assurance issue typical for deep-water. The first deepwater application of the tool confirms its robustness for production optimization purposes.
- Production and Well Operations > Well Operations and Optimization (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Production and Well Operations > Artificial Lift Systems > Gas lift (1.00)
- (3 more...)
ABSTRACT The current oil price scenario is strengthening the industry's attention towards a more efficient energy usage. This paper shows the energy saving results obtained from field application of an innovative tool for the integrated production optimization of surface facilities based on a genetic algorithm. The objective function of the tool is tailored for each of the described case studies in order to increase field production and reduce energy consumption. The presented tool integrates well performances, gathering system calculation, and process plant simulation in order to optimize the field configuration with a global perspective. Conflicts and interactions between variables, constraints, and operational limitations are balanced and solved holistically by the optimization tool. For each of the field application case studies presented a tailored energy efficiency objective function is defined to optimize production and energy consumption. A powerful evolutionary algorithm searches for the optimum field configuration that represents the best trade-off between efficient usage of energy resources and production maximization. The integrated production optimization tool has been applied on different fields with the aim of simultaneously increasing the energy efficiency of the assets and optimizing production. The benefits of the integrated optimization tool to boost energy efficiency have been proved on an offshore field application. The action suggested from the optimization tool permitted production increase, reducing the global energy losses of the system. A second application is presented, where a significant energy saving has been achieved by the optimized configuration suggested from the tool to recover production after a process upset. All the described applications show a relevant energy saving in terms of primary energy consumption, associated with the increase of field production. This paper describes an innovative approach to increased energy efficiency in oil and gas industry operations. The application of the integrated production optimization tool showed its benefits by improving process and equipment operations and reducing associated operating costs without capital expenditures on energy efficiency.
- Production and Well Operations > Well Operations and Optimization (1.00)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
Production Optimization in Plio-Pleistocene Sequences by Through Tubing Perforations and Sand Consolidation in Rigless Activities: Italian Case Histories
Marotta, M. (Eni-Upstream, DICS Italy ) | Morsetti, C. (Eni-Upstream, DICS Italy ) | Mazzoni, S. (Eni-Upstream, DICS Italy ) | Diaf, R. (Eni-Upstream, DICS Italy ) | Cherri, R. (Eni-Upstream, DICS Italy )
ABSTRACT Complex case histories of rigless activities for Production Optimization, in Eni offshore wells, are presented as pattern of methodology, with low economic impact, to increment production in difficult geological and technical situation. Several offshore gas fields are present in Adriatic Sea (Italy) producing since the 60s, biogenic gas from multilayer metric and submetric sand reservoirs. The production decline in these mature fields is commonly offset by drilling new infilling wells which require time and high associated cost, meanwhile rigless intervention could achieve in very short time important results in production optimization. The identification of rigless intervention needs a good understanding of the field. Detailed field production analysis, well pressure trends, stratigraphic correlations and log analysis and well completion architecture are the main keys to identify target layers never or poorly produced. Furthermore it's fundamental to define if layers target of T.T. perforations are isolated by other productive zones or it is necessary their isolation. Formation Evaluation Cased Hole log, on Pulsed Neutron base, is planned to confirm the residual potential in target layers. The presented case histories show two different applications in Plio-Pleistocene Sequence, in complex well situations. Both wells completed with 2"3/8 dual completion. By geological analysis the interesting layers resulted in intra-packer intervals where a previous productive layer was present. First step in both presented cases was to isolate the existing watered out layers by a water shut-off polymer. Once isolated, the new intervals identified were opened using the through tubing perforation technique using 1"11/16 gun. Afterwards when production history of the wells showed a sand production issue, a chemical sand consolidation job has been performed on the both cases with successful results. These experiences tested the combination of different technologies; it enabled to put in production secondary layers at limited costs.
- Europe (0.89)
- North America > United States > Texas (0.28)
- Phanerozoic > Cenozoic > Quaternary > Pleistocene (1.00)
- Phanerozoic > Cenozoic > Neogene > Pliocene (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.67)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.46)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.68)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well Operations and Optimization (1.00)
Integrated Optimization of Surface Assets With Fluid-Dynamic Check Workflow: A Real Case Application
Di Sarra, A. (Eni S.p.A.) | Ritondale, S. (Eni S.p.A.) | Viadana, G. (Eni S.p.A.) | Scaramellini, S. (Eni S.p.A.) | Frino, I. (Eni S.p.A.) | Pellegrini, S. (Eni S.p.A.) | Bianco, A. (Eni S.p.A.) | Masi, S. (Eni S.p.A.)
Abstract Production optimization is one of the most challenging tasks in the oil & gas industry, due to the high number of processes involved and the continuous update required. To best operate a production asset, a global perspective is needed. The integrated optimization of gathering facilities and process plant represents the way to achieve this complex goal. Integrated simulation models are nowadays able to deal with the presence of several variables, uncertainties, and operational constraints typical of the surface assets. In this article, an integrated tool developed to maximize field production is presented. Powerful genetic algorithms are used to identify the best field configuration, handling many operational variables simultaneously, in order to reach the global optimum in according to the system constraints. In addition, an operative workflow for fluid-dynamic check occurs, in order to avoid the selection of unstable field configurations. As consequence, the best field configuration will be not only the global optimum for the system, but also the most fluid-dynamically stable. Furthermore, multiphase transient code analysis allows understanding actual flow regime and, if necessary, identifying mitigative actions for management's improvement of the investigated asset. The strength of this tool is represented by the possibility to maximize the production of the system and operate the surface assets in a reliable way, evaluating the real application of the solution identified. The integrated workflow has been applied to a real case study, showing the power of the optimization algorithms and the importance of the fluid-dynamic check workflow. This work presents technical improvements for definition of field potential, production optimization, de-bottlenecking activities, asset management.
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics (1.00)
- Production and Well Operations > Well Operations and Optimization (1.00)
- (5 more...)
Integrated Production Optimization in Presence of Uncertainties: The Importance of Risk Analysis for Field Potential Evaluation
Scaramellini, S. (Eni S.p.A.) | Cerri, P. (Eni S.p.A.) | Frino, I. (Eni S.p.A.) | Di Sarra, A. (Eni S.p.A.) | Viadana, G. (Eni S.p.A.) | Pellegrini, S. (Eni S.p.A.) | Bianco, A. (Eni S.p.A.) | Masi, S. (Eni S.p.A.)
Abstract Production optimization is one of the most complex and multi-disciplinary task in the oil & gas industry. The high number of variables involved make the optimization process more challenging, since a global sight of the production asset is required. The optimization process is driven by input data subjected to uncertainties due to physical properties variability, instrument errors, and lack of up-to-date measurements. Neglecting the presence of these uncertainties may lead to an hazardous and unsafe optimized field configuration. For these reasons, the optimization process should be performed through a tool able to manage an integrated production system and its inner uncertainties. A workflow for hydrocarbon production optimization under uncertainties is presented in this article. The workflow is basically structured in three phases. In the first phase, the integrated optimization process with a powerful genetic algorithm takes place. The result is an optimized field configuration characterised by a deterministic production increase in respect to the initial production. In the second phase, after having identified the uncertain input variables, a Monte Carlo simulation for the optimized field configuration is performed. The result is a probabilistic distribution of the production increase. The third step is a detailed analysis of system constraints to evaluate the behaviour of the optimized configuration. The integrated workflow has been applied on a case study. The results obtained has shown the importance to identify and quantify uncertainties in an oil & gas production system in order to obtain a solution characterised by a production increase with a high reliability. The proposed workflow is an important tool to evaluate the field potential under uncertainties, optimize production, improve operations and system reliability, and support the decision-making process.
- Production and Well Operations > Well Operations and Optimization (1.00)
- Facilities Design, Construction and Operation > Processing Systems and Design > Separation and treating (0.73)
- Management > Risk Management and Decision-Making > Decision-making processes (0.70)
- Management > Risk Management and Decision-Making > Risk, uncertainty, and risk assessment (0.51)
ABSTRACT For conventional marine vessels maintenance & repair expenses may be 20% of total operation cost and may be even higher for an offshore plant. Optimising maintenance should result from a trade-off, as excessive maintenance leads to an increasing of the operability costs and machinery down-time, whereas poor maintenance may lead to frequent failures and reduced availability. There are essentially two classical approaches to maintenance: corrective and preventive maintenance. For non-critical parts, corrective maintenance may be the optimal strategy whereas preventive maintenance is safer for critical components. For machines that operated almost continuously at constant settings a fixed time-schedule maintenance plan is usually cost-effective. Such approach is less preferable for systems that are operated discontinuously or for new components. Moreover inspection of a critical part is usually expensive thus maintenance optimisation is rewarding. This leads to the conclusion that a Condition Based Maintenance approach may be the optimal strategy. A CBM approach requires a Condition Monitoring (CM) policy in order to collects all the parameters which identify the health of the component. Condition monitoring techniques have developed rapidly as well the availability of measurements analysis software and broadband satellite communication technology. This open new opportunities for remote online condition monitoring (ROCM) by making available in real-time to the technical offices of the operating company the access to the results of the condition base monitoring system on-board. It also makes it possible to implement a remote maintenance service for critical machineries, especially useful in the case of offshore plants which cannot be easily inspected. Based on the experience gathered by the Authors on practical CBM projects on cruise / naval vessels guidelines for CBM application to offshore drilling ships have been identified.
- Transportation > Marine (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Production and Well Operations > Well Operations and Optimization (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Risers (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- Well Drilling > Drilling Equipment > Offshore drilling units (0.67)
ABSTRACT The Production Optimization is one of the most complex and multi-disciplinary task in the oil & gas industry from an operational point of view: it involves the surface asset during all its production life and requires a continuous improvement process. In the gathering facilities and process plant engineering design, the optimization is driven by inputs that are subjected, during the asset life, to changes; this fact, coupled to improvements and modifications in surface facilities, creates the necessity to manage and optimize production scenarios with amore frequent time-frame. Technology improvements have enabled a widespread use of integrated simulation models for a better asset management to be fully combined with measured field data. In this paper we present a dedicated workflow for surface facilities-gathering system and process plant - production enhancement and management coupled with an advanced optimization technique based on a powerful algorithm. The main feature of this algorithm - and consequently of the proposed workflow - is the ability to control many variables simultaneously according to the system constraints even with complex, conflicting and non-direct interconnections between them and the objective to be reached. It has been proven that this algorithm has a robust practice that detects the global optimum of the feasible area avoiding a premature stop in a local optimum region, a situation quite common in highly-constrained and non-linear optimization problems in oil & gas industry. The technical contributions of the work are the abilities to support operations in: definition of field potential, production optimization and de-bottlenecking activities. In the paper a case study that tackles a more complex situation presented in [1], is reported; the proposed workflow's results are compared with another integrated optimization software available from other software-house, showing an improved ability to detect global optimum combining well management to the plant capabilities.
- Production and Well Operations > Well Operations and Optimization (1.00)
- Facilities Design, Construction and Operation > Processing Systems and Design (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (0.89)