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ESP Cable Deployment has Induced a New Paradigm in UAE to Turn the ESP Business into Rigless Operation, Presenting a Cost Efficient and Faster Application
Guzman, Rodrigo (ADNOC Onshore, Abu Dhabi, UAE) | Hashmi, Zahra Faisal Al (ADNOC Onshore, Abu Dhabi, UAE) | Ilyasov, Ruslan (ADNOC Onshore, Abu Dhabi, UAE) | Sonbaty, Tarek Mohamed El (ADNOC Onshore, Abu Dhabi, UAE) | Gupta, Sanchay (ADNOC Onshore, Abu Dhabi, UAE) | Aguilar, Hector (ADNOC Onshore, Abu Dhabi, UAE) | Martins, Azubuike (ADNOC Onshore, Abu Dhabi, UAE) | Ofodile, Onyebuchi (ADNOC Onshore, Abu Dhabi, UAE) | Cardozo Padron, Jose (Al Dhafra, Abu Dhabi UAE)
Abstract The implementation of the first pilot of the fully rigless ESP deployment in the UAE (United Arab Emirates), has successfully overcome the challenges of well availability and maintainability when using artificial lift systems. The application achieved the production potential of a standard ESP and completely replaced the requirement for a rig during its deployment. This enhanced ESP deployment is shifting the paradigm associated with ESP and rig intervention and is establishing new opportunities for the artificial lift industry. Cable deployment ESP is the only full rig-less technique allowing to complete the deployment in smaller tubing size (2 7/8" and 3 ยฝ") compared to other kind of ESP semi-rigless deployment as coiled tubing and slickline, which are normally limited to a 4.5" production tubing and initial rig interventions. The time and resources required for rig intervention were significantly reduced. This resulted in reducing HSE risks, reducing the and the carbon footprint by more than 50%, compared to standard rig-based ESP operations. With the aim of reducing the number of inactive wells and maximizing return on investment, while also reducing the work-over cost of oil ESP wells, the cable deployment rigless ESP was introduced to eliminate the rig costs associated with the ESP work-over costs - which represent 75-85% of total costs for an onshore ESP completion. Additionally, this approach reduced the failed ESP recovery time from 200 days (mainly waiting to allocate slot in DWS (Drilling and Workover Schedule) to 30 days, which decreased deferred production by 85%. Furthermore, this technology has proved to be an efficient tool to reduce inactive wells percentage, as it can be used as a temporary solution for gas lift wells waiting on availability of surface facilities, which typically could take five years. The payback of rig-less ESP is 15 days, versus payback of 38.6 days for a rig-based solution, it also avoids an average production deferment of 275K oil barrel per well/year and drastically decreases the number of inactive wells, supporting operations teams to sustain production quotas. Based on the trial results, the cable deployed rigless ESP has created business value through the following: Successfully re-activate production in less than 1.5 days. Proven success of rig-less application (installing and pulling activities). Production delivered after 2 hours of deployment (as per ESP design/model). Reduction footprint by 60% (compared rig-based ESP) Stable operation conditions observed and achieved proposed runlife of 360 days compliant with HSE 100%.
One of SEG's great traditions is the special recognition of individuals and organizations for their contributions to geophysics and to the Society.
- Asia > Middle East (1.00)
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- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
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- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Near-well and vertical seismic profiles (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
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In this episode, host Andrew Geary speaks with David Johnston on reservoir monitoring, the featured special section in July's The Leading Edge. This conversation covers a great deal of valuable information in a short time. David shares why reservoir monitoring is the specialization for generalists, the future and value of carbon sequestration, and why he believes there is another Copernican Revolution coming. He also breaks down reservoir monitoring in an easy-to-understand way by relating it to how we control the temperature in our home. If you are considering specializing in reservoir monitoring, want to learn how to work better with other disciplines, or simply want to hear a great preview of July's The Leading Edge, this episode will meet your goals.
Miguel explains how elastic Full Waveform Inversion and the Markov Chain Monte Carlo approach improve seismic inversion, discusses if data analysis and machine learning are essential to practice inversion, and highlights new tools that will improve the accuracy of inversion. This conversation provides great value and insight into the essential work of inversion. Miguel Bosch's expertise is in the field of geophysical inversion with a focus on advanced seismic inversion methods and data integration in complex reservoir models. He has worked on inference problems at different earth scales. In the topic of oil and gas reservoir description, he develops services and technology for the upstream oil and gas industry.
New Paradigm in the Understanding of In Situ Combustion: The Nature of the Fuel and the Important Role of Vapor Phase Combustion
Gutiรฉrrez, Dubert (AnBound Energy Inc.) | Mallory, Don (University of Calgary) | Moore, Gord (University of Calgary) | Mehta, Raj (University of Calgary) | Ursenbach, Matt (University of Calgary) | Bernal, Andrea (AnBound Energy Inc.)
Abstract Historically, the air injection literature has stated that the main fuel for the in situ combustion (ISC) process is the carbon-rich, solid-like residue resulting from distillation, oxidation, and thermal cracking of the residual oil near the combustion front, commonly referred to as "coke". At first glance, that assumption may appear sound, since many combustion tube tests reveal a "coke bank" at the point of termination of the combustion front. However, when one examines both the laboratory results from tests conducted on various oils at reservoir conditions, and historical field data from different sources, the conclusion may be different than what has been assumed. For instance, combustion tube tests performed on light oils rarely display any significant sign of coke deposition, which would make them poor candidates for air injection; nevertheless, they have been some of the most successful ISC projects. It is proposed that the main fuel consumed by the ISC process may not be the solid-like residue, but light hydrocarbon fractions that experience combustion reactions in the gas phase. This vapor fuel forms as a result of oxidative and thermal cracking of the original and oxidized oil fractions. An analysis of different oxidation experiments performed on oil samples ranging from 6.5 to 38.8ยฐAPI, at reservoir pressures, indicates that this behavior is consistent across this wide density spectrum, even in the absence of coke. While coke will form as a result of the low temperature oxidation of heavy oil fractions, and while thermal cracking of those fractions on the pathway to coke may produce vapor components which may themselves burn, the coke itself is not likely the main fuel for the process, particularly for lighter oils. This paper presents a new theory regarding the nature and formation of the main fuel utilized by the ISC process. It discusses the fundamental concepts associated with the proposed theory, and it summarizes the experimental laboratory evidence and the field evidence which support the concept. This new theory does still share much common ground with the current understanding of the ISC process, but with a twist. The new insights result from the analysis of laboratory tests performed on lighter oils at reservoir pressures; data which was not available at the time that the original ISC concepts were developed. This material suggests a complete change to one of the most important paradigms related to the ISC process, which is the nature and source of the fuel. This affects the way we understand the process, but provides a unified and consistent theory, which is important for the modelling efforts and overall development of a technology that has the potential to unlock many reserves from conventional and unconventional reservoirs.
- North America > United States (1.00)
- Europe (1.00)
- North America > Canada > Alberta (0.94)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.90)
- Geology > Geological Subdiscipline (0.67)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.94)
- North America > United States > Nebraska > Sloss Field (0.99)
- North America > Canada > Alberta > Athabasca Oil Sands > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- North America > United States > South Dakota > Williston Basin > Buffalo Field > Red River Formation (0.94)
- North America > United States > North Dakota > Medicine Pole Hills Field (0.94)
Cable Thru Downhole Insert Safety Valve: A New Paradigm
Kuswanto, Kuswanto (PETRONAS) | Fabian, Oka (PETRONAS) | B Samuel, Orient (PETRONAS) | B Yaakub, Mohd Yuzmanizeil (PETRONAS) | Hing Leong, Chua (PETRONAS) | Yin Ho, Yap (PETRONAS) | Abdul Rahim, Muhammad Fadzli (BAKER HUGHES) | Zhafrael, Rafael (BAKER HUGHES)
Abstract The B Field is located in the South China Sea, about 45 KM offshore Sarawak, Malaysia, in a water depth approximately 230 ft. Its structure is generally regarded as a gentle rollover anticline with collapsed crest resulting from growth faulting. The reservoirs were deposited in a coastal to shallow marine with some channels observed. Multiple stacked reservoirs consist of a series of very thick stacked alternating sandstone and minor shale layers with differing reservoir properties. The shallow zones are unconsolidated, and the wells were completed with internal gravel packs. Wells in B Field mostly were completed in multi-layered reservoirs as dual strings with SSDs and meant to produce as a commingled production. The well BX is located within B Field and designed as oil producer well with a conventional tubing jointedElectrical Submersible Pump (ESP) system which was installed back in 2008. Refer to figure 1, the initial completion schematic is 3-1/2โณ single string that consist of the single production packer, gas lift mandrel, tubing retrievable Surface Controlled Subsurface Safety Valve (SCSSV) and ESP. The production packers equipped with the feed thru design to accommodate the ESP cable and the gas vent valve as part of the ESP completion design. The gas lift mandrel was installed in the completion string as a backup artificial lift method to receive the gas lift and orifice valve in the event of the conventional ESP failed. Hence the well still able to produce by introducing the gas thru the annulus to activate the gas lift valve. Eventually throughout the end of the the field life, the well would depend on the ESP system for the primary lifting method due to gas lift depth limitation and the gas supply. The conventional ESP failed after seven years of operation which is above the average ESP lifetime. The well last produced at a flow rate with 28 % water cut, however the well is not at the end of the field life. Based on the economical study with the right technology and cost efficient approach, the well still economicaly profitable. The Thru Tubing (TT) ESP technology is approached as cost effective solution compare to fully well workover. Despite a couple of operational challenges, for example, setting the cable hanger, maintaining downhole barrier requirement, the Thru Tubing Electrical Submersible Pump Cable Deployed (TTESP CD) and Cable Thru Insert Safety Valve (CT-ISV) was successfully installed. Several post-installation findings have uncovered some problems which are requiring some additional technical and operation improvement for future similar applications. This paper will highlight the deployment of the Cable Thru Insert Safety Valve (CT-ISV) that was successfully installed as pilot, which is the first application in the world, and also highlights the success, lesson learnt and improvement for future requirement for the CT-ISV application as one of the solution for retrofitting completion application without jeopardizing the well integrity. This achievement is collaboration between Company and service partner as the technology and deployment under the proprietary scope. Further technology application, the replication of this insert safety valve was conducted and successfully deployed on other three wells.
- Geology > Structural Geology (0.54)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.54)
The article discusses a new paradigm for the development of the oil and gas complex of Russia, proposed by Academician of the Russian Academy of Sciences A.E. Kontorovich in 2020. It was noted that the oil industry is currently facing a number of serious difficulties, such as the depletion of fields, a decrease in the number of discoveries of new fields, ineffective production methods due to the lack of modern innovative technologies, imperfect legislation, licensing of large state-owned enterprises, insufficient proven reserves; and lack of funding. It is shown that there will still be periods of destabilization of the oil market (crises) in the world, and in such conditions a more thought-out policy of Russia in matters of oil and gas production is needed. In this regard, the proposals of A.E. Kontorovich on the need to change the current development paradigm, which consisted in the consistent development of new oil and gas provinces, moving from west to east. When discussing the new paradigm, we used the experience of the successful oil development in the oldest Russian oil ang gas bearing region - the Republic of Tatarstan. Over the long history of the development of the oil industry in the republic, a vast experience has been accumulated in the exploration and development of oil fields โ from small and smallest to giant and supergiant. Approaches for the rational development of various groups and categories of deposits have been found. The most effective methods of prospecting, exploration and additional exploration of oil fields, the most advanced hydrodynamic methods for the development of fields with active and hard-to-recover reserves, including at the late stages of development, have been developed, methods of enhanced oil recovery for various geological and physical conditions have been widely used, including the extraction of residual reserves of long-term exploited deposits. Extensive experience has been accumulated in the development of complex small fields with hard-to-recover oil reserves. It is concluded that the proposed by A.E. Kontorovich, a new paradigm for the development of the oil and gas complex of Russia touches upon topical problems of the industry, requires additional analysis and further development.
Application of Stratigraphic Forward Modelling to Carbonate Reservoir Characterization โ A New Paradigm from the Albion R&D Project
Borgomano, Jean (Aix-Marseille University) | Massonnat, Gรฉrard (TOTAL-EP) | Lanteaume, Cyprien (TOTAL-EP) | Danquigny, Charles (TOTAL-EP) | Samson, Philippe (TOTAL-EP) | Rolando, Jean-Paul (TOTAL-EP) | Rebelle, Michel (TOTAL-EP)
Abstract Improving carbonate reservoir prediction, field development and production forecasts, especially in zones lacking data, requires novel reservoir modelling approaches including process-based methods. Classical geostatistic modelling methods alone cannot match this challenge, in particular if subtle stratigraphic architectures or sedimentary and diagenetic geometries, not directly identified as properties with well data, control the reservoir heterogeneity. Stratigraphic forward modelling approaches can provide pertinent information to carbonate reservoir characterization. Integrating carbonate stratigraphic forward models in reservoir modelling workflows faces two sets of challenges: (1) the difficulty to establish high resolution and multi-scales continuous reservoir analogues from outcrops and (2) the development of forward modelling methods adapted to carbonate heterogeneity and calibrated to well data. The ALBION R&D Project dedicated to the Lower Cretaceous rudist-rich carbonate platform meets these two considerable scientific challenges. This workflow builds on previous modelling approaches at basin scale that integrates seismic inversion and forward modelling. This project delivers deterministic high-resolution static models that support the development of process-based modelling solutions. This multidisciplinary approach focuses on the characterization of primary sedimentary and diagenetic overprint that can impact drastically the flow behavior at inter-well scales in similar reservoir units such as the Kharaib and Shuaiba Formations. The SED-RES modelling package developed in house by Total R&D has been tested and calibrated with these high-resolution stratigraphic outcrop models. It allows valid prediction of carbonate facies associations mimicking the spatial distribution mapped along the Urgonian platform transects.
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (1.00)
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Asia > Thailand > Kamphaeng Phet > Block L10/43 > Sirikit Field (0.99)
- Asia > Middle East > Saudi Arabia > Thamama Group > Shu'aiba Formation (0.94)
- Asia > Middle East > Saudi Arabia > Thamama Group > Kharaib Formation (0.94)
Abstract Harvesting vast amounts of data has long been identified as an enabler of operational performance. The measurement of key performance indicators is a routine practice in well construction, but a systematic way of statistically analyzing performance against a large data bank of offset wells is not a common practice. The performance of statistical analysis in real time is even more rare. With the introduction of edge computing, devices capable of complex analytical functions in physical proximity to sensors and operations, this practice can be realized. Two case studies are presented: rate of penetration (ROP) and amount of vibration per run. Hypothesis testing is a statistical method in which a sampled dataset is compared against an idealized or status quo model. This model is built using many samples from a population. The characteristics of the population are then inferred from these samples. The model is built in centers where large amounts of data are available. These models are then transferred to an edge device in the field. The device collects real-time data and compares results to the status quo model. In the two cases presented, hypothesis testing was used to determine maximum and minimum levels of ROP and downhole vibration. This information is used to determine the effectiveness of new drilling practices, technologies, or methodologies. Because calculations are performed in real time, changes to drilling practices can be adopted quickly. The ROP case was performed at a US operating unit; the vibration case was performed in a Middle East unit. The models showed what improvement values should be. It was revealing to find wells that were thought to be poor performers were actually well within the population normal. Wells were also found that were thought to be good performers, but where new drilling methods were used, actually fell within the population model and thus suggested that the new methods had not affected performance. By performing this analysis on the edge device, operations can make changes early in such a way that results fall outside the status quo model and deliver real performance improvements. The paper presents the novel use of statistical models calculated in data centers in conjunction with real-time operations. Similar approaches in technical and physics modeling exist in which models are produced in the office and used in the field. However, building models for operations management, from a large bank of offset data, and performing analysis in the field with real-time data is a not common practice. This paper shows both technology and statistical methods that provide a valid scientific framework for operational performance improvement.
- Research Report > Experimental Study (1.00)
- Overview > Innovation (0.89)
- Research Report > New Finding (0.68)
Cashe - Change Agents for Safety, Health and Workplace Environment: A New Paradigm of HSE Management
Gupta, Dhaval (Reliance Industries) | Paliwal, Aditya (Reliance Industries) | Jain, Himanshu (Reliance Industries) | Gupta, Vinay Kumar (Oil & Natural Gases) | Goyal, Atin (Reliance Industries) | Kumar, Sujeet (Reliance Industries) | Bose, Soham (Reliance Industries)
Abstract The Reliance Group is India's largest private sector enterprise with business in energy & materials value chain. With over 24,000 employees & 100,000+ contract workers, RIL believes that a healthy employee and a healthy workplace is the strongest pillar for sustainable growth of any organisation. The management believes that driving and sustaining behavioural changes; by adopting best health practises at workplace, create sense of ownership & bring hazard free environment. To inculcate best practises in field of occupational health and safety, an innovative idea was introduced known as CASHe-Change Agents for Safety, Health and Workplace Environment .This innovative project with pro active preventive approach comprising team work of medical, safety, environment & technical professionals have established a landmark in field of occupational health resulting in hazard free environment and a positive change in work attitude of employees and contract workers from grass root to top level. CASHe projects have lead to manufacturing divisions consuming 0.48 million GJ of renewable energy (wind and biomass), recycled material use of 63,220 tonnes, recycled water as a percentage of total water consumed to be 55.05%. There has been 2.5% increase in renewable energy consumption, 3.1% reduction of direct GHG emission, 4.5% reduction of air emission (NOx), 4.1% increase in materials recycled, 11.7% reduction of air emission (SOx) (all compared to yr 2014-15), creating a milestone in the year 2015-16.CASHe has made employees realise that they are not just "employees" but doctors of change. It has set a benchmark for HSE management system, its time this model is used across companies to leverage their safety standards, enhance efficiency & make workplace hazard free. This paper studies how CASHe came into existence, its purpose, its implementation and results in 13 sites of Reliance Industries with emphasis of innovative projects that lead to its success.
- Health & Medicine (1.00)
- Energy > Oil & Gas > Downstream (0.39)
- Health, Safety, Environment & Sustainability > HSSE & Social Responsibility Management (1.00)
- Health, Safety, Environment & Sustainability > Health > Noise, chemicals, and other workplace hazards (0.92)
- Health, Safety, Environment & Sustainability > Environment > Air emissions (0.91)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (0.76)