Developments on Calcium Sulfate Scaling Prediction and Control in Oil and Gas Production

2020 ◽  
Author(s):  
Samridhdi Paudyal ◽  
Sana Mateen ◽  
Chong Dai ◽  
Saebom Ko ◽  
Xin Wang ◽  
...  
Keyword(s):  
Calcium Sulfate ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Prediction And Control ◽  
And Control

scholarly journals Improving the energy efficiency of oil production using identification and prediction of operating modes of production wells based on data analysis methods, machine learning and neural networks

2019 ◽  
Vol 124 ◽  
pp. 05031 ◽  
Author(s):  
A.M. Sagdatullin
Keyword(s):  
Neural Network ◽  
Neural Networks ◽  
Control System ◽  
Oil And Gas ◽  
Gas Production ◽  
Operating Conditions ◽  
Identification System ◽  
Oil And Gas Production ◽  
The Neural Network ◽  
And Control

Currently, there is a need to improve the systems and control of pumping equipment in the oil and gas production and oil and gas transport industries. Therefore, an adaptive neural network control system for an electric drive of a production well was developed. The task of expanding the functional capabilities of asynchronous electric motors control of the oil and gas production system using the methods of neural networks is solved. We have developed software modules of the well drive control system based on the neural network, an identification system, and a scheme to adapt the control processes to changing load parameters, that is, to dynamic load, to implement the entire system for real-time control of the highspeed process. In this paper, based on a model of an identification block that includes a multilayered neural network of direct propagation, the control of the well system was implemented. The neural network of the proposed system was trained on the basis of the error back-propagation algorithm, and the identification unit works as a forecaster of system operation modes based on the error prediction. In the initial stage of the model adaptation, some fluctuations of the torque are observed at the output of the neural network, which is associated with new operating conditions and underestimated level of learning. However, the identification object and control system is able to maintain an error at minimum values and adapt the control system to a new conditions, which confirms the reliability of the proposed scheme.

Scale Prediction for Oil and Gas Production

SPE Journal ◽  
2012 ◽  
Vol 17 (02) ◽  
pp. 362-378 ◽  
Author(s):  
Amy T. Kan ◽  
Mason B. Tomson
Keyword(s):  
Oil And Gas ◽  
Saturation Index ◽  
Continuous Production ◽  
Equilibrium Constants ◽  
Interaction Model ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Calcite Saturation ◽  
Prediction And Control ◽  
Ph Scale

Summary Scale prevention is important to ensure continuous production from existing reserves that produce brine. Wells could be abandoned prematurely because of poor management of scale and corrosion. The objective of this paper is to present an overview of scale prediction and control and the current research at Rice University to solve these problems. In this paper, the challenges of scale prediction at high temperature, high pressure, and high total dissolved solids (TDS) and an accurate model to predict pH, scale indices, density, and inhibitor needs at these conditions are discussed and reviewed: specifically discussed are (1) the various scale types found in oil and gas production and the condition under which they form; (2) the relationship of pH, alkalinity, organic acids, carbonates, and CO2 distribution; (3) the temperature (T), pressure (P), TDS dependence of the thermodynamic equilibrium constants and activity coefficients; and (4) the accuracy of the Pitzer ion-interaction model-based scale-prediction algorithms and their application. On the basis of a simple propagation of error estimation, the overall estimated error for calcite saturation index (SI) is ± 0.1. This algorithm has been validated with literature solubility data for six minerals in the T, P, and TDS range of 0 to 200°C, 0 to 15,000 psia, and 0 to 350 000 mg/L TDS; for pH data at 25 and 60°C; and density of weighting fluids with density between 8 and 12.7 lbm/gal.

Integrated modelling of entire production network and topsides facilities for production optimisation of major oil and gas fields

2013 ◽  
Vol 53 (2) ◽  
pp. 474
Author(s):  
Azwan Shaharun
Keyword(s):  
Oil And Gas ◽  
Network Models ◽  
Gas Production ◽  
Operating Conditions ◽  
Process Models ◽  
Integrated Modelling ◽  
Production Network ◽  
Oil And Gas Production ◽  
And Control ◽  
Process Simulator

An oil company sought to identify bottlenecks in three of their main oil and gas production networks. It was desired to, therefore, develop the entire production network from wells, flowlines, intra-field and inter-field pipelines, and export pipelines up to the onshore terminal first stage separator/slug catcher, all in the transient multi-phase-flow oil and gas (OLGA) simulator. Furthermore, the detailed topsides facilities were separately modelled in a process simulator. The OLGA and process simulator models were subsequently integrated, where the flow simulator model received boundary pressures from the topsides model and pushed through the mass flows of the individual phases into the process simulator. After field-matching and tuning the integrated models to the given field data, optimising the overall fields’ production and performance was carried out, powered by a market-leading optimisation engine. The main optimisation parameters were: wellhead choke openings; gas lift rates and allocations; and topsides operating conditions, facility constraints and control tuning parameters. The network models were used to investigate the dynamic behaviour of wells and pipelines as well as surface process facilities equipment and control systems, with the aim to improve productivity of the entire field networks. The development of the integrated and dynamic well, pipeline and process models is part of company initiatives to facilitate the design and operational support tools for the company’s engineers.

Failures of Chemical Injection Points in Upstream Facilities

2009 ◽  
Vol 83-86 ◽  
pp. 579-591 ◽  
Author(s):  
A.S. Al-Omari ◽  
Khalid M. Al-Nabulsi ◽  
Ali F. Al-Mari
Keyword(s):  
High Pressure ◽  
Phase Separation ◽  
Service Life ◽  
Oil And Gas ◽  
Gas Production ◽  
Materials Selection ◽  
Injection Point ◽  
Oil And Gas Production ◽  
And Control ◽  
Control Corrosion

Chemicals play an important role in the enhancement of oil and gas production and processing. They control corrosion, prevent organic and inorganic deposits, aid in phase separation and control microbial problems. Several factors can have significant impact on the safety, maintenance, operation, and service life of the chemical injection point. Failures encountered in the high pressure retrievable chemical injection points are presented. This paper also provides guidelines for materials selection and design of chemical injection points in upstream facilities.

scholarly journals INVESTIGATION OF THERMAL PROPERTIES OF RESERVOIR ROCKS AT DIFFERENT SATURATION

2020 ◽  
Author(s):  
Sudad H Al-Obaidi ◽  
Kamensky IP ◽  
Smirnov VI
Keyword(s):  
Thermal Properties ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Thermal Characteristics ◽  
Gas Production ◽  
Oil Field ◽  
Oil And Gas Production ◽  
Field Development ◽  
Water Saturated ◽  
And Control

Oil and gas production using formation thermal stimulation or treatment represents one of the main enhanced oil recovery methods. In this study the thermal properties of rocks and their relationship to the nature of rock saturation were investigated.The method, experimental setup, and results of studying the thermal characteristics of fine - and medium-grained highly porous sandstones at their different saturation are presented. The highest values of thermal diffusivity, thermal conductivity and heat capacity correspond to water-saturated samples, smaller values correspond to oil-saturated ones and the lowest values corresponds to dry (extracted) samples. The obtained data can be used in the selection of the technology of thermal formation stimulation on the reservoir and control over the process of oil field development.

Phase Stability and Inhibition of Calcium Sulfate in the System NaCl/Monoethylene Glycol/H2O

SPE Journal ◽  
2011 ◽  
Vol 17 (01) ◽  
pp. 187-197 ◽  
Author(s):  
Haiping Lu ◽  
Kan Amy T ◽  
Ping Zhang ◽  
Jie Yu ◽  
Chunfang Fan ◽  
...  
Keyword(s):  
Phase Transition ◽  
Phase Behavior ◽  
Calcium Sulfate ◽  
Oil And Gas ◽  
Gas Production ◽  
Inhibition Mechanism ◽  
Oil And Gas Production ◽  
Prediction And Prevention ◽  
Monoethylene Glycol ◽  
Kinetics Of

Summary Calcium sulfate is one of the major mineral scales in oil and gas production. Hemihydrate (CaSO4·0.5H2O) and anhydrite (CaSO4) are the predominant sulfate scales formed at high temperature, while gypsum (CaSO4·2H2O) scale may form at low temperatures (<~45°C). However, it has been shown in this study that anhydrite can form at low temperature in the presence of excess amounts of monoethylene glycol (MEG), and this may occur during offshore production with long tie-backs. The prediction and prevention of calcium sulfate scales requires knowledge of the phase behavior of the three major phases of calcium sulfate. The phase behavior of different calcium sulfate phases is related to the supersaturation state, temperature, and fugacity of water. In this study, the effect of a common hydrate inhibitor, MEG, on calcium sulfate solubility and phase behavior was investigated. This study was run with NaCl/CaSO4/MEG/H2O solutions at 0–6 molality (M) NaCl and 0–95 wt% MEG at 4–70°C. Three approaches were taken to determine the kinetics of calcium sulfate phase transition at various temperatures, ionic strengths, and MEG concentrations: (1) dissolution of gypsum, (2) dissolution of anhydrite, and (3) nucleation and precipitation of calcium sulfate by mixing calcium- and sulfate-containing solutions. The effect of scale inhibitors on phase transition was also evaluated. Phase transition of gypsum to anhydrite was observed in the presence of high concentrations of NaCl and MEG, regardless of the experimental approach. The transition boundary of temperature and concentrations of NaCl and MEG can be estimated from solubility of calcium sulfate and the fugacity of water. The inhibition mechanism of hexamethylene diamine tetra (methylene phosphonic acid) (HDTMP), one of the most effective inhibitors for calcium sulfate scale, was also tested by investigating the kinetics of precipitation and inhibition of calcium sulfate.

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