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Trichinellosis is a serious zoonotic parasitic and globally endemic disease. Benzimidazole derivativesare apparently unable to kill encapsulated larvae and its effectiveness depends on solubility, dosage oftherapy, host biotransformation, selectivity patterns as well as onset of treatment after infection. Excretory-secretory (ES) proteins released by Trichinella induce a strong immune response when tested as avaccine. The current study investigated both therapeutic and protective effects of adult worm excretorysecretory protein (AW/ES), or larval excretory secretory protein (LES) on T. spiralis infected mice,conducted by parasitological, histopathological, immunohistochemical, serological and molecular investigations.Larval excretory secretory protein achieved more significant therapeutic and protectiveeffects than adult worm excretory secretory protein in experimentally infected mice, causing reductionin larval counts and decrease in pathological changes of both muscular and intestinal tissues. It increasedserum IgG OD values, decreased Foxp3 expressions and increased the mean cycle thres- holdvalues of muscular tissues but it had lesser effects on adult worm counts than albendazole.

This paper is based on the analysis of miscible WAG for an onshore Middle-East field, with strongly undersaturated light oil. Water Alternate Gas operations have been ongoing for around 5 years, which is relatively recent compared to more than 40 years of production history. Goal of this work was to assess the efficiency of this miscible hydrocarbon WAG and to optimize it on the different compartments, with respect to miscibility, voidage replacement, and recycling.As this is a large mature field, with WAG operations dispatched on around 50 injectors and 9 fault blocks (compartments), the method of analysis had to be robust with respect to the different injection strategies followed in the past. It was essentially based on injection and production data, but also used pressure data when available. We computed the following dimensionless variables: oil recovery factor, BSW, voidage replacement ratio (VRR), and also WAG ratio and gas recycling ratio (GRR). Their evolution versus time was analyzed and compared between fault blocks.Using dimensionless variables allowed to compare fault blocks with different initial volumes in place, and to illustrate trends versus time. It was also found beneficial to lump some compartments, when communication was substantiated by pressure data. On the production side, we used the conventional BSW and GOR variables to quantify the water and gas recycling ratio. On the injection side, we observed that in some compartments, the historical WAG ratio was too low in the oil zone, which could be quantified by excluding the peripheral water injection volumes.The analysis allowed also to estimate the gas utilization factor and efficiency, which confirmed the overall high efficiency of miscible gas injection in 3-phase mode. It was also found that the injected fluid efficiency correlated with geology: gas injection tends to be more efficient in zones with high permeabilities at the bottom (coarsening downwards), while water injection is better adapted to zones with high permeabilities at the top (coarsening upwards). Estimating these water and gas efficiencies also allowed to optimize the injection strategy on a field level, by comparing the water efficiency with other units of the field only under waterflood.

The dual completion technique is considered very attractive by major oil companies as it offers significant CAPEX saving while maximizing oil recovery. Even though the first dual completion installation was in the 1960s, applications have been limited since it requires especial completion equipment, complicated run in/out hole procedures and challenging artificial lift implementation. Dual completions are also complicated by a lack of production control equipment. All these factors constrain the deployment of this potentially profitable completion technique worldwide. API 19G9 advises that dual-string gas lift is problematic and often ineffective. It is difficult, or even impossible to effectively producing both completed zones in a dual-string gas-lifted well, due to the complexity of controlling gas injection using conventional pressure operated valves. The string dedicated to the formation with the lowest productivity and reservoir pressure tends to divert the gas from the other string. Additionally, fluctuating casing pressure, unpredictable temperature gradients due to the proximity of the two strings, and inability to individually controlling the injection rates to each string makes simultaneous production optimization of these wells extremely complex. The majority of ADNOC Onshore dual completion wells are equipped with gas lift mandrels in only one of the strings, limiting the production from the naturally flowing string when water breaks through. Few wells in ADNOC Onshore have both stings on Gas lift. For these that do, the optimization of the amount of gas required for each zone is difficult and requires multiple wireline operation to change orifice sizes, causing increased operational risks. To overcome the production and operations constrains of existing gas lift practice in dual completion wells; the authors developed a dual string well design employing digitally controlled integrated gas lift valves. This design enables the adjustment of the gas lift injection rates for each of the strings without the need of rig-less intervention. Furthermore, the desing allows the simultaneous recording of downhole temperature and pressure at gas injection depth in each producing string. This paper describes the technical and economic evaluation of the pilot implementation of DIAL technology in dual completions across ADNOC Onshore, covering the candidate selection criteria, integrated evaluation of the well performance & surface debottlenecking scenarios, completion design considerations, best practice Installation and data integration system that ensure achieving a set of success criteria and targeting additional 20% extra production per well. This Worldwide first implementation of digital gas lift production optimization system in a dual string well, will be a game changer in the industry, enabling efficient production and enhanced recovery from both reservoirs within the same well. If successful, it is expected to achieve an additional production gain while reducing 30 % of the gas consumption.

The use of capacitor banks is considered as the best-known technique for minimizing the line losses in various distribution networks. Therefore, the appropriate allocations and sizes of capacitors are very important because they affect the reduction of system losses and improvement of the system voltage profile. In this article, a novel algorithm called the moth swarm algorithm (MSA) is developed to optimally determine the locations and sizes for installing capacitor banks in various radial distribution systems (RDN). The objective function is adapted to reduce the system power losses and to reduce total system cost. Consequently, an increase in the annual net saving with inequity constraints on capacitor size and voltage limits considering multi-loading levels is obtained. The validation of the proposed algorithm has been tested and verified through small, medium and large scales of standard RDN of IEEE (22, 69, 85-bus) systems and also on ring main 33-bus system. In addition, the obtained results are compared with other algorithms to highlight the advantages of the proposed approach. Numerical results stated that the MSA can achieve optimal solutions for losses reduction and capacitor locations with the finest performance compared with many existing algorithms.