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Processes
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New Challenges in Advanced Process Control in Petroleum Engineering
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New Challenges in Advanced Process Control in Petroleum Engineering

A special issue of Processes (ISSN 2227-9717). This special issue belongs to the section "Process Control and Monitoring".

Deadline for manuscript submissions: closed (30 September 2022) | Viewed by 16485

Special Issue Editors

Dr. Sheng Yang

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Guest Editor
Department of Chemical and Petroleum Engineering, University of Calgary, Calgary, AB T2N 1N4, Canada
Interests: reservoir simulation; oil sands; shale oil
Dr. Jinze Xu

E-Mail Website
Guest Editor
Department of Chemical and Petroleum Engineering, University of Calgary, Calgary, AB T2N 1N4, Canada
Interests: reservoir simulation; advanced process control; unconventional reservoirs
Special Issues, Collections and Topics in MDPI journals
Prof. Dr. Desheng Zhou

E-Mail Website
Guest Editor
College of Petroleum Engineering, Xi'an Shiyou University, Xi'an 710065, Shaanxi, China
Interests: hydraulic fracturing; reservoir engineering; shale/tight oil
Dr. Xing Hao

E-Mail Website
Guest Editor
Illinois Institute of Technology, Chicago, IL 60616, USA
Interests: advanced process control; signal processing
Prof. Dr. Zhangxing John Chen

E-Mail Website
Guest Editor
Department of Chemical & Petroleum Engineering, University of Calgary, Calgary, AB T2N 1N4, Canada
Interests: carbon capture and storage (CCS); cyclic steam stimulation (CSS); steam-assisted gravity drainage (SAGD); expanding solvent steam-assisted gravity drainage (ES-SAGD); vapor extraction process (VAPEX) for heavy oil and bitumen reservoirs; hydraulic fracturing for shale, tight oil and gas, and CBM (coal bed methane); underground coal gasification (UCG).
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

Advanced process control (APC) is a proven technique to guide and optimize field operations in the petroleum industry. APC provides a leading solution to coordinate surface facilities and in-situ production during reservoir development, which significantly reduces capital and operational costs and lowers process instabilities. However, with challenges in the exploration of unconventional reservoirs and the development of new surface facilities, process control becomes more complex and unpredictive, limiting its success from wellbores to refinery. The complexity mainly lies in reservoir uncertainty, enhanced oil recovery (EOR) applicability, time delay, optimization algorithm availability, and proper variable selection. In-depth theoretical advancements and case studies are thus needed to better utilize APC in practice.

This Special Issue on “New Challenges in Advanced Process Control in Petroleum Engineering” seeks high-quality studies focusing on theoretical advancements and field applications of APC in the oil and gas industry. Topics include, but are not limited to:

  • Machine learning and artificial intelligence (AI) techniques in reservoir development;
  • Studies of mechanisms of fluid flow in reservoirs and their implications for performance optimization;
  • Model predictive control (MPC) to optimize production and reduce costs;
  • Real-time optimization (RTO) from underground to surface;
  • Economic evaluation and optimization based on APC.

Dr. Sheng Yang
Dr. Jinze Xu
Prof. Dr. Desheng Zhou
Dr. Xing Hao
Prof. Dr. Zhangxing John Chen
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. Processes is an international peer-reviewed open access monthly 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 2400 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.

Published Papers (9 papers)

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Research

9 pages, 6646 KiB  
Article
Imbibition Characteristic of Fractured Tight Sandstone Reservoir
by Xiong Liu, Xin Fan, Jian Yin and Yang Zhang
Processes 2022, 10(11), 2189; https://doi.org/10.3390/pr10112189 - 25 Oct 2022
Cited by 7 | Viewed by 1107
Abstract
“Fracture network stimulation + imbibition replacement” is a new attempt to effectively develop tight sandstone reservoirs, and the fractures provide conditions for fluid imbibition replacement. On the basis of nuclear magnetic resonance and pseudo-color processing technology, combined with the imbibition experiments, this paper [...] Read more.
“Fracture network stimulation + imbibition replacement” is a new attempt to effectively develop tight sandstone reservoirs, and the fractures provide conditions for fluid imbibition replacement. On the basis of nuclear magnetic resonance and pseudo-color processing technology, combined with the imbibition experiments, this paper studies the imbibition process of fractured tight sandstone reservoirs, clarifies the effect of each level of pore-throat on imbibition, and realizes the visualization of the imbibition process. The results show that, in fractured tight sandstone reservoirs, the fluid displacement occurs in fractures first, followed by pore-throat. Most of the imbibition recovery is contributed by the macropore, the contribution of the mesopore to imbibition recovery is very weak, and the contributions of the micropore and the pinhole are even less. In the process of imbibition, capillary force and gravitational force are key parameters controlling fluid flow in pores and fractures. The replacement of fluid normally takes place in the early stage of imbibition, especially on the first day of imbibition, then the imbibition rate gradually decreases and finally tends to be stable. Full article
(This article belongs to the Special Issue New Challenges in Advanced Process Control in Petroleum Engineering)
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19 pages, 12943 KiB  
Article
Research on Casing Deformation Prevention Technology of a Deep Shale Gas Well Based on Cementing Slurry System Optimization
by Jing Cao, Shangyu Yang, Lihong Han, Jianjun Wang, Yisheng Mou and Caihong Lu
Processes 2022, 10(9), 1678; https://doi.org/10.3390/pr10091678 - 24 Aug 2022
Cited by 4 | Viewed by 1562
Abstract
In the complex fracturing process of shale gas wells, casing is subjected to serious deformation, which can easily to the failure of wellbore integrity and the reduction of well construction productivity. It is particularly important to clarify the casing deformation mechanism and carry [...] Read more.
In the complex fracturing process of shale gas wells, casing is subjected to serious deformation, which can easily to the failure of wellbore integrity and the reduction of well construction productivity. It is particularly important to clarify the casing deformation mechanism and carry out effective control. Based on the logging data of casing deformation from well and full-scale indoor tests, the casing deformation mechanism is mainly considered to be shear and non-uniform extrusion deformation caused by formation slip and displacement control, i.e., the ultimate working conditions. The slip displacement boundary (<40 mm) under complex fracturing conditions is quantified to provide the design and optimization basis. Then, the influence laws of steel grade and wall thickness on the shear and non-uniform extrusion bearing characteristics are studied, using unconventional oil and gas well casing simulation test systems for 110 ksi (φ139.7 × 10.54 mm) and 125 ksi (φ139.7 × 12.7 mm) casings. Furthermore, combined with the full-scale simulation tests and finite-element simulation, the effects of elastic and modified cement slurry with hollow glass beads on casing deformation are compared and studied. The results show that the deformation capacity mitigation of casing is limited by reducing the cement elastic modulus and increasing the elastic cement thickness. By reasonably adding hollow glass beads of modified cement slurry, the maximum geological movement absorption of cement slurry is up to 27 mm. This new method can obviously decrease casing deformation and have an excellent control effect. Combined with the cementing technology of Luzhou blocks, the formula of modified cement slurry is optimized, and the optimization window of the casing deformation control process is formed, which can ensure the smooth progress of engineering fracturing. Full article
(This article belongs to the Special Issue New Challenges in Advanced Process Control in Petroleum Engineering)
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15 pages, 8774 KiB  
Article
Experimental Research on Oil–Water Flow Imaging in Near-Horizontal Well Using Single-Probe Multi-Position Measurement Fluid Imager
by Junfeng Liu, Shoubo Shi and Hang Chen
Processes 2022, 10(6), 1051; https://doi.org/10.3390/pr10061051 - 25 May 2022
Cited by 3 | Viewed by 1277
Abstract
To obtain local flow velocity and holdup for oil–water in a near-horizontal well, array probes were adopted in the cross section of the wellbore. In this study, a fluid flow imaging logging tool called the single-probe multi-position measurement fluid imager (SPFI) was developed, [...] Read more.
To obtain local flow velocity and holdup for oil–water in a near-horizontal well, array probes were adopted in the cross section of the wellbore. In this study, a fluid flow imaging logging tool called the single-probe multi-position measurement fluid imager (SPFI) was developed, which consisted of only a single turbine flowmeter and a single capacitance holdup probe. Most importantly, it could collect local velocity and holdup information at different locations along the vertical direction of the wellbore diameter. Firstly, in the large-diameter multi-phase flow simulation test loop, the instrument was placed at five different positions along the wellbore cross section to perform simulated measurements in different wellbore deviation angles and oil–water flowrates. Secondly, the experiment data was analyzed, and the experiment flow pattern chart, instrument response coefficient, and rule of the instrument response were obtained. At the same time, the calculation methods of local holdup and local velocity were derived. Thirdly, by combining the interpolation algorithm, velocity imaging and holdup imaging were implemented, and the stratified flow model was used to calculate the flowrate of each phase. Finally, this study provides technology support for production profile data interpretation using the fluid flow imaging tool for oil–water in a near-horizontal well. Full article
(This article belongs to the Special Issue New Challenges in Advanced Process Control in Petroleum Engineering)
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11 pages, 1748 KiB  
Article
Transient Pressure Behavior of Volume Fracturing Horizontal Wells in Fractured Stress-Sensitive Tight Oil Reservoirs
by Zhong Li, Xinjiang Yan, Min Wen, Gang Bi, Nan Ma and Zongxiao Ren
Processes 2022, 10(5), 953; https://doi.org/10.3390/pr10050953 - 10 May 2022
Cited by 2 | Viewed by 1451
Abstract
Tight oil reservoirs tend to contain more natural fractures, and the presence of natural fractures leads to a greater stress sensitivity in tight oil reservoirs. It is a very challenging task to model the seepage in the volume fracturing horizontal wells considering the [...] Read more.
Tight oil reservoirs tend to contain more natural fractures, and the presence of natural fractures leads to a greater stress sensitivity in tight oil reservoirs. It is a very challenging task to model the seepage in the volume fracturing horizontal wells considering the stress-sensitive effects. Based on the Laplace transform, Perturbation transform and Stefest numerical inversion, this paper establishes a horizontal well seepage model for volume fracturing in fractured stress-sensitive tight oil reservoirs. This model allows us to analyze and study the effect of stress sensitivity, fracture interference, dual media and complex fracture network on seepage flow in tight oil reservoirs. We apply the model to delineate the seepage stages of volume fracturing horizontal wells, it can be divided into seven seepage stages I wellbore storage flow, II surface flow stage, III transition flow, IV natural fracture system proposed radial flow, V interporosity flow, VI system proposed radial flow and VII stress-sensitive flow stage. Wellbore storage coefficient mainly affects the flow in the wellbore storage stage. The larger the wellbore storage coefficient is, the longer the duration of wellbore storage flow will be. The higher the skin coefficient is, the greater the pressure drop is. The storage capacity ratio has a greater influence on the flow before the occurrence of channeling flow, and the “groove” depth on the derivative curve of dimensionless pressure drop becomes shallower with the increase in storage capacity ratio. The higher the channeling coefficient is, the earlier the channeling occurs from the matrix system to the natural fracture system and the more leftwing the “groove” position is. Full article
(This article belongs to the Special Issue New Challenges in Advanced Process Control in Petroleum Engineering)
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19 pages, 7755 KiB  
Article
Elastic Correlative Least-Squares Reverse Time Migration Based on Wave Mode Decomposition
by Yue Zheng, Youshan Liu, Tao Xu and Zhiyuan Li
Processes 2022, 10(2), 288; https://doi.org/10.3390/pr10020288 - 31 Jan 2022
Cited by 2 | Viewed by 1787
Abstract
The conventional elastic least-squares reverse time migration (LSRTM) generally inverts the parameter perturbation of the model rather than the reflectivity of reflected P- and S-modes, which leads to difficulty in directly interpreting the physical properties of the subsurface media. However, an accurate velocity [...] Read more.
The conventional elastic least-squares reverse time migration (LSRTM) generally inverts the parameter perturbation of the model rather than the reflectivity of reflected P- and S-modes, which leads to difficulty in directly interpreting the physical properties of the subsurface media. However, an accurate velocity model that is needed by the separation of seismic records of conventional LSRTM is usually unavailable in real data, which limits its application. In this study, we introduce a new practical correlative LSRTM (CLSRTM) scheme based on wave mode decomposition without amplitude and phase distortion, which frees from separation of seismic records. In this study, we deduced the migration and the de-migration operators using the decoupled P- and S-wave equations in heterogeneous media, which needs no extra wavefield decomposition in simulated data. To accelerate the convergence and improve the efficiency of the inversion, we adopted an analytical step-length formula that can be incidentally computed during the necessary de-migration process and the L-BFGS algorithm. Two numerical examples demonstrate that the proposed method can compensate the energy of deep structures, and generate clear images with balanced amplitudes and enhanced resolution even for the fault structures beneath the salt dome. Full article
(This article belongs to the Special Issue New Challenges in Advanced Process Control in Petroleum Engineering)
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11 pages, 1229 KiB  
Article
Review of Marginal Oil Resources in Highly Depleted Reservoirs
by Jun Pan, Yingfeng Meng, Ning Sun, Chang Liu, Sheng Yang, Jinze Xu, Wei Wu, Ran Li and Zhangxin Chen
Processes 2022, 10(2), 245; https://doi.org/10.3390/pr10020245 - 27 Jan 2022
Cited by 3 | Viewed by 2222
Abstract
The term “marginal oil resource” refers to an oil reservoir that has hydrocarbon resource preservation but cannot meet the criteria of resources under the U.S Securities and Exchange Commission (SEC) standards. When oilfields step into their late life, most of their economic petroleum [...] Read more.
The term “marginal oil resource” refers to an oil reservoir that has hydrocarbon resource preservation but cannot meet the criteria of resources under the U.S Securities and Exchange Commission (SEC) standards. When oilfields step into their late life, most of their economic petroleum reserves have been well developed, and their focuses need to be switched to their intact marginal resources. In this paper, reservoir characteristics and key petrophysical properties of marginal oil resources are introduced to classify marginal oil resources into four types for identifying potential development opportunities. Primary recovery and its following development strategy are applied to fully utilizing their economic returns. Waterflooding, low salinity waterflooding (LSW) and enhanced oil recovery processes are reviewed to illustrate its potential uplift on oil production and application challenges such as higher clay content in marginal resources than in commercial reservoirs. An oilfield is presented as a case study to demonstrate the classification of marginal resources and illustrate successful economic development including learnings and challenges. This paper highlights the development potential of marginal resources and proposes a clear guidance for policy makers on how to tailor a development strategy supporting their economic development. This review could increase certainty on forecasting performance of marginal resources. Full article
(This article belongs to the Special Issue New Challenges in Advanced Process Control in Petroleum Engineering)
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12 pages, 5757 KiB  
Article
Effect of Salinity on the Imbibition Recovery Process of Tight Sandstone Reservoirs
by Xiong Liu, Le Yan, Qian Gao, Yafei Liu, Hai Huang and Shun Liu
Processes 2022, 10(2), 228; https://doi.org/10.3390/pr10020228 - 26 Jan 2022
Cited by 2 | Viewed by 2257
Abstract
Fracture network fracturing combined with oil–water infiltration and replacement is an effective approach to develop tight sandstone reservoirs. How to further improve oil recovery based on imbibition is a problem encountered during production. In this study, the core of the CHANG-7 tight sandstone [...] Read more.
Fracture network fracturing combined with oil–water infiltration and replacement is an effective approach to develop tight sandstone reservoirs. How to further improve oil recovery based on imbibition is a problem encountered during production. In this study, the core of the CHANG-7 tight sandstone reservoir in the Changqing oilfield of the China National Petroleum Corporation (CNPC) is studied. Combined with the newly designed core self-imbibition experiment, the mechanisms of salinity action are studied, and the influence of salinity on the process of imbibition oil recovery is quantitatively characterized. Research results show that the influence of salinity on the imbibition process of tight sandstone reservoirs takes place mainly through two ways; one is to reduce the oil–water interfacial tension, and the other is to construct an osmotic pressure displacement model. The salinity has significant influences on interfacial tension. The interfacial tension of low-salinity brine is only 1/5 of that of distilled water, but in the presence of high-efficiency surfactants, the influence of the salinity on the interfacial tension can be ignored; the greater the difference in salt concentration, the higher the core permeability and the greater the influence of salinity on the process of imbibition and oil recovery in tight sandstone reservoirs. At the initial stage of imbibition, the effect of salinity is less important than that of capillary force. On the contrary, the effect of salinity is much more important than that of capillary force in the middle of imbibition, and the imbibition curve shows a downward trend. At the later stage of imbibition, the fluid tends toward imbibition equilibrium, and the effects of capillary force and salinity are not obvious. Full article
(This article belongs to the Special Issue New Challenges in Advanced Process Control in Petroleum Engineering)
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11 pages, 1874 KiB  
Article
Production Calculation Model of Thermal Recovery after Hydraulic Fracturing and Packing in Tight Reservoir
by Long Wang, Yang Li, Zhandong Li, Yikun Liu, Laiming Song and Yunshu Lv
Processes 2021, 9(12), 2226; https://doi.org/10.3390/pr9122226 - 09 Dec 2021
Cited by 1 | Viewed by 1771
Abstract
It was deemed important to calculate the thermal recovery production model of tight oil reservoirs after fracturing and packing based on the field data of an oilfield in Bohai Sea, China. The thermal recovery production of a tight oil reservoir after fracturing is [...] Read more.
It was deemed important to calculate the thermal recovery production model of tight oil reservoirs after fracturing and packing based on the field data of an oilfield in Bohai Sea, China. The thermal recovery production of a tight oil reservoir after fracturing is demonstrated through theoretical calculation and practical field data on the premise of five hypotheses. Fractures change the fluid flow capacity of the reservoir. Combined with the relevant theories of reservoir thermal production, the dual porosity system in the fractured zone and the single porosity system in the unfractured zone were established. The calculation models of heat loss in the fractured and unfractured zones were derived to determine the thermal recovery heating radius of the reservoir after fracturing and packing. Combined with the pseudo-steady state productivity formula of the composite reservoir, a production calculation model of thermal recovery after fracturing and packing in the tight oil reservoir was established. The results showed that the heating radius of the reservoir after fracturing and packing is smaller than that of the unfractured reservoir, and the additional heat absorption of the fracture system generated by fracturing and packing reduces the thermal recovery effect. The thermal recovery productivity of heavy oil reservoirs is mainly affected by the heating radius. With the increase of fracture density, the heating radius decreases and production decreases. The increase of fracture porosity also leads to the decrease of the heating radius and the production. The calculation result of this model is improved after tight oil reservoir fracturing during the production period, which indicates that the model has a better prediction effect of the production of the tight reservoir after fracturing and packing. Full article
(This article belongs to the Special Issue New Challenges in Advanced Process Control in Petroleum Engineering)
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20 pages, 2485 KiB  
Article
Parallel Implementation of the Deterministic Ensemble Kalman Filter for Reservoir History Matching
by Lihua Shen, Hui Liu and Zhangxin Chen
Processes 2021, 9(11), 1980; https://doi.org/10.3390/pr9111980 - 06 Nov 2021
Viewed by 1628
Abstract
In this paper, the deterministic ensemble Kalman filter is implemented with a parallel technique of the message passing interface based on our in-house black oil simulator. The implementation is separated into two cases: (1) the ensemble size is greater than the processor number [...] Read more.
In this paper, the deterministic ensemble Kalman filter is implemented with a parallel technique of the message passing interface based on our in-house black oil simulator. The implementation is separated into two cases: (1) the ensemble size is greater than the processor number and (2) the ensemble size is smaller than or equal to the processor number. Numerical experiments for estimations of three-phase relative permeabilities represented by power-law models with both known endpoints and unknown endpoints are presented. It is shown that with known endpoints, good estimations can be obtained. With unknown endpoints, good estimations can still be obtained using more observations and a larger ensemble size. Computational time is reported to show that the run time is greatly reduced with more CPU cores. The MPI speedup is over 70% for a small ensemble size and 77% for a large ensemble size with up to 640 CPU cores. Full article
(This article belongs to the Special Issue New Challenges in Advanced Process Control in Petroleum Engineering)
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