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Advanced Petroleum and Nature Gas Exploration Technology

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

Deadline for manuscript submissions: closed (19 April 2023) | Viewed by 9313

Special Issue Editors

Dr. Jiafeng Jin

E-Mail Website
Guest Editor
School of Petroleum Engineering, China University of Petroleum, Qingdao 266580, China
Interests: synthesis and application of nanomaterials in the petroleum industry; in situ conversion of shale oil
Special Issues, Collections and Topics in MDPI journals
Dr. Xianbin Huang

E-Mail Website
Guest Editor
School of Petroleum Engineering, China University of Petroleum, Qingdao 266580, China
Interests: drilling fluids and agents for high-temperature reservoir; mechanism of high temperature and salt resistance

Special Issue Information

Dear Colleagues,

During the past decades, unprecedented rapid globalization has accelerated the need for petroleum and gas, and it has become more difficult to recover enough oil and gas without advanced petroleum and gas exploration technology. Low- to medium-maturity shale oil is a promising alternative energy, and the in situ conversion method by the catalyst or high-temperature fluid has been proven to be one of the most promising measures. For the drilling industry, the deep and ultradeep reservoirs have become one of the most important targets to increase oil and gas production; however, the agents or drilling fluid used in conventional drilling is not suitable for the harsh conditions of the deep and ultradeep reservoirs, so novel nanomaterials and high-performance drilling fluid for the deep and ultradeep reservoirs are urgently needed. Drilling and fracture can cause serious formation damage without suitable pretreatment. To maintain stable oil and gas production, efficient formation protection measures must be taken, novel technology and agents in this area are important safeguards. The wettability of the reservoir dominates the migration and distribution of oil and gas in the porous media, the agents that can achieve wettability alternation and the microscopic flow mechanism that can push forward the research in the area are needed.

This Special Issue aims to present and disseminate the most recent advances related to the synthesis, application, and mechanism of novel materials and technology for the petroleum industry.

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

  • Synthesis and application of nanomaterials for the petroleum industry;
  • Drilling fluid and key agents;
  • Novel technology for formation protection;
  • Wettability alternation;
  • Mechanism of the flow behavior of fluids in porous media.

Dr. Jiafeng Jin
Dr. Xianbin Huang
Guest Editors

Manuscript Submission Information

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Keywords

  • synthesis and application of nanomaterials for the petroleum industry
  • novel technology petroleum exploration and formation protection
  • high-performance drilling fluids
  • key agents for drilling fluid
  • wettability alternation
  • mechanism of the flow behavior of fluids in porous media

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Published Papers (5 papers)

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Research

25 pages, 11047 KiB  
Article
Saturation and Pressure Prediction for Multi-Layer Irregular Reservoirs with Variable Well Patterns
by Haochen Wang, Yafeng Ju, Kai Zhang, Chengcheng Liu, Hongwei Yin, Zhongzheng Wang, Zhigang Yu, Ji Qi, Yanzhong Wang and Wenzheng Zhou
Energies 2023, 16(6), 2714; https://doi.org/10.3390/en16062714 - 14 Mar 2023
Viewed by 1412
Abstract
The well pattern and boundary shape of reservoirs determine the distribution of the remaining oil distribution to a large extent, especially for small-scale reservoir blocks. However, it is difficult to replicate experiences from other reservoirs directly to predict the remaining oil distribution because [...] Read more.
The well pattern and boundary shape of reservoirs determine the distribution of the remaining oil distribution to a large extent, especially for small-scale reservoir blocks. However, it is difficult to replicate experiences from other reservoirs directly to predict the remaining oil distribution because of the variety of irregular boundary shapes and corresponding well patterns. Meanwhile, the regular well pattern can hardly suit irregular boundary shapes. In this paper, we propose a well placement method for undeveloped irregular reservoirs and a multi-step prediction framework to predict both oil saturation and pressure fields for any reservoir shape and well pattern. To boost the physical information of input characteristics, a feature amplification approach based on physical formulae is initially presented. Then, 3D convolution technology is employed for the first time in 3D reservoir prediction to increase the spatial information in the vertical direction of the reservoir in the input. Moreover, to complete the two-field prediction, the concept of multi-task learning is adopted for the first time, improving the rationality of the forecast. Through the loss-based ablation test, we found that the operation we adopt will increase the accuracy of prediction to some extent. By testing on both manually designed and real irregular-shape reservoirs, our method is proven to be an accurate and fast oil saturation prediction method with its prediction loss less than 0.01 and calculation time less than 10 s in the future one year. Full article
(This article belongs to the Special Issue Advanced Petroleum and Nature Gas Exploration Technology)
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14 pages, 8116 KiB  
Article
Identification of Reservoir Water-Flooding Degrees via Core Sizes Based on a Drip Experiment of the Zhenwu Area in Gaoyou Sag, China
by Xiaoyu Ju, Xiaodong Zhao, Boyu Zhou, Ruixue Zhang, Xinyu Wu and Dafa Guo
Energies 2023, 16(2), 608; https://doi.org/10.3390/en16020608 - 4 Jan 2023
Cited by 1 | Viewed by 1342
Abstract
In order to identify the degree of water flooding in a reservoir and to discover any remaining oil-enriched areas, in this paper, a systematic study on the water flooding of cores in obturated coring wells is carried out. With observations and testing data [...] Read more.
In order to identify the degree of water flooding in a reservoir and to discover any remaining oil-enriched areas, in this paper, a systematic study on the water flooding of cores in obturated coring wells is carried out. With observations and testing data of the cores, based on the notion of sedimentary facies, the water-flooding degrees of 4–7 sand groups in member one of the Paleogene Sanduo Formation (E2s14–7) of the Zhenwu area in the Gaoyou Sag are determined. Overall, the results show that the study area is formed under the background of lake regression, with various sedimentary systems, mainly including delta facies, braided fluvial facies, and meandering fluvial facies. The degree of water flooding is determined using a point-by-point drip experiment of the core. Combined with the testing results of the core, the water-flooding degrees of the different sedimentary facies are quantitatively determined. Identification standards for the water-flooding degree of delta facies, braided river facies, and meandering river facies are established. The water-flooding degree of the delta sand body is generally weak, with an oil saturation rate of 24.1–40.2%, essentially indicating no water flooding or weak water flooding. The water-flooding degree of the braided fluvial sand body significantly changes, and the variation range of the oil and water saturation measurement results is also large. The water-flooding degree of the meandering fluvial sand body is weaker than that of the braided fluvial sand body, which is mostly not flooded or weakly flooded. The water-flooding degree is obviously controlled by the sedimentary rhythm and the sedimentary type. The top of the positive rhythm, the bottom of the sludge bed in the braided fluvial point bar, the deltaic front subaqueous distributary channel, and the point bar in the meandering fluvial have relatively low water-flooding degrees. They are the subjects of subsequent development adjustment and the remaining oil potential tapping. Full article
(This article belongs to the Special Issue Advanced Petroleum and Nature Gas Exploration Technology)
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19 pages, 2508 KiB  
Article
Process Optimization of the Flaring Gas for Field Applications
by Luisa Fernanda Ibañez-Gómez, Sebastian Albarracín-Quintero, Santiago Céspedes-Zuluaga, Erik Montes-Páez, Oswaldo Hideo Ando Junior, João Paulo Carmo, João Eduardo Ribeiro, Melkzedekue Moraes Alcântara Moreira, Adriano Almeida Goncalves Siqueira and Camilo Andrés Guerrero-Martin
Energies 2022, 15(20), 7655; https://doi.org/10.3390/en15207655 - 17 Oct 2022
Cited by 8 | Viewed by 2565
Abstract
During petroleum industry operations, burning flammable gas components in the flaring stacks is common, normally a symbol for stable production, but flaring these components creates harmful emissions for the environment. This flaring gas has components with a high quantity of heating power, an [...] Read more.
During petroleum industry operations, burning flammable gas components in the flaring stacks is common, normally a symbol for stable production, but flaring these components creates harmful emissions for the environment. This flaring gas has components with a high quantity of heating power, an important measurement that quantifies the energy that can potentially be obtained from this wasted resource. This paper aims to evaluate the energy usage of the flaring gas, estimating the possible energy produced with this usable resource by modeling a treatment and energy generation process employing the Aspen HYSYS® simulator. The flaring gas is characterized using different models and compositional ranges of natural gas to know what kind of gas it is and identify what type of equipment could be used for treatment and energy generation from this resource. After the gas characterization, the selection of the equipment of treatment and energy generation is necessary; this is done using a multicriteria analysis by taking into consideration the variables of gas composition, electrical efficiency, economic performance, and GHG emissions, ensuring to generate the greatest amount of energy possible to be produced with this flaring gas. By increasing the LHV, 0.95 MMSCF of flared gas of an oilfield in the VMM basin produced 5133 kW, enough energy to supply gas treatment and power generation facilities and four times the total gross consumption energy of a model oilfield in the basin, while the CO2 emissions were reduced 11.4%, and cost savings using this resource instead of diesel were obtained. In conclusion, to minimize flaring and to recover and reuse these waste components, looking for alternatives for the use of this gas-like power generation is an important option that reduces pollutants emission, gives a new source of fuel, and gives an energy usefulness to this wasted resource. Full article
(This article belongs to the Special Issue Advanced Petroleum and Nature Gas Exploration Technology)
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19 pages, 4845 KiB  
Article
Injectability of Partially Hydrolyzed Polyacrylamide Solutions Improved by Anionic-Nonionic Surfactant in Medium and Low Permeability Reservoirs
by Long Wang, Jianguang Wei, Yinghe Chen, Shihua Jia, Yiling Wang, Xudong Qiao and Long Xu
Energies 2022, 15(19), 6866; https://doi.org/10.3390/en15196866 - 20 Sep 2022
Cited by 3 | Viewed by 1374
Abstract
Injectability of the polymer solution is a very important factor that determines the effectiveness of polymer flooding for enhanced oil recovery. Here, the medium and low permeability oil reservoir was taken as a research object, and effects of relative molecular weight, concentration and [...] Read more.
Injectability of the polymer solution is a very important factor that determines the effectiveness of polymer flooding for enhanced oil recovery. Here, the medium and low permeability oil reservoir was taken as a research object, and effects of relative molecular weight, concentration and core permeability on the flow and injection performance of a partially hydrolyzed polyacrylamide (HPAM) solution with and without anionic-nonionic surfactant (ANS) were studied by indoor outcrop core physical model experiments. It was found that the influence of HPAM concentration on the flow performance was related to the core permeability. When the core permeability was lower than 59 mD, the resistance factor and residual resistance factor of HPAM increased with increasing the concentration. High molecular weight and low core permeability were not conducive to the injectability of HPAM solutions. The addition of ANS was beneficial in enhancing the injectability of HPAM solution by reducing the critical value of injectability of HPAM solution, which was elucidated by the Hall curve derivative method. In the presence of ANS, the flow pressure gradient and the residual resistance factor of the HPAM solution decreased. It is believed that the injectability of HPAM solution improved by ANS in the medium and low permeability reservoirs can be attributed to decrease in fluid viscosity and competitive adsorption on the surface of porous media. The study provides a new idea and theoretical basis for improving the injectability of an HPAM solution and the application of polymer flooding and a polymer/surfactant binary flooding system in medium and low permeability reservoirs. Full article
(This article belongs to the Special Issue Advanced Petroleum and Nature Gas Exploration Technology)
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14 pages, 1140 KiB  
Article
Experiment and Application of Wax Deposition in Dabei Deep Condensate Gas Wells with High Pressure
by Lihu Cao, Jinsheng Sun, Jianyi Liu and Jiquan Liu
Energies 2022, 15(17), 6200; https://doi.org/10.3390/en15176200 - 26 Aug 2022
Cited by 21 | Viewed by 1840
Abstract
The Dabei deep high-pressure condensate gas field occupies the paramount position in the Tarim Oilfield in China, the exploration and developments of which have been progressing. Since the initial development, the wax deposition and plugging in the wellbore and gathering pipeline have been [...] Read more.
The Dabei deep high-pressure condensate gas field occupies the paramount position in the Tarim Oilfield in China, the exploration and developments of which have been progressing. Since the initial development, the wax deposition and plugging in the wellbore and gathering pipeline have been the most bothering issues, resulting in the reduction or even shutdown of condensate gas well production. Therefore, the wax appearance temperature of Dabei condensate oil was studied using the capillary viscometer, differential scanning calorimetry (DSC), and polarizing microscope observation. The wax content was tested by using the DSC and crystallization separation test method. Finally, the wax appearance temperatures of degassed condensate oil and equilibrium condensate oil under different pressures were tested. Experimental results show that the wax appearance temperature measured by polarizing microscope observation was higher than that measured by the DSC and capillary viscometer, the lag of which can be recorded as the cloud point. The wax appearance temperature measured by polarizing microscope observation is of high accuracy. Secondly, the DSC method is not sufficient for measuring wax precipitation at low temperatures, showing a lower wax content than the crystallization separation test method. Thus, the wax content of Dabei condensate oil can be better measured by using the crystallization separation test method. Additionally, the wax precipitation law of equilibrium condensate oil is opposite to that of degassed condensate oil. The wax appearance temperature of equilibrium condensate oil increases as the pressure decreases. The results of wax appearance temperature of equilibrium condensate oil provide a useful and quick index to judge the potential risk of wax precipitation in the Tarim Oilfield, which can provide an efficient strategy for the development of waxy condensate gas reservoirs and the optimization of wax prevention and treatment technology. Full article
(This article belongs to the Special Issue Advanced Petroleum and Nature Gas Exploration Technology)
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