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Abstract An experimental evaluation of a gas-liquid axial cyclone separator was conducted in a multiphase flow facilities al PDVSA-Intevep, the evaluation of the prototype was executed under controlled conditions of flow rates, between 24 and 60 Bbl/day for a liquid phase and between 80.000 and 190000 SCFD for a gas phase, considering three stator with 45°, 60° and 75° of blade angle in a swirl generator section. The axial cyclone separator was built in plexiglass in order to record with video camera the phenomenon that was observed inside of the equipment the experimental data of the matrix was collected in a control room, considering the measurement of flow rate, local pressure and the pressure drop in the equipment. The axial cyclone separator consists of a flow conditioning section, as will generator section and a segregation section. Finally, a total of 72 points were valuated, the performance of the axial cyclone separator was improved with 60° and 75° of the blade angle than a 45° because the collection efficiency was above of 90%, in this study the pressure drop increases inside the equipment 30% when the 75° of blade angle was used in the stator, the best performance was achieve considering the 60° of blade angle in a swirl generator section.
Abstract For the majority of older oil and gas facilities, the production and processing environment has changed significantly since its early days, with increasing operational and maintenance overheads and obsolete control technology often threatening to bring lift costs above production revenues. As a result, Production and Operational Efficiency has significantly worsened in recent years with many of these assets performing well below optimum production, equating to approximately 500,000 barrels of lost production per day in the UKCS or £10bn/annum (based on Oil and Gas UK production availability figures) Enquest's Thistle platform was one of these assets and was due to be decommissioned until the brave decision was taken to extend its life by putting in place the Late Life Extension Program (LLX). Using groundbreaking Asset Life Extension techniques and methodologies, this old facility is in the process of being re-designed by simplifying the topsides which in turn, is leading to improved availability, increased production and reduced operating costs. A simplified, safer process in a controlled environment has been created whilst balancing the requirements of a capital budget, against reduced OPEX and process risk. It is estimated that the modifications have added at least 15 years of safe, viable, profitable production to the Thistle's lifespan, a great example of deferring decommissioning and Maximising Economic Recovery.
Janan, Bogdan Sultan Aziz (Gazpromneft NTC LLC) | Koryakin, Fyodor Andreevich (Gazpromneft NTC LLC) | Sherstoboev, Evgenii Andreevich (Gazpromneft NTC LLC) | Isakov, Kirill Dmitrievich (Gazpromneft NTC LLC) | Virt, Vitaliy Igorevich (Gazpromneft-Yamal) | Kashapov, Denis Zabirovich (Gazpromneft-Yamal)
This work describes the technological solutions that were used in the development of the Novoportovskoye field - a large oil and gas condensate field in the Yamalo-Nenets Autonomous Okrug. In particular, optimization of the associated gas utilization strategy is considered by organizing the reservoir pressure maintenance. The decisions were based on 3D mathematical calculations, analytical estimates, analysis of field information and reservoir simulation.
The paper presents the results of calculations performed to determine the specific efficiency of gas injection at productive formation. Additionally, weight coefficients of gas injection were calculated for gas well sites to identify the best injection zones. The paper provides the estimation of the current effect of the continuous two-year gas injection. The formation response to the gas injection into the gas cap was estimated by the usage of pressure-observation wells data, data from wells equipped with fiber-optic monitoring systems and by performing retrospective simulation.
The calculations made it possible to achieve complete utilization of associated petroleum gas and significantly increase the oil recovery factor.
Abstract The development of accurate digital measurement of instantaneous power during a pump stroke has made possible a very quick and detailed analysis of the efficiency of the pumping system. The efficiency is then used as the benchmark for determining whether a complete well performance analysis is warranted from the standpoint of making best use of personnel and economic resources to increase oil production. In addition, power measurement provides direct information about lifting cost per barrel of fluid and barrel of oil produced, electrical and mechanical loading of the prime mover, peak power demand, power factor and minimum required ratings. These results give operating personnel information regarding potential problems and give to management a complete picture of the distribution of pumping costs. The power measurements are also converted, by the software, to instantaneous torque and presented as continuous torque curves for the upstroke and downstroke. This allows determination of the existing level of counterbalance and provides the most rapid and accurate method for counterbalance adjustment to achieve lower torque loading on the gear box and reduced energy utilization. One of the principal advantages of this balancing method is that counterbalance adjustment can be made without need for an accurate description of the pumping unit's geometry which is often unknown or inaccurate. The effect of counterweight displacement on torque and power is observed immediately by repeating the power measurement after relocating the counterweights. This paper presents a series of case studies showing the application of power measurement to a variety of pumping systems and components, including conventional, Mark II, Rotaflex units and high efficiency motors. INSTANTANEOUS MOTOR POWER MEASUREMENT A system was designed and implemented to undertake quantitative measurement of instantaneous power using sensors consisting of two current probes and three voltage leads, which are connected to the three phase leads inside the units switch box. Special purpose integrated circuits process the sensors data so as to generate an analog signal which is proportional to the instantaneous power. The sensors are calibrated so as to determine the power with an accuracy better than 5% provided the probes are correctly installed. The measurement procedure must be followed closely in order to obtain data of good and repeatable quality. In general the user is interested in establishing the power use of the pumping system when it is operating under steady state conditions. In the case that the well is pumping a full barrel and then begins to pump a partial barrel of liquid, the measured power will vary and will not be representative of the normal operating conditions. Therefore it is advisable to insure that the well being tested is produced while testing at the same conditions as normal operations. This can easily be undertaken by running quick dynamo meter measurements. When power measurements are to be made with the purpose of comparing the efficiency of different motor wiring options (low, medium or high torque for example) it is important not to move the current sensors after installation so as not to change the relative position of the wire within the current sensor. Such change would cause small variations in the readings which might invalidate the conclusions of the test. The data for two successive pump cycles are acquired with a high speed, high precision A/D converter and processed by a portable PC. The software then generates graphic and tabular output screens which are saved on disk for subsequent printing. Figure 1 presents the information related to energy utilization. P. 815^
Abstract Using a database from Niger Delta, this study developed correlation of well completion/production efficiency as functions of pressure drawdown and sand control type to quantitatively evaluate the effect of pressure drawdown on well performance. Generally, Completion/performance efficiency declines exponentially with reservoir pressure drawdown. Critical pressure drawdown for various sand control types beyond which significant formation damage will occur are recommended. Apart from external gravel-pack (EGP) and milled casing under-reamed gravel-pack (MCUGP) wells which can tolerate drawdown of ±400 psi, the critical drawdown for other sand control types is ±250psi. With these correlations, drawdown for tubing conveyed perforation can be carefully designed and well completions evaluated. More so, real time prediction of production performance efficiency can be evaluated given the pressure drawdown.