This paper describes an efficient approach to evaluate the water supply-to-injection cluster facilities capacity and also to define the required upgrades and areas of optimization.The supergiant filed understudy is located in Abu Dhabi and is producing for decades from multilayered carbonate reservoirs. The field is under peripheral water injection to maintain reservoir pressure and also to enhance the oil recovery.Total of 53 water injection clusters have been commissioned in the field to support water injection operation for reservoir management purpose. The water clusters consists of producing wells from water bearing formations and multiple injection wells completed in different reservoirs. Frequent down time in the water supply wells and existing bottle necks in the water supply to injection system has led Abu Dhabi Company for Onshore Operation to evaluate the clusters looping option to enhance the water injection capacity of the field and optimal re-distribution of the water through the clusters.By this strategy, the high capacity water supply wells will be able to feed the candidate clusters required extra water or the clusters with the closed water supply well under maintenance.To achieve this strategy, a fully integrated water supply to water injection system was built using a commercial fluid flow simulator. The integrated model consists of water supply well equipped with ESP, water injection facilities network with surface pumps, strainers and choke manifolds as well as injection wells. The system was validated against most reliable measured data at a snap shot of time.The full integrated water supply to injection model was used to evaluate the opportunities to loop the high capacity clusters to high demanding clusters, identify the bottlenecks in the system and also to determine the various options in the clusters facilities to enhance the water injection capacity of the field.
There are 26 sedimentary basins in India divided into four categories on the basis of hydrocarbon prospectivity. A total of about 3.14 million square kilometres area is covered by these sedimentary basins which includes both onshore and offshore. One of the most prominent category-1 (commercially producing) basin of India is Krishna Godavari basin with an estimated hydrocarbon potential of about 1130 million metric tonnes. It is is formed by the extensive deltaic plain formed by the two large east coast rivers, Krishna and Godavari. It covers an area of 15000 square kilometres onshore and about 25000 square kilometrs offshore, upto a water depth of about 1000m (National Data Repository, DGH-MoPNG, GOI). It is believed that India relies heavily on KG basin for its energy security. However, one of the major challenges being faced in the KG basin offshore field development is Flow Assurance. Since most of the fields offshore KG basin are in deepwater setting, high pressure and low temperature conditions aggravate flow assurance problems. Flow assurance is identified as a significant deepwater offshore development challenges and hence has emerged as a prominent discipline in the oil and gas industry. There are several definitions of Flow Assurance, one of the most common of which is: Flow Assurance is the analysis of thermal, hydraulic and fluid related threats to flow and product quality and their mitigation using equipment, chemicals and procedure (Makogon T.Y., 2019). It can be understood as an all-encompassing holistic approach of fluid flow from the reservoir to point of sale with an integrated perspective of asset development. In simple terms flow assurance aims to ensure fluid flow irrespective of flow trajectory, fluid chemistry and environmental conditions (Brown L.D., 2002). It has become increasingly important in recent times as the industry has turned to deepwater resources for energy sources. There are multiple examples where the proper utilization of Flow Assurance technology has saved billions of dollars for oil and gas companies. Norske Shell saved approximately 30 billion NOK in the Troll field by resorting to direct electrical heating of produced fluids. The same was utilized by Italian company ENI for its Goliath development and by BP in its Skarv field (Makogon T.Y., 2019). This paper describes a comprehensive workflow to identify and mitigate flow assurance risks for the deepwater block in KG basin.
BACKGROUND Cardiac conduction disorders and electrocardiographic (ECG) changes may occur as a manifestation of coronavirus disease 2019 (COVID-19), especially in severe cases. AIM To describe conduction system disorders and their association with other electrocardiographic parameters in patients who died of COVID-19. METHODS In this cross-sectional study, electrocardiographic and clinical data of 432 patients who expired from COVID-19 between August 1 st , 2021, and December 1 st , 2021, in a tertiary hospital were reviewed. RESULTS Among 432 patients who died from COVID-19, atrioventricular block (AVB) was found in 40 (9.3%). Among these 40 patients, 28 (6.5%) suffered from 1st degree AVB, and 12 (2.8%) suffered from complete heart block (CHB). Changes in ST-T wave, compatible with myocardial infarction or localized myocarditis, appeared in 189 (59.0%). Findings compatible with myocardial injury, such as fragmented QRS and prolonged QTc, were found in 91 patients (21.1%) and 28 patients (6.5%), respectively. In patients who died of COVID-19, conduction disorder was unrelated to any underlying medical condition. Fragmented QRS, axis deviation, and ST-T changes were significantly related to conduction system disorder in patients who died of COVID-19 ( P value < 0.05). CONCLUSION Conduction system disorders are associated with several other ECG abnormalities, especially those indicative of myocardial ischemia or inflammation. Most patients (73.14%) who died of COVID-19 demonstrated at least one ECG abnormality parameter. Since a COVID-19 patient's ECG gives important information regarding their cardiac health, our findings can help develop a risk stratification method for at-risk COVID-19 patients in future studies.
S Field field started enhancement planning and redevelopment recently by using an innovation EOR program called GASWAG, Gravity Assisted Simultaneous Water and Gas, in the selective oil-bearing sands. The initial program includes 6 infill producers, 2 water injectors, 3 gas injector wells and approximately 15 potential well reactivations to increase recovery by 7%. Since GASWAG is a new program in this region, it requires well and reservoir monitoring system to be implemented to have better understanding of complex behavior of water and gas injection and its effect on EOR performance. The main objective of the EOR Integrated Operation (IO) workflows solution, is to determine as quickly as possible if EOR performance is deviating from plan. This will be accomplished by earlier detection of EOR performance exceptions (compared to process without IO functionality), so that corrective action cycle time can be reduced, thereby reducing production deferment. Well Surveillance & Operational: a workflow to monitor, analyse and manage EOR wells production/ injection performance using real-time and in-time data together with updated well model. This Workflow focus on well and zones monitoring by using the well model and existing measurement. In addition, the existing IO workflows are integrated with EOR-Operational and feeding online data to this WF which is consistent with operational safety limit and KPOs. All operational data required for reservoir and production engineering were extracted either from well model, measurement or other workflows to the same well interface. Additionally, production and injection well surveillance and alarming system is implemented to benchmark the current operational condition deviated from plan or operational limit. Updated dynamic model and optimizer tool are used to define the optimum choke size of each reservoir layer for injecting or producing wells. This workflow was built and implemented successfully. It is designed based on very comprehensive technical aspects and KPIs from reservoir management, production engineering, facility constraint, well integrity to operational optimization. A single interactive visualization interface via web-based is implemented which cover all necessary production and reservoir data needed for collaborative decision making. The EOR well surveillance IO workflows will assist in automating computation of injection and production well health and performance. This solution benefits the asset team by allowing early detection of underperforming injection and production wells. Main challenges in S Field was, it is divided by several jackets thus require movement via vessel for manual data gathering. Unpredictable and adverse weather heavily challenge this activity. By having IO would help to improve data hygiene and collective data on daily monitoring. Additional functionality of the well surveillance workflow includes the monitoring of zonal rate and pressure, which are considered as main reservoir performance parameters. Operations, production, and reservoir engineers, as well as technical & business owners benefit from these workflows to steer the EOR operation.
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