Anti – Microbial effect of three essential oils in treating Upper respiratory tract Infection via vapours generated by Pressurized steam chamber (PSC)

Disinfection tunnel (DT) or sanitization tunnel used for disinfecting the persons by spraying with appropriately atomized virucide spray, Direct inhalation or spraying of disinfectants on people with chemical element and different toxicant chemicals may lead to eye and skin irritation and cause numerous allergic disorders. So this obstacle was overcome by Ideal flow control private limited by designing the Pressurized Steam Chamber (PSC) in which Natural oils was mixed in an emulsifier solution, and induced along with steam through multiple nozzles within the chamber, so that persons could get disinfected the entire body. Anti-microbial efficacy of our three essentials oils were determined by standard method, ISO 4833-1:2013 by collecting sample through walk in/walk out chamber protocol. Our present study report of MSME (ministry of micro, small and medium enterprises) and SGS Chennai, reveals that in phytotherapeutic oils initial microbial load are found to be <1 CFU / mL, in emulsifier and in formulation (water + emulsifier + natural oils) the presence of bacterial colonies found to be 470000 CFU / mL and 20000000 CFU / mL whereas, the distillate collected from essential oils at 65̊ c shows the absence of microbial load. Further swab analysis report of 8 individuals states that samples (hand swab and surface swab) collected for the estimation of Total plate Count showed that there is a reduction in microbial load when exposed to the Steam generated by Pressurized Steam Chamber (PSC) at both the time intervals, 20 and 40 seconds. These findings confirm that three essential phytotherapeutic oils combined with steam have some potent activity against emerging disease.

Application of Time Lapse 3D/4D Seismic in the Monitoring of Steam Conformance and Cap Rock Integrity of Heavy Oil Thermal Production Project in North Kuwait

The challenge of Heavy oil thermal production Kuwait includes how to monitor steam flood effectiveness and cap rock integrity. Due to shallow & heterogeneous reservoirs and thin cap rock, pressurized and heated steam could diffuse in all directions and breach the cap rock. KOC acquired a baseline & time-lapsed surface seismic and 3D VSP for purposes of monitoring CSS production. This paper presents a technical application of seismic inversion to steam chamber size & cap rock integrity interpretation. The seismic image area includes 13 CSS wells, at varying CSS stages of steam injection, soaking and production. The data acquisition consisted of a base and a time-lapsed monitor seismic; each acquisition period lasting for around a week and separated by 40 day intervals. The simultaneous acquisition of surface seismic and the 3D VSP enabled complimentary data exchange and results validation. Well data of sonic and PHIT are used for building a low frequency inversion model. Rock physical modeling is also required to understand the effect of steam and production changes on acoustic and elastic properties. Various geophysical inversion methods are performed on AI inversion of post & pre stack seismic and Poisson's ratio inversion. To estimate reservoir temperature changes due to steam injection, the calibrated rock-physics model was utilized to relate the AI response to temperature change. The steam injection is expected to decrease acoustic impedance. The AI difference exhibits much wider impedance anomalies revealing steam chamber size and the production zone around the wells at various stages of the CSS cycle. Average temperature maps in reservoirs derived from rock-physical modeling also show temperature change around the wells. Inverted seismic attributes of acoustic impedance and temperature were used for study of cap rock integrity. Interpretation results of the steam size through AI and temperature analysis at reservoir and cap rock enable optimization of our CSS and SF completion strategies include steam pressure and volume, soaking period and thermal production control. The result of cap rock integrity monitoring also indicate no serious damage of cap rock under existing conditions of CSS operation (WHT: 420 °F & WHP: 320 PSI), which defines the limits of strategies to increase steam pressure and volume to increase EOR efficiency.

Time-Lapse Pulsed Neutron Well Logging in Oil Sands for Monitoring Steam Chamber Development

Steam-assisted gravity drainage (SAGD) technology, although a relatively new oil recovery method, has already proved its value in economic development of heavy-oil sands in Western Canada. The SAGD process requires a lifetime monitoring of steam chamber growth to optimize reservoir development, improve oil recovery, and minimize environmental impact. Operators have widely used pulsed neutron well logs to monitor their life cycles of oil sand reservoirs. Time-lapse pulsed neutron logs acquired in observation wells enable operators to effectively track the growth of the steam chamber and identify the changes of formation fluid saturations. We present high-temperature pulsed neutron logging technology and an algorithm to quantify steam, heavy oil and water saturations in SAGD wells. One of the major challenges in well logging operation is to withstand the thermal shock from the steam chamber. Reservoir temperature often varies abruptly, by as much as 250 degrees C in a very short interval, so the logging tool must be stable in drastic temperature variations. Well logging conditions such as a steam-filled wellbore, extra completion hardware and bad cement quality are challenging factors as well. Furthermore, formation fluid saturation analysis in Canadian oil sands is typically complex because the formation water salinity is relatively fresh but varies, clay properties are not homogeneous, and SAGD operations create conditions in which three-phase fluids coexist in the formation. These environmental conditions make it difficult to rely only on commonly used thermal neutron capture cross-section measurements (formation sigma). In this paper, case study examples present the above-mentioned challenges and solutions to identify the multi-component formation fluids. The multi-detector pulsed neutron well logging instrument has been modified with a custom-designed heat flask to handle the extreme temperature variations in the SAGD environment. This heat-flask equipped instrument ensures a stable data acquisition in the presence of rapid and extreme temperature variation and enables a prolonged and time-efficient operation through effective heat management. For saturation analysis, we demonstrate an advanced algorithm to quantify three fluid components using a combination of gamma ray ratio and carbon/oxygen (C/O) measurements.

Breccia interlayer effects on steam-assisted gravity drainage performance: experimental and numerical study

Currently, the reservoir heterogeneity is a serious challenge for developing oil sands with SAGD method. Nexen’s Long Lake SAGD project reported that breccia interlayer was widely distributed in lower and middle part of reservoir, impeding the steam chamber expansion and heated oil drainage. In this paper, two physical experiments were conducted to study the impact of breccia interlayer on development of steam chamber and production performance. Then, a laboratory scale numerical simulation model was established and a history match was conducted based on the 3D experimental results. Finally, the sensitivity analysis of thickness and permeability of breccia layer was performed. The influence mechanism of breccia layer on SAGD performance was analyzed by comparing the temperature profile of steam chamber and production dynamics. The experimental results indicate that the existence of breccia interlayer causes a thinner steam chamber profile and longer time to reach the peak oil rate. And, the ultimate oil recovery reduced 15.8% due to much oil stuck in breccia interlayer areas. The numerical simulation results show that a lower permeability in breccia layer area has a serious adverse impact on oil recovery if the thickness of breccia layer is larger, whereas the effect of permeability on SAGD performance is limited when the breccia layer is thinner. Besides, a thicker breccia layer can increase the time required to reach the peak oil rate, but has a little impact on the ultimate oil recovery.

PSIX-7 Differences in rumen degradability according to the degree of corn gelatinization

This study was conducted to evaluate the difference in ruminal degradability by the degree of gelatinization of corn grain. The treatments were Control (whole corn grain), T1 (70% gelatinized corn grain steam flake), and T2 (30% gelatinized corn grain steam flake). Corn grain steam flaked for T1 was produced by a pressurized steam chamber for a longer time than T2. For this reason, the thickness of T1 and T2 was 1.5 and 2.5mm on average, respectively. Two Holstein cows (BW.405±15.4kg, 26.5±12 months) fitted with ruminal cannula were fed 4 kg of tall fescue and 3 kg of a formulated concentrate mix. Immediately after morning feeding, the nylon bags containing the sample from all treatments were incubated in the ruminal ventral sac for 0, 2, 4, 8, 12, 18, 24, 36, and 48h. At 0h of incubation, the DM degradability of T1 (16.70%) was higher (P&lt; 0.05) than Control (9.74%) and T2 (12.00%). The degradability of both Control and T2 slightly increased from 4 (23.08 and 27.57%) to 18h (36.65 and 35.52%), exponentially increased from 18 to 48h. On the other hand, the degradability for T1 exponentially increased from 2 (28.74%) to 18h (77.31%), only slightly increased thereafter. The final degradability (48h) of Control, T1, and T2 were 78.07, 89.20, and 84.86%, respectively (P&lt; 0.05). The fraction a of DM degradability for T1 (24.29%) was higher than Control (2.26%) and T2 (6.26%) (P&lt; 0.05). The effective degradability (ED) of T1 (75.31%) was higher (P&lt; 0.05) than Control (57.42%) and T2 (60.86%). Therefore, this study demonstrated that 70% gelatinized corn grain steam flake showed a higher rate of ruminal degradability than other treatments. Thus, it is necessary to determine how these differences affect ruminant productivity through additional feeding experiments.

Challenges of D-SAGD Completion

In the production well of a Steam Assisted Gravity Drainage (SAGD) injector-producer well-pair, Direct-to-SAGD (D-SAGD) reservoir steam chamber development and electrical submersible pump (ESP) deployment requires only a single workover, effectively performing the jobs in parallel. This is an improvement over the traditional approach where reservoir steam chamber development and ESP deployment occur sequentially, each requiring a dedicated workover. The D-SAGD completion not only eliminates all costs associated with one workover, but also minimizes the heat energy dissipation that would otherwise occur over several days of steam injection downtime associated with pulling the completion string and installing the artificial lift system, along with decreased time, and increased safety, among other attendant benefits. Traditionally, an initial completion is performed on the production well to install monitoring instrumentation and a steam injection string, then steam injection occurs through both the injection and production wells for approximately 90 to 120 days. Once the reservoir temperature has reached a predetermined midpoint temperature between the wells, a fall-off test is performed by halting steam injection in both the production and injection wells and monitoring the completion's heat energy distribution profile throughout the length of the liner from heel to toe as the well cools back down toward its steady state temperature. If the results of the fall-off test are satisfactory, then subsequently a second workover is performed to install the ESP into the production well. Lastly, steam injection in the injector well is resumed, and the ESP operation begins. Given that the single D-SAGD workover achieves both the deployment of instrumentation and the ESP prior to steam chamber development, this implies that the ESP is required to withstand the large temperature and pressure fluctuations inherent to the combination of steam chamber development and fall off testing, all prior to being powered on for production to begin. This represents an unprecedented challenge for ESP seal sections. Among several other novel challenges, if the internal oil volume contraction induced by the deep temperature drop of the fall off test exceeds the capacity of the seal section to compensate for it, then the seal and motor may flood with wellbore fluid prior to the first attempt at turning it on. This paper discusses the unique challenges associated with the D-SAGD completion as it relates to ESP reliability. A SAGD-spec ESP remaining downhole for several months at unprecedented bottom hole pressure and temperature, and withstanding the associated fall-off test is a meaningful deviation from the conventional SAGD application, and this paper will detail the considerations associated with achieving ESP reliability in a D-SAGD completion that is comparable to that achieved in the conventional SAGD completion.

Aplicability of an Innovative and Light Seismic Approach to Monitor SAGD Operations in Surmont: A Blind Test

Surmont is a heavy oil field located in northeast Alberta which is currently being developed by a joint venture between ConocoPhillips and Total using Steam Assisted Gravity Drainage (SAGD). To monitor the enhanced oil recovery process and caprock integrity, highly repeatable 4D seismic surveys using dynamite have been completed over the years. In order to maximize the value of information while controlling costs, a novel light seismic monitoring approach has been "blind-tested" on existing 4D data. The concept requires the use of only one source and one receiver couple, optimally placed in the field to monitor one or several subsurface spots, using time redundancy to detect 4D changes in these zones of interest. Three spot locations have been defined by the client on a well pad for which the history was not provided. For each of these spots, specific series of seismic processing steps have enabled the identification of the optimum source/receiver locations. Then, these optimum raw seismic traces extracted from different 4D campaigns have been analysed to detect potential time shift changes in the selected horizon induced by the growth of the steam chamber. Time-shift changes were plotted for all 3 spots. An increase was observed for one of the spots (Spot 3) from the first 4D monitor in 2010 up to the last monitor in 2015. An increase was also plotted between March 2013 and September 2013 for another spot (Spot 1), changes attributed to the dynamics of the steam chamber. On the contrary, spot 1 did not see any effect of the steam. These time-shift changes were then successfully cross-checked with temperature data from observation wells, confirming the qualitative variations attributed to the effects of the steam chamber evolution. It demonstrated the viability of this innovative seismic and focused monitoring approach to monitor the evolution of the steam chamber in Surmont. This also paves the way for a simpler and yet reliable and cost-effective way of monitoring the evolution of the steam chamber to further optimize production and increase rentability.

Effect of Flue Gas on Steam Chamber Expansion in Steamflooding

Summary The expansion of the steam chamber is very important for the recovery performance of steamflooding. In this paper, we discuss 1D and 2D sandpack experiments to performed analyze the effect of flue gas on steam chamber expansion and displacement efficiency in steamflooding. In addition, we examine the effect of flue gas acting on the steam condensation characteristics. The results show that within a certain range of injection rate, flue gas can significantly enlarge the swept volume and oil displacement efficiency of steam. However, when the flue gas injection rate is excessively high (the ratio of gas injection rate to steam injection rate exceeds 4), gas channels may form, resulting in a decline of oil recovery from steamflooding. The results of the 2D visualization experiments reveal that the swept volume of the steam chamber during steamflooding was small, and the remaining oil saturation in the reservoir was high, so the recovery was only 28%. The swept volume of the steam chamber for flue-gas-assisted steamflooding was obviously larger than that of steamflooding, and the recovery of flue-gas-assisted steamflooding in 2D experiments could reach 40.35%. The results of the steam condensation experiment indicate that flue gas could reduce the growth and coalescence rates of steam-condensed droplets on the cooling wall and increase the shedding period of the droplets. Macroscopically, flue gas could reduce the heat exchange rate between the steam and the reservoir and inhibit the rapid condensation and heat exchange of the steam near the injection well. As a result, flue gas could expand the steam chamber into the reservoir for heating and displacing oil.