Virtual flow metering of production flow rates of individual wells in oil and gas platforms through data reconciliation

2021 ◽  
pp. 109772
Author(s):  
Gabriel M.P. Andrade ◽  
Diego Q.F. de Menezes ◽  
Rafael M. Soares ◽  
Tiago S.M. Lemos ◽  
Alex F. Teixeira ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Data Reconciliation ◽  
Production Flow ◽  
Flow Rates ◽  
Flow Metering

Application of Genetic-Algorithm-Based Data Reconciliation on Offshore Virtual Flow Metering of Gas-Condensate Field Production

2018 ◽  
Author(s):  
Dan Wang ◽  
Jing Gong ◽  
Di Fan ◽  
Guoyun Shi ◽  
Juheng Yang
Keyword(s):  
Genetic Algorithm ◽  
Flow Rate ◽  
Engineering Application ◽  
Gas Condensate ◽  
Physical Models ◽  
Data Reconciliation ◽  
Production Flow ◽  
Two Phase ◽  
Flow Metering ◽  
Single Well

During present offshore gas-condensate production, flow meters, due to its exceedingly high cost, are being substituted by Virtual Flow Metering (VFM) Technology for monitoring total and single-well flow rates through sensor measurements and physical models. In this work, the inverse problem is solved by Data Reconciliation (DR), minimizing weighted sum of errors with constraints integrating multiple two-phase flow models. The DR problem is solved by Parallel Genetic Algorithm, without complex calculations required by conventional optimization. The newly developed VFM method is tested by data from a realistic gas-condensate production system. The results show good accuracy for the total mass flow rate with model calibration. Meanwhile, recommended single-well flow rate can be provided without physical meters. The method is proved of good robustness with individual pressure sensor invalid, even total flow rate measurements unavailable. The time cost of each reconciliation process can meet the demand of engineering application.

Introduction of Circumferentially Nonuniform Variable Guide Vanes in the Inlet Plenum of a Centrifugal Compressor for Minimum Losses and Flow Distortion

2016 ◽  
Vol 138 (9) ◽  
Author(s):  
Ismail Sezal ◽  
Nan Chen ◽  
Christian Aalburg ◽  
Rajesh Kumar V. Gadamsetty ◽  
Wolfgang Erhard ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Variable Speed ◽  
Flow Distortion ◽  
Flow Rates ◽  
Guide Vanes ◽  
Baseline Design ◽  
Pressure Losses ◽  
Operating Range ◽  
Maximum Angle ◽  
The Impact

In the oil and gas industry, large variations in flow rates are often encountered, which require compression trains with a wide operating range. If the stable operating range at constant speed is insufficient, variable speed drivers can be used to meet the requirements. Alternatively, variable inlet guide vanes (IGVs) can be introduced into the inlet plenum to provide pre- or counterswirl to the first-stage impeller, possibly eliminating the need for variable speed. This paper presents the development and validation of circumferentially nonuniform IGVs that were specifically designed to provide maximum angle variation at minimum losses and flow distortion for the downstream impeller. This includes the comparison of three concepts: a baseline design based on circumferentially uniform and symmetric profiles, two circumferentially nonuniform concepts based on uniquely cambered airfoils at each circumferential position, and a multi-airfoil configuration consisting of a uniquely cambered fixed part and a movable part. The idea behind the circumferentially nonuniform designs was to take into account nonsymmetric flow features inside the plenum and a bias toward large preswirl angles rather than counter-swirl during practical operation. The designs were carried out by computational fluid dynamics (CFD) and first tested in a steady, full-annulus cascade in order to quantify pressure losses and flow quality at the inlet to the impeller at different IGV setting angles (ranging from −20 deg to +60 deg) and flow rates. Subsequently, the designs were mounted in front of a typical oil and gas impeller on a high-speed rotating rig in order to determine the impact of flow distortion on the impeller performance. The results show that pressure losses in the inlet plenum could be reduced by up to 40% with the circumferentially nonuniform designs over the symmetric baseline configuration. Furthermore, a significant reduction in circumferential distortion could be achieved with the circumferentially nonuniform designs. The resulting improvement in impeller performance contributed approximately 40% to the overall efficiency gains for inlet plenum and impeller combined.

Automated systematic method for calculating the operating mode of gas wells using concentric tubing during self-pressure

2020 ◽  
pp. 51-59
Author(s):  
А.I. Ponomarev ◽  
◽  
T.T. Ragimov ◽  
E.S. Yushin ◽  
◽  
...  
Keyword(s):  
Flow Rate ◽  
Software Package ◽  
Oil And Gas ◽  
Operating Mode ◽  
Gas Condensate ◽  
Innovative Technology ◽  
Gas Wells ◽  
Systematic Method ◽  
Field Problem ◽  
Flow Rates

The article proposes a solution to the problem of operating wells, at the bottom of which, during the production of reservoir products, fluid accumulates. It is shown that traditionally this field problem is solved by carrying out underground repairs, which creates the risk of the wells not being brought back to the initial parameters, primarily in terms of flow rate. The solution to this type of complication in the wells of the Cenomanian deposit of the Urengoy oil and gas condensate field is to transfer the wells to operation using concentric lift columns. This relatively new innovative technology allows for the removal of liquid from the bottom together with gas, thereby avoiding killing the well and its subsequent repair, as well as possible stimulating treatments to restore the necessary flow. It is shown that by calculating the dependencies and the software package it is possible to determine the critical and recommended flow rates for well operation without complications.

scholarly journals Appropriate Separator Sizing: A Modified Stewart and Arnold Method

2012 ◽  
Vol 2012 ◽  
pp. 1-4
Author(s):  
F. Boukadi ◽  
V. Singh ◽  
R. Trabelsi ◽  
F. Sebring ◽  
D. Allen ◽  
...  
Keyword(s):  
Pressure Drop ◽  
History Matching ◽  
Oil And Gas ◽  
Slenderness Ratio ◽  
Petroleum Industry ◽  
Production Equipment ◽  
Time Model ◽  
Initial Flow ◽  
Flow Rates ◽  
Valve Pressure

Oil and gas separators were one of the first pieces of production equipment to be used in the petroleum industry. The different stages of separation are completed using the following three principles: gravity, centrifugal force, and impingement. The sizes of the oil droplets, in the production water, are based mainly on the choke valve pressure drop. The choke valve pressure drop creates a shearing effect; this reduces the ability of the droplets to combine. One of the goals of oil separation is to reduce the shearing effect of the choke. Separators are conventionally designed based on initial flow rates; as a result, the separator is no longer able to accommodate totality of produced fluids. Changing fluid flow rates as well as emulsion viscosity effect separator design. The reduction in vessel performance results in recorded measurements that do not match actual production levels inducing doubt into any history matching process and distorting reservoir management programs. In this paper, the new model takes into account flow rates and emulsion viscosity. The generated vessel length, vessel diameter, and slenderness ratio monographs are used to select appropriate separator size based on required retention time. Model results are compared to API 12J standards.

scholarly journals Design of Flowline, Separator, and Slug Catcher in X Field

2018 ◽  
Vol 1 (3) ◽  
Author(s):  
I Gede Dian Aryana ◽  
Muhammad Taufiq Fathaddin ◽  
Djoko Sulistyanto
Keyword(s):  
Multiphase Flow ◽  
Oil And Gas ◽  
Slenderness Ratio ◽  
Transport Processes ◽  
Hydrodynamic Conditions ◽  
Production Flow ◽  
Gas Field ◽  
Oil And Gas Field ◽  
High Production ◽  
High Possibility

<p>The use of the pipeline is the safest method in sending oil and gas from one area to another in oil and gas transportation system. The only challenge is to keep the pressure drop in the pipeline as small as possible to avoid high pressure differences. This pressure difference can result in reduced production flow rate and affect the flow pattern in the pipeline. The condition can lead to high possibility of a slug on pipelines that drain multiphase flow. Slug becomes one of the main concerns transport processes multiphase flow in pipelines. The emergence of slug in the pipeline could cause an unstable hydrodynamic conditions will continue to affect the liquid level in the inlet separator and cause flooding in the separator. Some of the conclusions mainly on the diameter of the pipeline, the size of the slug catcher and the size of the separator obtained from the calculation based on the study of literature and simulations with software HYSIS and OLGA. Design slug catcher to accommodate the number of processes that occur in the production transportation of X oil and gas field through a pipeline 10 inches along the 12 km with 20.68 m3 volume of slug using 3 (three) finger with diameter 28 inches and length of 10 meters each. For the separation process of oil and gas in the first five (5) years of X oil and gas field  which has a high production of oil and condensate will require separator with 30 inches diameter, seam to seam height of 8.1 ft or 2.5 meters, with retention time for 2 minutes and the 3.2 slenderness ratio of the vertical separator.</p>

Dependence of Gas Transportation in Radial Lip Seals on Oil and Gas

2005 ◽  
Author(s):  
J. Sugimura ◽  
S. Gondo ◽  
Y. Yamamoto
Keyword(s):  
Gas Flow ◽  
Oil And Gas ◽  
Experimental Studies ◽  
Shaft Speed ◽  
Oil Viscosity ◽  
Flow Rates ◽  
Mineral Oils ◽  
Pump Rate ◽  
Lip Seals ◽  
Shaft Seals

Experimental studies are made on transportation of gas across radial shaft seals. Gas flow rates are determined with gas chromatography. Gas is pumped in, while gas also leaks at about half of the pump rate. The flow rates increase with shaft speed and oil viscosity, though paraffinic mineral oils allow more gas to move than polyalphaolefin of the same viscosity. The rate also depends on gas. These suggest that gas is conveyed by hydrodynamic flow of oil at the seal lip.

Exploration of an unconventional petroleum resource through extensive core analysis and basin geology interpretation utilising play element methodology: the Lower Goldwyer Formation, onshore Canning Basin, Western Australia

2019 ◽  
Vol 59 (1) ◽  
pp. 464 ◽  
Author(s):  
Jop van Hattum ◽  
Aaron Bond ◽  
Dariusz Jablonski ◽  
Ryan Taylor-Walshe
Keyword(s):  
Oil And Gas ◽  
Fluid Composition ◽  
Reservoir Properties ◽  
Oil And Gas Development ◽  
Flow Rates ◽  
Canning Basin ◽  
Petroleum Systems ◽  
Multi Stage ◽  
Play Elements ◽  
Extractable Organic Matter

Theia Energy Pty Ltd1 (Theia Energy) discovered a potential unconventional hydrocarbon resource in the Ordovician Lower Goldwyer (GIII) Formation shale located on the Broome Platform of the onshore Canning Basin. The collation, processing, analysis and interpretation of all available regional data culminated in a successful exploration well, Theia-1 (drilled in 2015), which, based upon petrophysical and core analyses, intersected a 70 m gross oil column at 1500–1570 m depth. Theia-1 recovered essential core and wireline log data required to analyse and assess the play elements and reservoir properties necessary for a viable shale oil and gas development. Utilisation of an ‘Unconventional Play Element’ methodology has proven the unconventional hydrocarbon potential of the GIII Formation, and preliminary modelling indicates that economic stimulated flow rates may be achieved. Further operations (a test well with multi-stage hydraulic fracture stimulation) are scheduled in the coming permit year to further quantify the presence of extractable organic matter in the GIII Formation, assess hydrocarbon flow rates, determine fluid composition and appraise commercial viability. This paper will discuss Theia Energy’s exploration campaign in the onshore Canning Basin starting with the regional evaluation, which encompassed all available geoscience data (offset wells, pre-existing seismic and potential analogue fields) and modern specialised shale analysis (sequence stratigraphy, paleogeography, geochemistry, unconventional petrophysics and petroleum systems modelling), to develop a robust regional geological model for the GIII Formation. Pre-drill analysis reduced exploration risk and successfully identified the key geological play elements essential for the successful Theia-1 exploration evaluation program.

Predicting Oil Production Flow Rate Using Artificial Neural Networks - The Volve Field Case

2021 ◽  
Author(s):  
Alexander George
Keyword(s):  
Flow Rate ◽  
Learning Algorithm ◽  
Oil Production ◽  
High Accuracy ◽  
Training Dataset ◽  
Empirical Correlations ◽  
Production Flow ◽  
Flow Rates ◽  
Oil Flow ◽  
Artificial Neural

Abstract Accurate prediction of oil production flow rates helps production engineers to detect anomalous values which in turn will provide insights about any flaws in huge oil well systems. To aid this, oil flow rate is commonly estimated using empirical correlations. However, in some cases, significant error is inherent in application of this empirical correlation and will often yield inaccurate results. This present work aims to develop a machine learning algorithm based on an Artificial Neural Network to predict with (high accuracy) the oil production flow rate, using an open source data obtained from Volve production field in Norway. The Downhole Pressure and Temperature, Average Tubing and Annular Pressure Details, Onstream Hours, and Choke Details are used as the input parameters to the algorithm. The procedure can be considered a valid approach for its high accuracy and due to the wide acceptance of data-driven analytics in the industry today. To develop the model structure, 70% of the data was used the training dataset, and to further evaluate the performance, 30% of the data was used to derive the mean square error and determination coefficient. An error distribution histogram and the cross-plot between simulation data and verification data were drawn. These results show high predictability of the model and affirmed that ANN has the ability to handle large dataset and also will give a better prediction of oil flow rate when compared to the empirical correlations method. Therefore, equipping production engineers with the capacity to accurately predict oil flow rates from upstream pressure, choke size, and producing gas to oil ratio of a producing well rather than the use of empirical correlations.

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