Sanding: An Expert-System Approach for Assessment and Control in Wells

1997 ◽  
Vol 119 (4) ◽  
pp. 223-235 ◽  
Author(s):  
M. Kanj ◽  
M. Zaman ◽  
J.-C. Roegiers
Keyword(s):  
Expert System ◽  
Oil And Gas ◽  
Petroleum Industry ◽  
Control Process ◽  
Major Influence ◽  
Well Completion ◽  
Oil And Gas Fields ◽  
Sand Control ◽  
Completion Process ◽  
And Control

The sand production problem is plaguing the petroleum industry by its adverse effects on thousands of oil and gas fields throughout the world. A tremendous amount of money is spent each year on attempts to predict and control sand influx and/or repair wells and equipment damaged by sand. Sand inflow into the well during production leads to casing abrasion and failure, formation damage and distortion, and frequent sand removal and cleaning. The sand control process has a major influence on the type of the well completion design and it influences the guidelines for the completion process. In addition, many wells are currently being produced below their potential in order to restrict sand influx or erosion, and/or as a result of poorly designed or installed sand control methods. Evidently, the sand prediction and control problem is exceedingly complex and suggests the use of heuristics and the appropriateness of the expert systems technology. An automated sand control consultant and expert system has been developed. The system is aimed at assisting users in predicting sand occurrence during production and in selecting and designing the proper sand-exclusion treatments. The knowledge base of the system is based on an easy upgrade, easy expand format and involves four primary modules, thus giving the end-user greater flexibility to tentatively access and evaluate different scenarios of knowledge processing. Input data can range from “not known” formation characteristics and/or well stimulation requirements, for which the system gives conservative recommendations based on the remaining known facts, completion characteristics of the hole, well history, and geological probability; to cases with detailed information available, in which case very elaborate and precise recommendations are prescribed. This paper describes the knowledge involved in various modules of the sanding system, as well as future plans and further developments.

A geomechanical approach for sanding risk assessment applied to three field cases for completion optimisation

2010 ◽  
Vol 50 (1) ◽  
pp. 623 ◽  
Author(s):  
Khalil Rahman ◽  
Abbas Khaksar ◽  
Toby Kayes
Keyword(s):  
Decision Making ◽  
Petroleum Industry ◽  
Cost Effective ◽  
Development Planning ◽  
Control Measures ◽  
Sand Production ◽  
Field Development ◽  
Well Completion ◽  
Sand Control ◽  
Production Prediction

Mitigation of sand production is increasingly becoming an important and challenging issue in the petroleum industry. This is because the increasing demand for oil and gas resources is forcing the industry to expand its production operations in more challenging unconsolidated reservoir rocks and depleted sandstones with more complex well completion architecture. A sand production prediction study is now often an integral part of an overall field development planning study to see if and when sand production will be an issue over the life of the field. The appropriate type of sand control measures and a cost-effective sand management strategy are adopted for the field depending on timing and the severity of predicted sand production. This paper presents a geomechanical modelling approach that integrates production or flow tests history with information from drilling data, well logs and rock mechanics tests. The approach has been applied to three fields in the Australasia region, all with different geological settings. The studies resulted in recommendations for three different well completion and sand control approaches. This highlights that there is no unique solution for sand production problems, and that a robust geomechanical model is capable of finding a field-specific solution considering in-situ stresses, rock strength, well trajectory, reservoir depletion, drawdown and perforation strategy. The approach results in cost-effective decision making for appropriate well/perforation trajectory, completion type (e.g. cased hole, openhole or liner completion), drawdown control or delayed sand control installation. This type of timely decision making often turns what may be perceived as an economically marginal field development scenario into a profitable project. This paper presents three case studies to provide well engineers with guidelines to understanding the principles and overall workflow involved in sand production prediction and minimisation of sand production risk by optimising completion type.

The Pyrenees development: a new oil development for Western Australia

2010 ◽  
Vol 50 (1) ◽  
pp. 241
Author(s):  
Tony Slate ◽  
Ralf Napalowski ◽  
Steve Pastor ◽  
Kevin Black ◽  
Robert Stomp
Keyword(s):  
Western Australia ◽  
Oil Recovery ◽  
Oil And Gas ◽  
Flow Meters ◽  
Field Development ◽  
Oil And Gas Fields ◽  
Sand Control ◽  
Concurrent Development ◽  
Gas Fields ◽  
Offshore Oil

The Pyrenees development comprises the concurrent development of three oil and gas fields: Ravensworth, Crosby and Stickle. The fields are located in production licenses WA-42-L and WA-43-L, offshore Western Australia, in the Exmouth Sub-basin. The development will be one of the largest offshore oil developments in Australia for some time. It is a complex subsea development consisting of a series of manifolds, control umbilicals and flexible flowlines tied back to a disconnectable floating production, storage and offloading (FPSO) vessel. The development involves the construction of 17 subsea wells, including 13 horizontal producers, three vertical water disposal wells and one gas injection well. The project is presently on production with first oil achieved during February 2010. This paper gives an overview of the field development and describes the engineering and technologies that have been selected to enable the economic development of these fields. The Pyrenees fields are low relief, with oil columns of about 40 metres in excellent quality reservoirs of the Barrow Group. Two of the fields have small gas caps and a strong bottom water drive common to all fields is expected to assist recovery. The oil is a moderate viscosity, low gas-to-oil ratio (GOR), 19°API crude. Due to the geometry of the reservoirs, the expected drive mechanism and the nature of the crude, effective oil recovery requires maximum reservoir contact and hence the drilling of long near horizontal wells. Besides the challenging nature of well construction, other technologies adopted to improve recovery efficiency and operability includes subsea multiphase flow meters and sand control with inflow control devices.

Mechanical Design and Analysis of an Intelligent Oil Well Sensory System

2010 ◽  
Author(s):  
Atefeh Salmasi ◽  
Aghil Yousefi-Koma ◽  
Mohammad Hossein Soorgee
Keyword(s):  
Oil And Gas ◽  
Mechanical Design ◽  
Sensory System ◽  
High Price ◽  
Oil Well ◽  
Gas Industry ◽  
Oil And Gas Fields ◽  
Sensing Technology ◽  
And Control ◽  
Measurement And Control

Optimal revenue of oil and gas fields is of interest due to high price and limited amount of these sources of energy. In this way, smart well technology provides a numerous range of benefits and for these great advantageous is widely used in oil/gas industry. This technology involves down-hole measurement and control of well bore and reservoir flow. One of the most important down-hole control subsystems in a smart well is pressure and temperature sensing system which can help the reservoir being modeled accurately. The purpose of this paper is to design and analysis a new sensory package for a desired oil well. A brief review of the advantages of fiber optic sensing technology in smart well control system is performed. Having studied several possibilities of installation systems for sensors, a new arrangement and casing for temperature/pressure sensor is developed here. Effect of pressure and temperature on stress distribution in the casing has been investigated and a suitable casing is obtained.

scholarly journals NEW APPROACH TO FLARE GAS RECOVERY SYSTEM USING INTEGRATED RECIPROCATING COMPRESSORS FOR SOLVING ENVIRONMENTAL ISSUE BY MONETIZING GAS

2020 ◽  
Vol 3 (2) ◽  
pp. 149
Author(s):  
Ratnayu Sitaresmi ◽  
Tamado Sitorus ◽  
Hari Karyadi Oetomo ◽  
Doddy Abdassah ◽  
Luluan Almanna Lubis
Keyword(s):  
Gas Flow ◽  
Oil And Gas ◽  
Petroleum Industry ◽  
Environmental Issue ◽  
Co2 Removal ◽  
Subject Field ◽  
Gas Recovery ◽  
Oil And Gas Fields ◽  
Recovery System ◽  
Production Wells

Flare gas is light hydrocarbon gas, by product of any petroleum industry activities, that is flared; and it could not pass into production facilities due its to low pressure. The gas flare volume frequently is significant, causing greenhouse gas emissions which gives serious environmental issue. Aims: The purpose of this research is to utilize flare gas in oil and gas fields to reduce environmental issue. Methodology and Results: Flare gas in an oil producing field is compressed to produce higher pressure gas flow, by using three one-stage Integrated Reciprocating Compressors to enter the production trunk line. The gas is flown to CO2 Removal Plant, as the gas would be gas sales. The subject field in West Java, the production wells experiences pressure decline; resulting the wellhead flowing pressure becomes low, so the gas is being flared. The gas flare recovery system is economically profitable both for purchase and rental scenarios. Renting the equipment is more profitable and has lower technical risk, because all risks is burdened to rental service provider. Conclusion, significance and impact study: Monetizing flare gas will reduce environmental issue, and it is utilized for own use or gas sales. The best Economics Scenario is rental scenario.

Technology GEONOD: Status and Prospects of Automation and Control

2019 ◽  
Vol 20 (11) ◽  
pp. 696-701
Author(s):  
M. R. Liberzon
Keyword(s):  
Oil And Gas ◽  
Seismic Exploration ◽  
Quality Data ◽  
Seismic Prospecting ◽  
Oil And Gas Fields ◽  
Sea Bottom ◽  
Automation And Control ◽  
Shipping Traffic ◽  
Marine Seismic ◽  
And Control

Seismic prospecting is one of the crucial components for an effective use of oil and gas fields on offshore. Since the costs of drilling a well on the shelf is hundreds of times more expensive than drilling a well on land, preliminary marine seismic exploration can help avoid unnecessary costs. High quality data of marine seismic surveys can only be obtained from bottom technologies: special bottom stations are lowered into the investigated area of the seabed. These bottom stations collecting direct and reflected acoustic signals (generated on the surface by an acoustic radiator) from the seabed. After all data is recorded, bottom stations are lifted to the surface, the recorded data is downloaded for subsequent interpretation. As a result, based on the obtained data, a 2D or 3D detailed map of the potential oil and gas deposits is complied. The resulting maps are used to determine the exact coordinates of the installation of drilling stations. The most common technology of marine seismic exploration is the use of bottom stations on a halyard rope. First development of this technology began in the 1970s and did not assume the means of automation work with bottom stations. All operations of removal and attachment of rope to station, diving and lifting stations, as well as a number of other operations were performed manually. Nowadays, there has not been any automation in working with stations on the halyard rope. In addition, the use of halyard rope has a number of disadvantages such as: Hooking of halyard rope for obstacles on the sea bottom; The breakage of the halyard rope; The need to have additional space on the vessel to store the halyard rope and all accessories, which leads to the use of larger vessels that can not operate at shallow depths; The halyard rope that is connected to the bottom stations generates a seismic noise, which degrades the quality of the received data; Impossible to conduct seismic prospecting in places with high shipping traffic. Developed over the past few years, a new Russian technology of marine seismic exploration GEONOD allows us easily solve many of mentioned problems. Many of these problems do not rise at all, since the GEONODE technology does not use halyards, and the work is carried out by the autonomous self-popup bottom stations (ASDS). In this paper a number of problems on applied mechanics and control in connection with technology GEONOD are considering.

Scale formation and control in oil and gas fields: A review

2016 ◽  
Vol 38 (5) ◽  
pp. 661-670 ◽  
Author(s):  
Jianbo Li ◽  
Mingjin Tang ◽  
Zhengrong Ye ◽  
Longli Chen ◽  
Yuqin Zhou
Keyword(s):  
Oil And Gas ◽  
Scale Formation ◽  
Oil And Gas Fields ◽  
Gas Fields ◽  
And Control

scholarly journals Power supply and control systems for subsea production complexes in Arctic offshore fields

2021 ◽  
Vol 1201 (1) ◽  
pp. 012064
Author(s):  
Yu A Kharchenko ◽  
K N Krotov
Keyword(s):  
Control Systems ◽  
Power Supply ◽  
Oil And Gas ◽  
Arctic Shelf ◽  
The Arctic ◽  
Effective Control ◽  
Oil And Gas Fields ◽  
Current State ◽  
Gas Fields ◽  
And Control

Abstract The subsea type of arrangement is no alternative for remote deep-sea oil and gas fields of the Arctic shelf. One of the main factors determining the level of reliability of year-round production of hydrocarbons using subsea production complexes is the availability of effective control and power supply systems. In this article the current state of subsea production complexes is studied, possible ways to develop power supply and control systems are analyzed in order to increase their efficiency and reliability when used in deep-water remote fields of the Arctic shelf.

scholarly journals Effect of Alkalinity on Sand Production Due to Optimized Smart Water Based on the Scale Minimization: Impact of Silica Nanoparticles

2020 ◽  
Vol 11 (1) ◽  
pp. 7712-7724
Keyword(s):  
Silica Nanoparticles ◽  
Oil And Gas ◽  
Low Cost ◽  
Water Injection ◽  
Petroleum Industry ◽  
Effective Parameters ◽  
Sand Production ◽  
Gas Reservoirs ◽  
Smart Water ◽  
And Control

Smart water injection in oil and gas reservoirs is one of the most popular and low-cost methods to increase the recovery factor of reservoirs. However, due to the abundance of sandstone reservoirs in the world and the necessity to increase recovery in these types of reservoirs, injection of smart water will disturb the distribution of intergranular stresses in the porous media which results in sand production that causes many problems in many parts of the petroleum industry. For this reason, the necessity to investigate possible parameters affecting sand production was increased. Also, according to the relative researches, the injection of smart water changes the reservoir pH, which could change the sand production rate. In this paper, a comprehensive study on the effect of pH or alkalinity on sand production, as well as the effect and mechanism of silica nanoparticles, has been performed to control the grains separated from the rock. The effect and mechanism of silica nanoparticles with economic concerns have also been analyzed, which can significantly reduce and control the amount of sand production. In this paper, we can determine the effectiveness and the most effective parameters in an acidic or basic environment.

Artificial Intelligence Model for Predicting Formation Damage in Oil and Gas Wells

2021 ◽  
Author(s):  
Augustine James Effiong ◽  
Joseph Okon Etim ◽  
Anietie Ndarake Okon
Keyword(s):  
Mean Square Error ◽  
Goodness Of Fit ◽  
Oil And Gas ◽  
Performance Metrics ◽  
Petroleum Industry ◽  
Formation Damage ◽  
Mean Square ◽  
Ann Model ◽  
Gas Drilling ◽  
Well Completion

Abstract An artificial neural network (ANN) was developed to predict skin, a formation damage parameter in oil and gas drilling, well completion and production operations. Four performance metrics: goodness of fit (R2), mean square error (MSE), root mean square error (RMSE), average absolute percentage relative error (AAPRE), was used to check the performance of the developed model. The results obtained indicate that the model had an overall MSE of 355.343, RMSE of 18.850, AAPRE of 4.090 and an R2 of 0.9978. All the predictions agreed with the measured result. The generalization capacity of the developed ANN model was assessed using 500 randomly generated datasets that were not part of the model training process. The results obtained indicate that the developed model predicted 97% of these new datasets with an MSE of 375.021, RMSE of 19.370, AAPRE of 6.090 and R2 of 0.9731, while Standing (1970) equation resulted in R2of −0.807, MSE of 9.34×1016, AAPRE of 3.10×106 and RMSE of 4.10×105. The relative importance analysis of the model input parameters showed that the flow rates (q), permeability (k), porosity (φ) and pressure drop (Δp) had a significant impact on the skin (S) values estimated from the downhole. Thus, the developed model if embedded in a downhole (sensing) tool that capture these basic or required reservoir parameters: pressure, flowrate, permeability, viscosity, and thickness, would eliminate the diagnostic approach of estimating skin factor in the petroleum industry.

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