Workplace violence (WPV) against healthcare providers is a serious problem that carries health, safety, and legal consequences. Healthcare providers working in emergency departments (ED) are more susceptible to WPV compared to other healthcare settings. This study aimed to assess the prevalence of physical and verbal violence against ED physicians and nurses in public hospitals in Amman, Jordan, and to explore the relationship between WPV and the socio-demographic characteristics of the participants. A quantitative descriptive cross-sectional study design was used to assess physical and verbal violence against ED physicians and nurses. A self-administered questionnaire was completed by 67 physicians and 96 nurses from three public hospitals in Amman. In the past year, 33% and 53% of the participants experienced physical and verbal violence, respectively. Compared to their female counterparts, males were more frequently physically (43.7% vs. 2.3%, p-value < 0.001) and verbally (61.3% vs. 29.5%, p-value < 0.001) abused. The main perpetrators of physical and verbal violence were the patients’ relatives. Out of 53 physical and 86 verbal abuse incidents, only 15 cases (10.8%) were followed up with legal persecution. In conclusion, there is a widespread occurrence of physical and verbal violence against ED physicians and nurses in the public sector hospitals in Jordan. A collaborative effort by all stakeholders should be instituted to ensure the safety of the physicians and nurses and to improve the quality of the healthcare provided.
The Extended Reach Drilling (ERD) field re-development of a giant offshore field in United Arab Emirates (UAE) from four artificial islands predominantly requires the use of artificial lift (gas lift) to assist in unloading the wells post-completion operations and enhance reservoir production recovery rates. The vision was to achieve a well completion that allows for intervention-less unloading via gas lift using shearable Gas Lift Valves (GLV) and Remote Actuated Barrier Devices (RABD). The key principals in developing a solution to achieve this vision were to reduce rig time by avoiding critical path unloading, minimize post-rig activity to install live gas lift valves, and eliminate HSE exposures. Historically producer wells were completed with dummy gas lift valves and a frangible barrier device to facilitate the required completion pressure testing and provide barriers for rigging down from well. Coil Tubing (CT) was used to break the barrier device and kick off the wells with nitrogen. Once gas lift is available, the wells would be shut in, and a series of wireline interventions carried out to replace the dummy valves with live GLVs. This time consuming and costly process increases in cost when subsequent rig location covers the well that needs intervention; critical path rig time has been needed to unload wells with CT, in some cases requiring up to seven (7) rig days. This resulted in increased construction cost of each well and additional HSE exposure associated with the rig-less interventions required. A method was developed to deploy the upper completion with live, barrier qualified Tubing Pressure Shearable GLV’s (TSGLV) and a RABD, which enables all necessary well-construction integrity tests to be performed, and subsequently convert to a production configuration to allow unloading, gas lift and production of wells. Post-completion, well unloading and gas lift is immediately available without incurring critical path rig time or rig-less interventions. In this paper, the authors will demonstrate the technology that was developed, the qualification and testing program that was implemented, and final solution that enabled the Company to deliver wells successfully with remotely actuated unloading and production without the need for intervention.
This development, predominantly from four artificial islands, of a giant offshore field in the United Arab Emirates (UAE) requires Extended Reach Drilling (ERD) well design including extended length liners in order to reach drilling and geological targets of the field and Maximum Reservoir Contact (MRC) well design that can drastically decrease development costs. Despite drilling challenges during well construction process such as losses in UER, shallow aquifer flows in Simsima, key seating issues in the base of Simsima, wellbore instability in Laffan and Nahr Umr shale, losses in Salabikh and etc. the team has managed to deliver the longest well to date in UAE to a depth of 35,800 feet and has set many ZADCO internal records for drilling performance with no HSE events. Through the use of enabling best practices, lessons learnt and new technologies such as Casing Swivel, Fixed-Bonded non-rotating centralizers and 21 days swell packers, the well was drilled and completed 11.3 days under Authorization for Expenditure (AFE). Several major milestones and records were achieved such as record drilling performance (spud to TD), longest 8 ½" hole section (18,800 feet) with one Bit and Bottom Hole Assembly (BHA), 16" surface hole inclination of 56°, deepest set 9 ⅝" casing to 17,000 feet MD, longest single stage 6 ⅝" liner in the world (total length of 19,004 feet at the time). All well objectives have been achieved. Several technologies were deployed to enable the abovementioned records including the use of Fixed-Bonded non-rotating centralizers in tandem with sacrificial casing swivel.
The long term development from four artificial islands of this giant offshore field in the United Arab Emirates (UAE) is requiring longer and longer ERD wells. This can only be achieved by drilling higher angle, higher departure and increasing lateral lengths. Horizontal departure ratios have increased from 2:1 to 3:1 and will, before the development has finished approach 4:1. Maximum Reservoir Contact (MRC) lateral lengths at the beginning of the development were planned to average 10,000ft but are already being lengthened to 20,000ft, and beyond. This paper describes the many challenges that have arisen and have been successfully overcome to enable deployment of 6 5/8" horizontal lower completions of lengths up to 20,000ft into wells that are greater than 30,000ft MD. These challenges have been surmounted through the use of proprietary in-house software, leveraging partner resources and global experience, close collaboration between drilling, completion and field development teams, new technology equipment development and deployment methodologies. Several case histories will be presented and discussed at length in this paper. These will focus on specific aspects for each of the wells such as the; high strength liner connections, high load liner running tools, reservoir drilling fluid composition, swellpacker design, use of drillpipe or casing swivels, centraliser type and the effect of dog leg severity in the long reservoir lateral.
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