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A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "H1: Petroleum Engineering".

Deadline for manuscript submissions: closed (10 October 2022) | Viewed by 27466

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Special Issue Editors

Dr. Valentin Morenov

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Guest Editor

Department of Petroleum Engineering, Saint Petersburg Mining University, Saint Petersburg, Russia
Interests: the issues of sustainable petroleum production; utilization of petroleum gas; power supply of oil and gas fields; treatment and processing of crudes in the field conditions; carbon capture, use and storage at petroleum fields
Special Issues, Collections and Topics in MDPI journals

Prof. Dr. Tianle Liu

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Co-Guest Editor

Faculty of engineering, Department of oil and gas well engineering, China University of Geosciences, Wuhan, China
Interests: well engineering; natural gas hydrates; drilling muds

Special Issue Information

Dear Colleagues,

We invite you to submit articles regarding the broad topic of the petroleum well life cycle to be published in this Special Issue of Energies. We also welcome critical review articles from renowned experts in industry and academia.

Despite the existing trend towards green power sources, hydrocarbons will be essential for the world energy market for years to come. Sustainable development of modern society is impossible without reliable energy sources. Until renewables are able to cope with such problems as the efficient generation and storage of produced energy, oil and gas will provide a steady power supply for consumers. At the same time, traditional petroleum fields are being depleted. New deposits of oil and gas are located in remote and hard-to-reach regions, such as the Arctic. In addition to complicated conditions of petroleum production in these areas, environmental concerns are of great importance. A relevant trend is reducing the carbon footprint for oil and gas production. In this regard, this Special Issue deals with questions of modern techniques and approaches during the entire life cycle of petroleum wells: from construction to abandonment.

Topics of interest for publication include, but are not limited to:

Well engineering
Well integrity;
Cement sheath integrity;
Chemical instability;
Wellbore strengthening techniques;
Petroleum production;
Fluid flow;
Formation stimulation;
Gas hydrates;
Well completion;
Well-killing technologies;
Oil emulsions;
Water shut-off;
Geodynamically hazardous areas;
Well development in the Arctic region;
Unconventional oil and gas reserves;
Optimization of energy consumption at well construction and operation;
Directional and horizontal drilling;
Artificial water-flooding;
Low-permeable reservoirs;
Well and reservoir surveys;
Energy saving and digital technologies.

Dr. Valentin Morenov
Guest Editor

Prof. Dr. Tianle Liu
Co-Guest Editor

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 100 words) can be sent to the Editorial Office for announcement on this website.

Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-blind peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Energies is an international peer-reviewed open access semimonthly journal published by MDPI.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2600 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

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Published Papers (13 papers)

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Editorial

Jump to: Research

3 pages, 164 KiB

Open AccessEditorial

Advances in Oil and Gas Production: A Viewpoint

by Valentin Morenov

Energies 2023, 16(3), 1379; https://doi.org/10.3390/en16031379 - 30 Jan 2023

Cited by 1 | Viewed by 1302

Abstract

Nowadays, there is a global trend towards “green” industry, which implies the reduction in carbon emissions from various industrial processes [...] Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

Research

Jump to: Editorial

20 pages, 3941 KiB

Open AccessArticle

Salt Deposits and Brine Blowout: Development of a Cross-Linking Composition for Blocking Formations and Methodology for Its Testing

by Mikhail Dvoynikov, Dmitry Sidorov, Evgeniy Kambulov, Frederick Rose and Rustem Ahiyarov

Energies 2022, 15(19), 7415; https://doi.org/10.3390/en15197415 - 9 Oct 2022

Cited by 13 | Viewed by 2245

Abstract

Uncontrolled inflow of formation fluid (brine) into a well adversely affects the cation–anion bonds in solutions and leads to their dissociation and loss of aggregative stability. Blow-out significantly complicates the drilling process and leads to an increase in non-productive time and in financial costs for problem solving. It is necessary to create a blocking screen that allows separation of the layer from the well and prevents brine flow. This article is devoted to the development of polymeric-blocking compositions that work due to the crystallization reaction of divalent salts of calcium and magnesium chlorides. More than 14 components were detected in the formation fluid on the atomic emission spectrometer. Based on the study of the compatibility of components with brine and the study of rheology and filtration processes through a real core under HPHT conditions, the optimal component polymer composition was selected. The reason for the increase in the rheology of composition during its thickening was established. With the help of tomographic studies, the depth of penetration of the filtrate into the core of layers was determined. For further studies, an experimental stand was designed for physical simulation of the isolation process under HPHT conditions and backpressure from the formation. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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23 pages, 6823 KiB

Open AccessArticle

Development of Monitoring and Forecasting Technology Energy Efficiency of Well Drilling Using Mechanical Specific Energy

by Andrey Kunshin, Mikhail Dvoynikov, Eduard Timashev and Vitaly Starikov

Energies 2022, 15(19), 7408; https://doi.org/10.3390/en15197408 - 9 Oct 2022

Cited by 14 | Viewed by 2197

Abstract

This article is devoted to the development of technology for improving the efficiency of directional well drilling by predicting and adjusting the system of static and dynamic components of the actual weight on the bit, based on the real-time data interpretation from telemetry sensors of the bottom hole assembly (BHA). Studies of the petrophysical and geomechanical properties of rock samples were carried out. Based on fourth strength theory and the Palmgren–Miner fatigue stress theory, the mathematical model for prediction of effective distribution of mechanical specific energy, using machine learning methods while drilling, was developed. An algorithm was set for evaluation and estimation of effective destruction of rock by comparing petrophysical data in the well section and predicting the shock impulse of the bit. Based on the theory provided, it is assumed that the given shock impulse is an actual representation of an excessive energy, conveyed to BHA. This excessive energy was quantitively determined and expressed as an adjusting coefficient for optimal weight on bit. The developed mathematical and predictive model helps to identify the presence of ineffective rock destruction and adjust drilling regime accordingly. Several well drilling datasets from the North Sea were analyzed. The effectiveness of the developed mathematical model and algorithms was confirmed by testing well drilling data. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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10 pages, 2090 KiB

Open AccessArticle

Effect of Temperature Conditions in Arctic Offshore Oil Fields on the Rheological Properties of Various Based Drilling Muds

by Ekaterina Leusheva and Valentin Morenov

Energies 2022, 15(15), 5750; https://doi.org/10.3390/en15155750 - 8 Aug 2022

Cited by 6 | Viewed by 1989

Abstract

During well drilling in offshore conditions beyond the North of the Arctic Circle, there are often problems associated with deviations in the rheological parameters of the drilling mud as the temperature changes. Mud temperature in the upper part of the well in most cases is in the range up to 20 °C, whereas in the productive formation it is up to 80 °C and more. For such conditions, it is necessary to estimate the influence of temperature on the rheological parameters of drilling fluids, which is done in this paper. Compositions of water-based and hydrocarbon-based muds that may be used in the conditions of the offshore hydrocarbon fields were considered. The paper presents the authors’ formula for a drilling mud that possesses more stable rheological parameters in the temperature conditions of the offshore oil field and is more environmentally friendly. The physical properties of the newly designed drilling mud were measured with laboratory equipment. Rheological investigations were carried out under varying temperatures up to 80 °C. The results of the experiments show the newly designed drilling mud to be more stable than its hydrocarbon-based analogue. Besides, the newly developed composition has a lower content of solid phase, which is also an important parameter for the process of sea wells construction, often characterized by a narrow window of permissible pressure. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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13 pages, 2562 KiB

Open AccessArticle

A Numerical Study on the Application of Stress Cage Technology

by Pouya Abdollahpour, Seyyed Shahab Tabatabaee Moradi, Ekaterina Leusheva and Valentin Morenov

Energies 2022, 15(15), 5439; https://doi.org/10.3390/en15155439 - 27 Jul 2022

Cited by 8 | Viewed by 2014

Abstract

Lost circulation is considered a time-consuming, costly problem during the construction of oil and gas wells. There are several preventive techniques to mitigate this problem. Stress cage technology is a mechanical lost circulation method, in which the formation at the wellbore wall is strengthened to stop the creation of induced fractures as one of the main causes of lost circulation. In this research, a two-dimensional numerical model, considering the elastic, poro-elastic, and thermo-poro-elastic behavior of the rock, is built to investigate the effectiveness of the stress cage method. Results show that better performance of the technology is achieved if the fractures are bridged close to their apertures. Additionally, it was found that the difference between the elastic, poro-elastic, and thermo-poro-elastic models is slightly visible. The conclusion states that the application of the stress cage methods leads to an increase in hoop stress and subsequent formation fracture gradient. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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13 pages, 3026 KiB

Open AccessArticle

Modeling Results for the Real Horizontal Heavy-Oil-Production Well of Mechanical Solids

by Aleksey Dengaev, Vladimir Shishulin, Elena Safiullina and Aleksandra Palyanitsina

Energies 2022, 15(14), 5182; https://doi.org/10.3390/en15145182 - 17 Jul 2022

Cited by 4 | Viewed by 1593

Abstract

Recently, more and more new oil fields entering commercial production are complicated by the content of high-viscosity products, which are located at relatively shallow depths. For the rational development of such fields, a network of horizontal wells is used. A special feature of these objects is a weakly cemented reservoir, which leads to significant sand occurrence during well operation. At the same time, the removal of mechanical impurities cannot be avoided even when using complex measures, including the use of various filters. There are quite a few methods describing the behavior of mechanical impurities in gas–liquid flows. The purpose of the work was to analyze the removal of mechanical impurity particles from horizontal wells with high-viscosity oil. A model of a typical well in the OLGA software was created, and data on the types of particle removal were obtained. As a result of calculations, the quality of removal for different diameters of mechanical impurities was determined, and the dependence of the critical diameter on the well flow rate was constructed. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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13 pages, 2852 KiB

Open AccessArticle

Substantiation of In Situ Water Shut-Off Technology in Carbonate Oil Reservoirs

by Artem Shagiakhmetov and Svetlana Yushchenko

Energies 2022, 15(14), 5059; https://doi.org/10.3390/en15145059 - 11 Jul 2022

Cited by 14 | Viewed by 1990

Abstract

The efficient development of carbonate oil deposits with excessive fissuring is a current challenge. Uneven and rapid well stream watering is considered as one of the factors that make the process of the development of carbon deposits more complicated. The purpose of the research is to diagnose and evaluate the mechanisms of well stream watering for carbon deposits and find applicable technology to prevent it. An overview of in situ water shut-off technologies was carried out. A description of the main materials used for water shut-off is presented, and selective methods are studied in more detail. A carbonate basin of an oil field is selected as the object of investigation. The geological and physical characteristics of this deposit are given. Analysis of possible causes and sources of water cut of the fluid is made according to the technique of K.S. Chan, under which the main reason for the watering of the well production is the breakthrough of formation and injection water through a system of highly permeable natural fractures and channels. Matrixes of applicability of in situ water shut-off technologies and polymer compositions are made. The composition based on carboxymethyl cellulose for in situ water shut-off is selected for the chosen deposit. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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13 pages, 6616 KiB

Open AccessArticle

The Rod String Loads Variation during Short-Term Annular Gas Extraction

by Alexander Vladimirovich Artyukhov, Anatoliy Andreevich Isaev, Alexander Nikolaevich Drozdov, Yana Alekseevna Gorbyleva and Karina Shamilyevna Nurgalieva

Energies 2022, 15(14), 5045; https://doi.org/10.3390/en15145045 - 11 Jul 2022

Cited by 6 | Viewed by 1394

Abstract

This paper highlights field studies to determine the nature of variations in the load on the sucker-rod string during short-term gas extraction from the wellbore annulus. The results of step-by-step gas extraction from the annular spaces of the wells of fields developed by PJSC TATNEFT are provided. In the course of investigations, we have obtained both the trends of maximum and minimum loads on the polished rod during annular gas extraction, and the dependence of maximum load increment on the rod string with respect to pump size and pressure variation in the annular space. The analysis of the research data resulted in the elaboration of guidelines for short-term extraction of annular gas from wells operated by the PCP units. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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17 pages, 4374 KiB

Open AccessArticle

Experimental Evaluation of the Multiphase Flow Effect on Sand Production Process: Prepack Sand Retention Testing Results

by Dmitry Tananykhin, Maxim Grigorev, Maxim Korolev, Timur Solovyev, Nikolay Mikhailov and Mark Nesterov

Energies 2022, 15(13), 4657; https://doi.org/10.3390/en15134657 - 25 Jun 2022

Cited by 13 | Viewed by 2031

Abstract

This paper considers a field with high-viscosity oil in a terrigenous weakly consolidated reservoir (sandstone) with a massive gas cap and an aquifer. The major challenge in the field operation is the migration of solid sand particles into the well, accompanied by a breakthrough of water and/or gas. The goal of the investigation was to evaluate the degree of influence on the sanding process of water and gas shares in the produced fluid and to determine the effect of pressure drop. The research methodology is based on a series of filtration experiments on small-sized bulk reservoir models. Particle size distribution of bulk models was created in accordance with that of the reservoir. The experiments were made in the form of Prepack Sand Retention Tests (SRT). Gas breakthrough allows sand production on a relatively high level for a longer amount of time, even though the concentration of solids in the produced fluid is lower than that of water breakthrough. On the other hand, water breakthrough triggers higher sand production, but it rapidly decreases as time goes on. Retained permeability of the model-screen system from the drawdown pressure (pressure gradient) and phase distribution of the flow were investigated. Moreover, a methodology has been developed for conducting filtration tests on bulk reservoir models to evaluate the efficiency of different screens (wire-wrapped screens, in particular). Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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18 pages, 4180 KiB

Open AccessArticle

Facilities Construction Engineering for the Avaldsnes Section of the Johan Sverdrup Field in the North Sea

by Diana Lvova, Artem Shagiakhmetov, Boris Seregin and Aleksey Vasiliev

Energies 2022, 15(12), 4388; https://doi.org/10.3390/en15124388 - 16 Jun 2022

Cited by 6 | Viewed by 1904

Abstract

The object of this article is to define the facilities construction for the Avaldsnes section of the Johan Sverdrup field in the North Sea. Based on the experiences of oil and gas companies, the applicability of various offshore oil and gas field structures will be analyzed. According to the results, the most relevant field facilities scenarios were formed. Each scenario was technically and economically assessed. The technical assessment consisted of the evaluation of loads under the different climate conditions on the offshore oil and gas facility, along with resistance against overturning and sliding. The economic assessment included the calculation of the key economic indicators of various scenarios and comparing them. The integrated assessment indicated that the combination of several subsea production modules is the most cost-effective field facilities scenario to implement in the Avaldsnes area of the Johan Sverdrup field in the North Sea. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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14 pages, 2573 KiB

Open AccessArticle

Improving the Efficiency of Curved Wells’ Operation by Means of Progressive Cavity Pumps

by Anatoliy Andreevich Isaev, Mekhrali Mirzali Ogly Aliev, Alexander Nikolaevich Drozdov, Yana Alekseevna Gorbyleva and Karina Shamilyevna Nurgalieva

Energies 2022, 15(12), 4259; https://doi.org/10.3390/en15124259 - 9 Jun 2022

Cited by 13 | Viewed by 2478

Abstract

This paper proposes a solution to the problem of improving the reliability of the operation of progressive cavity pump units in deviated and directional wells. High dogleg severity significantly contributes to rod breakage; rods often break close to the “elbows” with a dogleg severity of 2 deg/10 m or higher. Statistical analyses were used to identify the frequency of failures and their impact on the reliability of a PCP unit. The design layout and mathematical model for pump rods’ torsional vibrations in the curved section of a wellbore were developed. A simulation of the curved section was performed. This article provides the basic formulas needed to design a rotating rod string using two reduced discs. The creation of an additional crooked section resulted in multiple reductions in the “resonant” rotational speed and rigidity in the mathematical model. Determining the moment of inertia of the reduced discs’ mass made it possible to determine the sucker-rod string’s stiffness, the circular rotation frequency, and the number of sucker-rod revolutions under resonance. The number of reduced discs on the sucker-rod string depends on the curvature pattern. In summary, a centralizer for a rotating string was designed to reduce the vibration and shock effects of rods on the tubing. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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19 pages, 7983 KiB

Open AccessArticle

A Three-Dimensional Finite-Element Model in ABAQUS to Analyze Wellbore Instability and Determine Mud Weight Window

by Mohammad Javad Bozorgi, Masoud Parham, Omeid Rahmani, Ali Piroozian, Haylay Tsegab Gebretsadik and Syed Muhammad Ibad

Energies 2022, 15(9), 3449; https://doi.org/10.3390/en15093449 - 9 May 2022

Cited by 2 | Viewed by 3792

Abstract

Wellbore instability is one of the main problems of the oil industry, causing high costs in the drilling operation. Knowing about the mechanical properties of involved formations and in-situ stresses is a privilege gained by determining an appropriate mud weight window (MWW). To this aim, a three-dimensional (3D) finite-element model was simulated in ABAQUS to analyze in-situ stresses and determine the MWW in the drilling operation of wellbore-D in the Azar oilfield. The results from the 3D finite model revealed that the Azar oilfield is structurally under the impact of a complex tectonic system dominated by two reverse faults with a configuration of σ_H > σ_h > σ_v across the Sarvak Formation. The amount of vertical, minimum, and maximum horizontal stresses was 90.15, 90.15, and 94.66 MPa, respectively, at a depth of 4 km. Besides, the amount of pore pressure and its gradient was 46 MPa and 11.5 MPa/km, respectively. From drilling wellbore-D in the direction of the maximum horizontal stress, the lower limit of the MWW was obtained at 89 pcf. In this case, the results showed that the wellbore with a deviation angle of 10° is critical with a mud weight lower than 89 pcf. It caused the fall of the wellbore wall within the plastic zone sooner than other deviation angles. Also, in the case of drilling wellbore in the direction of minimum horizontal stress, the lower limit of the MWW was 90.3 pcf. Moreover, in the deviation angle of approximately 90°, the wellbore wall remained critical while the mud weight was below 90.3 pcf. Comparison of the results of numerical and analytical modeling showed that the modeling error falls within an acceptable value of < 4%. As a result, the wellbore with the azimuth of the maximum horizontal stress needed less mud weight and decreased the drilling costs. This particular research finding also provides insights for obtaining the lower limit of the mud weight window and determining the optimal path of the well-bore when using directional drilling technology. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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13 pages, 4328 KiB

Open AccessArticle

Research on Conductivity Damage Based on Response Surface Analysis

by Yuan Pan, Ze Yang, Yuting Pan, Yiwen Xu and Ruiquan Liao

Energies 2022, 15(8), 2818; https://doi.org/10.3390/en15082818 - 12 Apr 2022

Cited by 1 | Viewed by 1470

Abstract

Hydraulic fracturing is an important means of developing unconventional oil and gas layers. The fracture conductivity of tight sandstone reservoirs after fracture is affected by many factors, such as the interaction between the fracturing fluid, water, and rocks; the fracturing materials; and the construction parameters. This paper improves the experimental process of the long-term conductivity test and provides insight into conductivity prediction and optimization based on the response surface test method. The test process is conducted in the following manner: (1) inject nitrogen to evaluate the fracture conductivity before fracturing fluid damage; (2) inject fracturing fluid to simulate shut-in; and (3) inject nitrogen again to evaluate fracture conductivity after the damage ability of the fracturing fluid. The single factor test results show that the lower the sand concentration is, the higher the fracturing fluid viscosity will be, and the longer the fracturing fluid retention time is, the greater the damage to the conductivity of the fracturing fluid will be. The response surface test results show that the order of factors affecting the retention of conductivity is fracturing fluid viscosity > sand concentration > fracturing fluid retention time. There is a certain interaction between sand concentration and fluid viscosity, and there is also a certain interaction between fluid viscosity and fluid retention time, but these interactions are not significant; when the fracturing fluid retention time is longer, there will be an interaction between the sand concentration and the fracturing fluid retention time. In addition, based on the model used to optimize the fracturing construction parameters from the perspective of proppant conductivity damage, the optimal solution is when the viscosity of the fracturing fluid is 1 mPa.s, the paved-sand content is 8.49 kg/m², and the retention time of the fracturing fluid is 10 h. The maximum retention rate of the flow conductivity is 63.19%. Full article

(This article belongs to the Special Issue Advances in Techniques of Construction, Development and Operation of Oil and Gas Wells)

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