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Advances in Petroleum Exploration and Production

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

Deadline for manuscript submissions: closed (31 July 2023) | Viewed by 29229

Special Issue Editors

Prof. Dr. Mohamed Mahmoud

E-Mail Website
Guest Editor
Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi Arabia
Interests: petroleum engineering; well stimulationformation damage; enhanced oil recovery; drilling fluids; modeling of hole cleaning during drilling deviated and horizontal wells; multiphase flow in vertical and horizontal wells
Special Issues, Collections and Topics in MDPI journals
Dr. Zeeshan Tariq

E-Mail Website
Guest Editor
Ali I. Al-Naimi Petroleum Engineering Research Center, Physical Science and Engineering Division, King Abdullah University of Science and Technology (KAUST), Thuwal 23955-6900, Saudi Arabia
Interests: machine learning; geomechanics; hydraulic fracturing; petrophysics

Special Issue Information

Dear Colleagues,

Guest Editors Prof. Mohamed A. Mahmoud and Dr. Zeeshan Tariq invite the submission of original high-quality research articles to a Special Issue of Energies on the “Advances in Petroleum Exploration and Production”. This Special Issue on petroleum exploration and production will cover a broad range of topics concerning petroleum exploration, reservoir characterization, machine learning applications, well logging, and geological aspects on both conventional and unconventional oil and gas systems, and approach those topics from both an exploration and a production standpoint. The Special Issue will publish high-quality original research work, such as numerical, analytical, and experimental papers.

High-quality papers that explore these areas and provide emerging solutions and visions for future research activities are sought. Theoretical and empirical studies, as well as state-of-the-art reviews, are welcome. Prospective authors are invited to submit manuscripts for review for publication in this Special Issue.

The scope of the Special Issue includes, but is not limited to:

  1. Unconventional resources related to exploration;
  2. Exploration and development of unconventional resources;
  3. Formation evaluation;
  4. Well logging;
  5. Reservoir characterization;
  6. AI and ML in reservoir petrophysical evaluation;
  7. Advanced data analytics and analysis in petrophysics;
  8. Machine learning oriented for reservoir characterization;
  9. Geological facies prediction;
  10. Scale inhibition;
  11. Flow assurance;
  12. Production management;
  13. Surface network simulation;
  14. AI and data analytics in production operations;
  15. Sand control and management.

Prof. Dr. Mohamed Mahmoud
Dr. Zeeshan Tariq
Guest Editors

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.

Keywords

  • unconventional resources
  • formation evaluation
  • well logging
  • reservoir characterization
  • artificial intelligence
  • machine learning
  • advanced data analytics
  • geological facies prediction
  • scale inhibition
  • flow assurance
  • production management
  • surface network simulation
  • sand control and management

Published Papers (19 papers)

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19 pages, 5473 KiB  
Article
Establishment and Application of a Pattern for Identifying Sedimentary Microfacies of a Single Horizontal Well: An Example from the Eastern Transition Block in the Daqing Oilfield, Songliao Basin, China
by Guangjuan Fan, Ting Dong, Yuejun Zhao, Yalou Zhou, Wentong Zhao, Jie Wang and Yilong Wang
Energies 2023, 16(20), 7053; https://0-doi-org.brum.beds.ac.uk/10.3390/en16207053 - 12 Oct 2023
Viewed by 620
Abstract
The study of sedimentary microfacies of horizontal wells is important for improving oil recovery using horizontal well technology. Vertical well data alone do not provide accurate enough information to determine the sedimentary microfacies of horizontal wells. Therefore, a comprehensive method combining the data [...] Read more.
The study of sedimentary microfacies of horizontal wells is important for improving oil recovery using horizontal well technology. Vertical well data alone do not provide accurate enough information to determine the sedimentary microfacies of horizontal wells. Therefore, a comprehensive method combining the data of both horizontal and vertical wells was established to identify sedimentary microfacies of horizontal wells and applied to a single horizontal well in the Daqing oilfield in China’s Songliao Basin. The results identified the study area as a delta sedimentary environment, mainly subdivided into four microfacies types: a distributary channel, the main overbank sand, the overbank sand, and an interdistributary bay. The criteria for identifying each sedimentary microfacies were established. Among them, the criteria for identifying distributary channels include a natural gamma value continuously less than 90 API; a resistivity value continuously greater than 11 Ω·m; a logging curve, which is typically bell-shaped or box-shaped with very high amplitude and amplitude difference; a mainly siltstone lithology; and a total hydrocarbon content (Tg) continuously greater than 3%. The variations in the two types of channel boundaries (narrowing of the channel boundary and reverse extension of the bifurcated channel boundary) were corrected. The research results can provide guidance for the efficient development of favorable reservoirs in oilfields using horizontal well technology. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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15 pages, 10915 KiB  
Article
A Numerical Study on Labyrinth Screw Pump (LSP) Performance under Viscous Fluid Flow
by Wenqi Ke, Hao Zeng, Zhuoyu Wang, Hong Yu, Yaxin Liu, Danzhu Zheng, Jianjun Zhu and Haiwen Zhu
Energies 2023, 16(16), 5997; https://0-doi-org.brum.beds.ac.uk/10.3390/en16165997 - 16 Aug 2023
Cited by 5 | Viewed by 847
Abstract
In this study, fluid viscosity effects on LSP performance in terms of boosting pressure were numerically investigated. A water–glycerin mixture with different concentrations corresponding to varying apparent viscosities was flowed through an in-house manufactured LSP under various flow conditions, e.g., changing flow rates, [...] Read more.
In this study, fluid viscosity effects on LSP performance in terms of boosting pressure were numerically investigated. A water–glycerin mixture with different concentrations corresponding to varying apparent viscosities was flowed through an in-house manufactured LSP under various flow conditions, e.g., changing flow rates, rotational speeds, and fluid viscosities. The pressure increment between the intake and discharge of the LSP was recorded using the differential pressure transducer. The same pump geometries, fluid properties and flow conditions were incorporated into the numerical configurations, where three-dimensional (3D), steady-state, Reynolds-averaged Navier–Stokes (RANS) equations with a standard SST (shear stress transport) turbulence model were solved by a commercial CFD code. With the high-quality poly-hexcore grids, the simulated pressure increment was compared with the corresponding experimental measurement. The internal flow structures and characteristics within the cavities contained by the LSP impeller and diffuser were also analyzed. The good agreement between the numerical results against the experimental data verified the methodology adopted in this study. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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13 pages, 2433 KiB  
Article
Experimental Investigation on the Relationship between Biot’s Coefficient and Hydrostatic Stress for Enhanced Oil Recovery Projects
by Mohammad Ahmad Mahmoudi Zamani and Dariusz Knez
Energies 2023, 16(13), 4999; https://0-doi-org.brum.beds.ac.uk/10.3390/en16134999 - 27 Jun 2023
Cited by 5 | Viewed by 853
Abstract
The majority of global conventional oil reservoirs have been dramatically depleted during the last few decades. To increase the oil production rate, enhanced oil recovery (EOR) techniques are commonly utilized. The ratio of the recovered oil volume to the rock volume change is [...] Read more.
The majority of global conventional oil reservoirs have been dramatically depleted during the last few decades. To increase the oil production rate, enhanced oil recovery (EOR) techniques are commonly utilized. The ratio of the recovered oil volume to the rock volume change is defined as Biot’s coefficient. During the EOR operations, Biot’s coefficient continuously changes due to the fluid injection and oil production; however, so far, only porosity-dependent or constant values of Biot’s coefficient have been incorporated in the EOR calculations, which is not valid since the role of external stress changes is overlooked. In this research, the Biot’s coefficient of a sandstone formation was measured through the acoustic wave propagation technique. A stress-dependent equation of Biot’s coefficient was achieved for application in the EOR calculations. The findings illustrated that Biot’s coefficient decreases logarithmically with the hydrostatic stress. Moreover, the Biot’s coefficient varied from 0.52 to 0.60 for an applied hydrostatic stress of 3.50 MPa to 21 MPa. Furthermore, it was found that there was no anisotropy of Biot’s coefficient in the sandstone formations. The extracted empirical correlation can be utilized for EOR projects in which the recovered oil volume is of paramount importance economically. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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24 pages, 1088 KiB  
Article
Optimisation of a Gas-Lifted System with Nonlinear Model Predictive Control
by Ojonugwa Adukwu, Darci Odloak and Fuad Kassab, Jr.
Energies 2023, 16(7), 3082; https://0-doi-org.brum.beds.ac.uk/10.3390/en16073082 - 28 Mar 2023
Viewed by 1060
Abstract
A gas-lifted system in a mature oil well can experience casing-heading instability, which reduces the mean oil production and it is not healthy for the downstream equipment. This instability was removed by implementing a terminal equality-constrained nonlinear model predictive control (NMPC) having input [...] Read more.
A gas-lifted system in a mature oil well can experience casing-heading instability, which reduces the mean oil production and it is not healthy for the downstream equipment. This instability was removed by implementing a terminal equality-constrained nonlinear model predictive control (NMPC) having input targets with control zones in the system. The input-dependent stability behaviour of the gas-lifted system was visualised through the bifurcation diagram and the step responses of the linearised model at various operating points. The controller was then presented. Then, the close-loop feasibility, as well as the convergence, were discussed. The controller stabilised the undisturbed gas-lifted system, improving production by 5.63% compared to the open-loop operation when the system was in casing-heading instability. For the two input case, the steady-state production, aided by the high-input target, reached 12.25 kg/s, which was far more than 9.57 kg/s for the one input case. This controller showed a 3.76% improvement over the PI controller for the same purpose. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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15 pages, 5799 KiB  
Article
An Artificial Lift Selection Approach Using Machine Learning: A Case Study in Sudan
by Mohaned Alhaj A. Mahdi, Mohamed Amish and Gbenga Oluyemi
Energies 2023, 16(6), 2853; https://0-doi-org.brum.beds.ac.uk/10.3390/en16062853 - 19 Mar 2023
Cited by 1 | Viewed by 2029
Abstract
This article presents a machine learning (ML) application to examine artificial lift (AL) selection, using only field production datasets from a Sudanese oil field. Five ML algorithms were used to develop a selection model, and the results demonstrated the ML capabilities in the [...] Read more.
This article presents a machine learning (ML) application to examine artificial lift (AL) selection, using only field production datasets from a Sudanese oil field. Five ML algorithms were used to develop a selection model, and the results demonstrated the ML capabilities in the optimum selection, with accuracy reaching 93%. Moreover, the predicted AL has a better production performance than the actual ones in the field. The research shows the significant production parameters to consider in AL type and size selection. The top six critical factors affecting AL selection are gas, cumulatively produced fluid, wellhead pressure, GOR, produced water, and the implemented EOR. This article contributes significantly to the literature and proposes a new and efficient approach to selecting the optimum AL to maximize oil production and profitability, reducing the analysis time and production losses associated with inconsistency in selection and frequent AL replacement. This study offers a universal model that can be applied to any oil field with different parameters and lifting methods. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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19 pages, 13674 KiB  
Article
Drainage Research of Different Tubing Depth in the Horizontal Gas Well Based on Laboratory Experimental Investigation and a New Liquid-Carrying Model
by Xiuwu Wang, Wenmin Ma, Wei Luo and Ruiquan Liao
Energies 2023, 16(5), 2165; https://0-doi-org.brum.beds.ac.uk/10.3390/en16052165 - 23 Feb 2023
Viewed by 1468
Abstract
Since the structure of horizontal gas wells is more intricate than that of vertical wells, there is a lack of consistency in the form of liquid-carrying in different portions. Applying the commonly utilized liquid-carrying hypothesis of vertical gas wells into horizontal gas wells [...] Read more.
Since the structure of horizontal gas wells is more intricate than that of vertical wells, there is a lack of consistency in the form of liquid-carrying in different portions. Applying the commonly utilized liquid-carrying hypothesis of vertical gas wells into horizontal gas wells is therefore challenging. The maximum liquid volume that the gas flow could raise, the gas flow rate, and the maximum amount of energy that could be produced from a specific amount of gas flow should all be considered when determining the liquid volume that the gas flow could lift. This study is the first to integrate theoretical analysis with laboratory testing to analyze the gas–liquid flow law of drainage stability at varied tubing depths. The impact of gas drainage stability is then verified through the laboratory experiments. The novel model of various tubing depths, which is based on the energy of inflow and outflow from the horizontal well, is cleverly built. According to the study, the fluctuation is typically less when the tubing reaches the heel of the horizontal section than it is in the other sections, and the relative error of the new model, which is validated using laboratory tests, is typically less than 10%. The research showed that for horizontal gas wells with a normal structure, the gas flow and liquid discharge are most stable when the tubing reaches the heel of the horizontal section. Instead of depending exclusively on crucial liquid-carrying gas flow rates, the new model uses the combination of gas and liquid flow rates to make decisions concerning liquid loading and to quantify the liquid removal in real time, which is more realistic. The research illustrates how the study could provide a factual basis for assessing the capacity of horizontal gas wells to raise the liquid. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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23 pages, 4591 KiB  
Article
Stable Carbon Isotopic Composition of Selected Alkylnaphthalenes and Alkylphenanthrenes from the Tarim Oilfields, NW China
by N’Guessan Francois De Sales Konan, Meijun Li, Shengbao Shi, Amoako Kojo, Abdulkareem Toyin, Nancy Pearl Osei Boakye and Tiantian Li
Energies 2022, 15(19), 7145; https://0-doi-org.brum.beds.ac.uk/10.3390/en15197145 - 28 Sep 2022
Cited by 4 | Viewed by 1025
Abstract
The present study aimed firstly to use a set of crude oil samples and a dataset to provide new evidence for source input contribution in selected aromatic isomers for discrimination of oils from three oilfields from Tarim Basin and identify the key factor [...] Read more.
The present study aimed firstly to use a set of crude oil samples and a dataset to provide new evidence for source input contribution in selected aromatic isomers for discrimination of oils from three oilfields from Tarim Basin and identify the key factor (s) controlling the isotope composition. Thus, the present research showed that the δ13C values of alkylnaphthalenes and alkylphenanthrenes plotted against P/DBT and Ga/C30H ratios is a reliable and convenient tool for discrimination of organic matter variations in different oilfields. More importantly, molecular ratios and different diagram plots revealed that the selected oil samples would be derived from a mixing of indigenous organic matter from the terrestrial (in Kuqa area) and marine (in the cratonic area) depositional environments prior the apparition of the Yakela Faulted Uplift. Thus, Daolaoba, Yakela, and Tahe oils were made up of organic materials from both marine and terrestrial sources. Furthermore, marine organic matter input dominates oils from the Tahe and Yakela, with a minor input from terrestrial sources. The oils from Daolaoba were assigned to be from a mixing of marine and terrestrial material inputs. The controlling factors assessment revealed that biodegradation has an insignificant effect on the set of oils; however, the source input and the thermal maturity together control the isotopic compositions of individual aromatic isomers from these three oilfields. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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16 pages, 1405 KiB  
Article
Economical Optimum Gas Allocation Model Considering Different Types of Gas-Lift Performance Curves
by Haiquan Zhong, Chengjie Zhao, Zhiyu Xu and Chuangen Zheng
Energies 2022, 15(19), 6950; https://0-doi-org.brum.beds.ac.uk/10.3390/en15196950 - 22 Sep 2022
Viewed by 1244
Abstract
The traditional optimum modes of gas-lift production are usually established by taking the injected gas rate as a decision variable and maximum oil production as the objective function. After solving the model, the injected gas rates of single wells are obtained, and then [...] Read more.
The traditional optimum modes of gas-lift production are usually established by taking the injected gas rate as a decision variable and maximum oil production as the objective function. After solving the model, the injected gas rates of single wells are obtained, and then the oil productions of single wells, the total oil productions of well groups and economic profit can be obtained. However, the models do not take both different types of gas-lift performance curves (GLPCs) and the cost factors of gas-lift production technique into account. On the basis of GLPCs, this paper introduces the factors of a gas-lift production technique, which includes the water cut of crude oil, cost of gas injection and water treatment, and oil and gas prices. The concept of a gas-lift economic performance curve (GLEPC) is proposed, and an optimum gas allocation model is established, considering different types of GLPCs and taking economic benefits as the objective, and the model is solved by the method of mixed penalty function. Taking gas-lift well group JD as an example, four gas-lift gas allocation schemes are obtained, and the proposed economical optimum model is applied to optimize gas allocation and analyze profit. What is more, the oil production rate and the result of optimum gas allocation taking maximum oil production rate as the objective in the model are calculated and compared. Then the gas allocation scheme with maximum economical profit is selected, and the significance of considering different types of GLPCs and taking economic benefits as the objective to gas allocation is confirmed. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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15 pages, 5326 KiB  
Article
Kinematic and Dynamic Simulation Analysis of Modified Conventional Beam Pumping Unit
by Jinchao Xu, Wei Li and Siyuan Meng
Energies 2022, 15(15), 5496; https://0-doi-org.brum.beds.ac.uk/10.3390/en15155496 - 29 Jul 2022
Cited by 1 | Viewed by 1247
Abstract
The large net torque fluctuations in the reducer output shafts of conventional beam pumping units and the existence of negative torque are the decisive factors that lead to their low efficiency and high energy consumption. This study developed a positive torque modulation scheme [...] Read more.
The large net torque fluctuations in the reducer output shafts of conventional beam pumping units and the existence of negative torque are the decisive factors that lead to their low efficiency and high energy consumption. This study developed a positive torque modulation scheme for conventional beam pumping units, which was based on the principle of the follow-up secondary balance of the connecting rod. The CYJ10-4.2-53HF conventional beam pumping unit was selected as the research object. The kinematic and dynamic simulation analysis of the modified pumping unit was carried out using ADAMS software. The results showed that secondary balance torque curves could realize the function of “peak cutting and valley filling” for the curves after the primary balance and that the modified pumping unit could achieve a full-cycle positive value for the reducer output shaft and verify the feasibility of our modulation scheme. A secondary balance offset angle of 315° was the best choice as the amplitude of the torque curve clearly increased and the phase remained basically the same when the radius of the mass center of the secondary balance increased. Therefore, when the offset angle value of the secondary balance weight was determined, the radius of the mass center could be changed by adjusting the position of the secondary balance weight to achieve the balance adjustment. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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18 pages, 5340 KiB  
Article
Effect of Comb-Type Copolymers on the Non-Isothermal Crystallization Behavior of Paraffin in Methyl Ethyl Ketone (MEK)–Toluene Dewaxing
by Ying Xiong, Xinyao Nie, Zheng Wang, Hongyang Li, Yueqin Song, Jinan Wang, Xiaolong Zhou and Lifang Chen
Energies 2022, 15(11), 3989; https://0-doi-org.brum.beds.ac.uk/10.3390/en15113989 - 28 May 2022
Viewed by 1499
Abstract
Two comb-type copolymers were synthesized by modifications of the maleic anhydride-α-octadecene copolymer with aniline (AMAC) and with phenethylamine (EMAC), respectively. The effects of AMAC and EMAC on the non-isothermal crystallization kinetics of the MEK–toluene dewaxing process were comparatively investigated. The results showed that, [...] Read more.
Two comb-type copolymers were synthesized by modifications of the maleic anhydride-α-octadecene copolymer with aniline (AMAC) and with phenethylamine (EMAC), respectively. The effects of AMAC and EMAC on the non-isothermal crystallization kinetics of the MEK–toluene dewaxing process were comparatively investigated. The results showed that, under the optimum process conditions, the addition of 100 ppm AMAC or EMAC could increase the yield of dewaxed oil (DWO) from 67.21% to 70.87% or 69.90%, respectively, and increase the filtration rate by 80% and 70%, respectively. The non-isothermal crystallization kinetics analysis showed that the crystallization process conformed to Mo’s equation, and the addition of AMAC and EMAC slowed down the crystallization rate of paraffin. The polarizing light microscope observations revealed that the addition of AMAC promoted the formation of snow flower-like crystals, and the EMAC addition led to the crystals having longer rods with a relatively complete morphology. This work provided useful experimental data for a better understanding of the roles of comb-type copolymer additives in the MEK–toluene dewaxing process. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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15 pages, 6555 KiB  
Article
Well-Logging-Based Lithology Classification Using Machine Learning Methods for High-Quality Reservoir Identification: A Case Study of Baikouquan Formation in Mahu Area of Junggar Basin, NW China
by Junlong Zhang, Youbin He, Yuan Zhang, Weifeng Li and Junjie Zhang
Energies 2022, 15(10), 3675; https://0-doi-org.brum.beds.ac.uk/10.3390/en15103675 - 17 May 2022
Cited by 10 | Viewed by 2740
Abstract
The identification of underground formation lithology is fundamental in reservoir characterization during petroleum exploration. With the increasing availability and diversity of well-logging data, automated interpretation of well-logging data is in great demand for more efficient and reliable decision making for geologists and geophysicists. [...] Read more.
The identification of underground formation lithology is fundamental in reservoir characterization during petroleum exploration. With the increasing availability and diversity of well-logging data, automated interpretation of well-logging data is in great demand for more efficient and reliable decision making for geologists and geophysicists. This study benchmarked the performances of an array of machine learning models, from linear and nonlinear individual classifiers to ensemble methods, on the task of lithology identification. Cross-validation and Bayesian optimization were utilized to optimize the hyperparameters of different models and performances were evaluated based on the metrics of accuracy—the area under the receiver operating characteristic curve (AUC), precision, recall, and F1-score. The dataset of the study consists of well-logging data acquired from the Baikouquan formation in the Mahu Sag of the Junggar Basin, China, including 4156 labeled data points with 9 well-logging variables. Results exhibit that ensemble methods (XGBoost and RF) outperform the other two categories of machine learning methods by a material margin. Within the ensemble methods, XGBoost has the best performance, achieving an overall accuracy of 0.882 and AUC of 0.947 in classifying mudstone, sandstone, and sandy conglomerate. Among the three lithology classes, sandy conglomerate, as in the potential reservoirs in the study area, can be best distinguished with accuracy of 97%, precision of 0.888, and recall of 0.969, suggesting the XGBoost model as a strong candidate machine learning model for more efficient and accurate lithology identification and reservoir quantification for geologists. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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16 pages, 3291 KiB  
Article
Positive Torque Modulation Method and Key Technology of Conventional Beam Pumping Unit
by Jinchao Xu, Siyuan Meng, Wei Li and Yan Wang
Energies 2022, 15(9), 3141; https://0-doi-org.brum.beds.ac.uk/10.3390/en15093141 - 25 Apr 2022
Cited by 3 | Viewed by 1515
Abstract
The large fluctuation of net torque and the existence of negative torque on the crank output shaft of the beam pumping unit are the decisive factors leading to its low efficiency and high energy consumption. The conventional pumping unit CYJ10-4.2-53HF was selected as [...] Read more.
The large fluctuation of net torque and the existence of negative torque on the crank output shaft of the beam pumping unit are the decisive factors leading to its low efficiency and high energy consumption. The conventional pumping unit CYJ10-4.2-53HF was selected as the study object on the basis of the fixed shaft secondary balance principle and the positive torque modulation scheme was first proposed according to the following secondary balance principle based on the linkage. The kinematics analysis of the suspension point and the secondary incremental velocity mechanism were carried out using the theory of rigid body plane kinematics. The force analysis of each moving part of the pumping unit was carried out, the net torque expression of the crank output shaft was obtained, and an example calculation was performed. The positive torque beam pumping unit was developed and tested in a field test. The tests showed that the positive torque beam pumping unit was able to fully realize positive torque operation under field well conditions, with a power saving rate of 23.73% and a 14.5% increase in system efficiency, and that the reliability of the pumping unit meets the requirements for field application. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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17 pages, 3396 KiB  
Article
The Application of Neural Networks to Forecast Radial Jet Drilling Effectiveness
by Sergey Krivoshchekov, Alexander Kochnev and Evgeny Ozhgibesov
Energies 2022, 15(5), 1917; https://doi.org/10.3390/en15051917 - 06 Mar 2022
Cited by 1 | Viewed by 1490
Abstract
This paper aims to study the applicability of machine-learning algorithms, specifically neural networks, for forecasting the effectiveness of Improved recovery methods. Radial jet drilling is the case operation in this study. Understanding changes in reservoir flow properties and their effect on liquid flow [...] Read more.
This paper aims to study the applicability of machine-learning algorithms, specifically neural networks, for forecasting the effectiveness of Improved recovery methods. Radial jet drilling is the case operation in this study. Understanding changes in reservoir flow properties and their effect on liquid flow rate is essential to evaluate the radial jet drilling effectiveness. Therefore, liquid flow rate after radial jet drilling is the target variable, while geological and process parameters have been taken as features. The effect of various network parameters on learning quality has been assessed. As a result, conclusions on the applicability of neural networks to evaluate the radial jet drilling potential of wells in various geological conditions of carbonate reservoirs have been made. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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16 pages, 5753 KiB  
Article
Diagenesis Evolution and Pore Types in Tight Sandstone of Shanxi Formation Reservoir in Hangjinqi Area, Ordos Basin, Northern China
by Yue Zhang, Jingchun Tian, Xiang Zhang, Jian Li, Qingshao Liang and Xiaoyu Zheng
Energies 2022, 15(2), 470; https://0-doi-org.brum.beds.ac.uk/10.3390/en15020470 - 10 Jan 2022
Cited by 6 | Viewed by 1557
Abstract
Diagenesis and pore evolution of tight sandstone reservoir is one of the most important issues surrounding clastic reservoirs. The tight sandstone of the Shanxi Formation is an important oil and gas producing layer of the Upper Paleozoic in Ordos Basin, and its densification [...] Read more.
Diagenesis and pore evolution of tight sandstone reservoir is one of the most important issues surrounding clastic reservoirs. The tight sandstone of the Shanxi Formation is an important oil and gas producing layer of the Upper Paleozoic in Ordos Basin, and its densification process has an important impact on reservoir quality. This study determined the physical properties and diagenetic evolution of Shanxi Formation sandstones and quantitatively calculated the pore loss in the diagenetic process. Microscopic identification, cathodoluminescence, and a scanning electron microscope were used identify diagenesis, and the diagenesis evolution process was clarified along with inclusion analysis. In addition, reservoir quality was determined based on the identification of pore types and physical porosity. Results show that rock types are mainly sublitharenite and litharenite. The reservoir has numerous secondary pores after experiencing compaction, cementation, and dissolution. We obtained insight into the relationship between homogenous temperature and two hydrocarbon charges. The results indicated that there were two hydrocarbon charges in the Late Triassic–Early Jurassic (70–90 °C) and Middle Jurassic–Early Cretaceous (110–130 °C) before reservoir densification. The quantitative calculation of pore loss shows that the average apparent compaction, cementation, and dissolution rates are 67.36%, 22.24%, and 80.76%, respectively. Compaction directly affected the reservoir tightness, and intense dissolution was beneficial to improve the physical properties of the reservoir. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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21 pages, 8089 KiB  
Article
Carbonate Platform Reef-Shoal Reservoir Architecture Study and Characteristic Evaluation: A Case of S Field in Turkmenistan
by Hao Wang, Qiumei Zhou, Wen Zhou, Yinde Zhang and Jianhua He
Energies 2022, 15(1), 226; https://0-doi-org.brum.beds.ac.uk/10.3390/en15010226 - 29 Dec 2021
Cited by 2 | Viewed by 1862
Abstract
Carbonate sediments are susceptible to many factors, such as paleostructure, diagenesis, and strong microbial alteration; as such, their sedimentary architecture still calls for further research. In this study, the reef and shoal bodies in the XVm and XVp layers of the Middle–Upper Jurassic [...] Read more.
Carbonate sediments are susceptible to many factors, such as paleostructure, diagenesis, and strong microbial alteration; as such, their sedimentary architecture still calls for further research. In this study, the reef and shoal bodies in the XVm and XVp layers of the Middle–Upper Jurassic Karlov-Oxfordian in the S gas field were used as the object, and the architecture of the reef-shoal facies was studied. Based on the idea of “vertical grading and horizontal boundary”, the interface characteristics of the 6th to 4th levels of reef-shoal bodies in the study area were summarized, as were four ways to determine the boundaries of reef-shoal bodies. Based on the dense well network, we quantitatively described the scale of each small layer of single reef shoal body through the point-line-surface method and established a geological database of the reef shoal bodies in the study area. In addition, we established the width and thickness of the reef shoal body and the empirical formula for relationships. The study of morphological characteristics of reef-shoal bodies and the degree of overlap revealed six architecture models of reef-shoal bodies. The vertical and lateral superimposed reefs were obtained by evaluating the reservoir space, pore throat characteristics, and physical property characteristics corresponding to various architecture models. The vertical and lateral superimposed shoals corresponded to large reservoir thicknesses. The petrophysical properties were good, and we concluded that the reef-shoal superimposed area was a sweet spot for reservoir development. We applied the research results of reef-shoal architecture reservoir characteristics to gas field development, and therefore improved well pattern deployment in the reef-shoal superimposed area. By comparing the test results of newly deployed horizontal wells with adjacent vertical wells, we confirmed that the selection of horizontal wells was better for gas field development. This study on the architecture of reef-shoal facies could guide the study of carbonate rock architecture. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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18 pages, 8510 KiB  
Article
Research on Test and Logging Data Quality Classification for Gas–Water Identification
by Zehou Xiang, Kesai Li, Hucheng Deng, Yan Liu, Jianhua He, Xiaoju Zhang and Xianhong He
Energies 2021, 14(21), 6991; https://0-doi-org.brum.beds.ac.uk/10.3390/en14216991 - 25 Oct 2021
Cited by 2 | Viewed by 1407
Abstract
Tight sandstone oil and gas reservoirs are widely distributed, rich in resources, with a bright prospect for exploration and development in China. Due to multiple evolutions of the structure and sedimentary system, the gas–water distribution laws are complicated in tight sandstone gas reservoirs [...] Read more.
Tight sandstone oil and gas reservoirs are widely distributed, rich in resources, with a bright prospect for exploration and development in China. Due to multiple evolutions of the structure and sedimentary system, the gas–water distribution laws are complicated in tight sandstone gas reservoirs in the northern Ordos area. It is difficult to identify gas and water layers in the study area. In addition, in the development and production, various factors, such as the failure of the instrument, the difference in construction parameters (injected sand volume, flowback rate), poor test results, and multi-layer joint testing lead to unreliable gas test results. Then, the inaccurate logging responses will be screened by unreliable gas test results for different types of fluids. It is hard to make high-precision fluid logging identification charts or models. Therefore, this article combines gas logging, well logging, testing and other data to research the test and logging data quality classification. Firstly, we select reliable standard samples through the initial gas test results. Secondly, we analyze the four main factors which affect the inaccuracy of gas test results. Thirdly, according to these factors, the flowback rate and the sand volume are determined as the main parameters. Then, we establish a recognition chart of injected sand volume/gas–water ratio. Finally, we proposed an evaluation method for testing quality classification. It provides a test basis for the subsequent identification of gas and water through the second logging interpretation. It also provides a theoretical basis for the exploration and evaluation of tight oil and gas reservoirs. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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14 pages, 14890 KiB  
Article
Using the Modified Resistivity–Porosity Cross Plot Method to Identify Formation Fluid Types in Tight Sandstone with Variable Water Salinity
by Yufei Yang, Kesai Li, Yuanyuan Wang, Hucheng Deng, Jianhua He, Zehou Xiang and Deli Li
Energies 2021, 14(19), 6335; https://0-doi-org.brum.beds.ac.uk/10.3390/en14196335 - 04 Oct 2021
Cited by 4 | Viewed by 1541
Abstract
It is generally difficult to identify fluid types in low-porosity and low-permeability reservoirs, and the Chang 8 Member in the Ordos Basin is a typical example. In the Chang 8 Member of Yanchang Formation in the Zhenyuan area of Ordos Basin, affected by [...] Read more.
It is generally difficult to identify fluid types in low-porosity and low-permeability reservoirs, and the Chang 8 Member in the Ordos Basin is a typical example. In the Chang 8 Member of Yanchang Formation in the Zhenyuan area of Ordos Basin, affected by lithology and physical properties, the resistivity of the oil layer and water layer are close, which brings great difficulties to fluid type identification. In this paper, we first analyzed the geological and petrophysical characteristics of the study area, and found that high clay content is one of the reasons for the low-resistivity oil pay layer. Then, the formation water types and characteristics of formation water salinity were studied. The water type was mainly CaCl2, and formation water salinity had a great difference in the study area ranging from 7510 ppm to 72,590 ppm, which is the main cause of the low-resistivity oil pay layer. According to the reservoir fluid logging response characteristics, the water saturation boundary of the oil layer, oil–water layer and water layer were determined to be 30%, 65% and 80%, respectively. We modified the traditional resistivity–porosity cross plot method based on Archie’s equations, and established three basic plates with variable formation water salinity, respectively. The above method was used to identify the fluid types of the reservoirs, and the application results indicate that the modified method agrees well with the perforation test data, which can effectively improve the accuracy of fluid identification. The accuracy of the plate is 88.1%. The findings of this study can help for a better understanding of fluid identification and formation evaluation. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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Review

Jump to: Research

23 pages, 3166 KiB  
Review
A Survey on the Shortcomings of the Current Rate of Penetration Predictive Models in Petroleum Engineering
by Mitra Khalilidermani and Dariusz Knez
Energies 2023, 16(11), 4289; https://0-doi-org.brum.beds.ac.uk/10.3390/en16114289 - 24 May 2023
Cited by 5 | Viewed by 1062
Abstract
In drilling engineering, the rate of penetration (ROP) is a prevalent indicator to evaluate the energy efficiency of drilling operations. Nowadays, ROP prediction has become more critical since the production from deeper hydrocarbon resources is unprecedentedly escalating. So far, a wealth [...] Read more.
In drilling engineering, the rate of penetration (ROP) is a prevalent indicator to evaluate the energy efficiency of drilling operations. Nowadays, ROP prediction has become more critical since the production from deeper hydrocarbon resources is unprecedentedly escalating. So far, a wealth of theoretical and practical investigations has been conducted to develop ROP models; however, the existing models have not been adequately updated with the new technological advancements or geological restrictions. This research strives to integrate the latest advancements, restrictions, and future requirements in ROP prediction. To do this, the existing empirical and data-driven ROP models are elaborated and compared. From the conducted research, it was deduced that four uncontrollable factors, including the rock permeability, wellbore inclination, temperature, and rock hardness, have not been adequately considered in ROP models. Moreover, although data-driven ROP models deliver more accurate results than the empirical models, the determination of the number and type of the input parameters is still challenging. To tackle this issue, it is recommended to develop a formation-based classification system of input parameters for future investigations. This inclusive review can be adopted by the companies and engineers involved in drilling operations to update and reform their drilling strategies. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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20 pages, 4039 KiB  
Review
Probabilistic Decline Curve Analysis: State-of-the-Art Review
by Taha Yehia, Ahmed Naguib, Mostafa M. Abdelhafiz, Gehad M. Hegazy and Omar Mahmoud
Energies 2023, 16(10), 4117; https://0-doi-org.brum.beds.ac.uk/10.3390/en16104117 - 16 May 2023
Cited by 4 | Viewed by 2150
Abstract
The decline curve analysis (DCA) technique is the simplest, fastest, least computationally demanding, and least data-required reservoir forecasting method. Assuming that the decline rate of the initial production data will continue in the future, the estimated ultimate recovery (EUR) can be determined at [...] Read more.
The decline curve analysis (DCA) technique is the simplest, fastest, least computationally demanding, and least data-required reservoir forecasting method. Assuming that the decline rate of the initial production data will continue in the future, the estimated ultimate recovery (EUR) can be determined at the end of the well/reservoir lifetime based on the declining mode. Many empirical DCA models have been developed to match different types of reservoirs as the decline rate varies from one well/reservoir to another. In addition to the uncertainties related to each DCA model’s performance, structure, and reliability, any of them can be used to estimate one deterministic value of the EUR, which, therefore, might be misleading with a bias of over- and/or under-estimation. To reduce the uncertainties related to the DCA, the EUR could be assumed to be within a certain range, with different levels of confidence. Probabilistic decline curve analysis (pDCA) is the method used to generate these confidence intervals (CIs), and many pDCA approaches have been introduced to reduce the uncertainties that come with the deterministic DCA. The selected probabilistic type of analysis (i.e., frequentist or Bayesian), the used DCA model(s), the type and the number of wells, the sampling technique of the data or the model’s parameters, and the parameters themselves undergo a probability distribution, and these are the main differences among all of these approaches and the factors that determine how each approach can quantify the uncertainties and mitigate them. In this work, the Bayesian and frequentist approaches are deeply discussed. In addition, the uncertainties of DCA are briefly discussed. Further, the bases of the different probabilistic analyses are explained. After that, 15 pDCA approaches are reviewed and summarized, and the differences among them are stated. The study concludes that Bayesian analysis is generally more effective than frequentist analysis, though with narrower CIs. However, the choice of DCA model and sampling algorithm can also affect the bounds of the CIs and the calculation of the EUR. Moreover, the pDCA approach is recommended for quantifying uncertainties in DCA, with narrower CIs that indicate greater effectiveness. However, the computational time and the number of iterations in sampling are also considered critical factors. That is why various assumptions and modifications have been made in the pDCA approaches, including the assumption of a certain probability distribution for the sampled parameters to improve their reliability of reserve estimation. The motivation behind this research was to present a full state-of-the-art review of the pDCA and the latest developments in this area of research. Full article
(This article belongs to the Special Issue Advances in Petroleum Exploration and Production)
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