item: #1 of 106
          id: iogr-1144
      author: Yang, Yong ; Zhang, Ming ; Bie, Aifang ; Cui, Zehong ; Xia, Zhaohui 
       title: An Integrated Approach of Uncertainty Assessment for Coalbed Methane Model: DOI: 10.14800/IOGR.1144
        date: 2020
       words: 2638
      flesch: 52
     summary: Max MinBase Case Base Case High_residual Low_residual SGS grid Uncertainty ResidualBase Case SGS x High_res/3 SGS x Low_res/3 - = - = = + + 0 - 4 Figure 3—Parameters uncertainty analysis. Abstract This study deals with quantitative detection of parameters uncertainty in coalbed methane(CBM) modelling and a systematic and integrated workflow is developed to analyze the uncertainty of CBM model.
    keywords: analysis; base; modelling; surface; thickness; uncertainty
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        item: #2 of 106
          id: iogr-1145
      author: Gu, Qingjie 
       title: Study on Technical and Economic Limit of Layer-Recombination and Well Pattern Adjustment: DOI: 10.14800/IOGR.1145
        date: 2020
       words: 2180
      flesch: 55
     summary: By controlling the thickness of the interlayer, the development effects under different production wells spacing were simulated. Dr. Gu specializes in enhance oil recovery and economic analysis.
    keywords: limit; oil; recovery; spacing
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        item: #3 of 106
          id: iogr-1146
      author: Yan, Liping 
       title: Using Dynamic Monitoring Data to Calculate Remaining Oil Saturation : DOI: 10.14800/IOGR.1146
        date: 2020
       words: 3023
      flesch: 54
     summary: In conclusion, the calculation methods of remaining oil saturation in injection wells is as follows,  Using Eq. 13 to calculate the residual oil saturation of each oil layer when injection begins;  To determine the accumulative water injection rate and effective thickness of each layer according to all the previous water injection profile data. That is the value of remaining oil saturation.
    keywords: data; dynamic; oil; oil saturation; saturation; water
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        item: #4 of 106
          id: iogr-1147
      author: Zou, Xinning; Lu, Tao; Li, Jinbu; Fu, Bin
       title: Geophysical Research Progress on Tight Sandstone Reservoir in Sulige Gas Field: DOI: 10.14800/IOGR.1147
        date: 2020
       words: 3502
      flesch: 53
     summary: By applying prestack seismic data processing techniques with wide frequency, fidelity reserved and amplitude reserved at its core, the energy of high frequency constituent in the data was enhanced, and we obtained the reprocessed data with high fidelity, wide frequency band, high resolution and good consistency, compared to the previous processing results. Based on the significant quality difference, to meet the need of reservoir prediction, the well control processing technique was applied to enhance seismic data resolution and keep the relative relationship of amplitude.
    keywords: area; data; figure; gas; he8; processing; reservoir; sandstone
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        item: #5 of 106
          id: iogr-1148
      author: Tian, Weidong; Dong, Zhenzhen; Lin, Jiaen
       title: Horizontal Well Productivity Evaluation for Stress Sensitive Elliptical Reservoirs: DOI: 10.14800/IOGR.1148
        date: 2020
       words: 4850
      flesch: 56
     summary: Joshi (1988a) further illustrates the principle of horizontal well production through electrical simulation, and the calculation of steady-state production of horizontal well was derived in detail. In this section, the proposed production model (Eq. 28) was applied to study the impact of horizontal well length (L), reservoir thickness (h), medium deformation coefficient (ak), shape of drainage area (a/b), anisotropy index (𝐼𝑎𝑛𝑖), eccentric distance(𝛿) and formation damage (S) on horizontal well production (Q).
    keywords: flow; pressure; production; productivity; reservoir; wells; 𝐿/2
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        item: #6 of 106
          id: iogr-1155
      author: Vo, Minh; Su, San; Lv, Jianjiang; Xiao, Chaohong
       title: Reservoir Modeling and Production History Matching in A Triassic Naturally Fractured Carbonate Reservoir in Sichuan, China: DOI: 10.14800/IOGR.1155
        date: 2020
       words: 4461
      flesch: 51
     summary: Similarly, the well-test derived fracture permeability kisof should be equal to geometric mean of calibrated kmaxf_c and kminf_c, as shown ����� 2 = �����_� × ������,.……….……………..…………….……………….……………………….(2) To keep the ratio between major axis and minor axis of the fracture permeability tensors unchanged during the calibration process, we have �����_� �����_� = ����� ����� ....…….………………………………………………………….…….............................(3) Solve Eqs. 2 and 3, the �����_� and �����_� as final anisotropic fracture permeability can be calculated as �����_� = ����� 2 × ����� ����� ,…………….....……………………………….………….………..………..(4) �����_� = ����� 2 × ����� ����� .…………...…………………………............................................................(5)
    keywords: data; field; figure; fracture; model; permeability; production; ratio; reservoir; test; � �
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        item: #7 of 106
          id: iogr-1156
      author: Chen, Li
       title: Sweet Spots Selection of Low-Abundance Coalbed Methane Reservoir: DOI: 10.14800/IOGR.1156
        date: 2020
       words: 2388
      flesch: 56
     summary: Table 1—The comparison of well production contains 2# coal and not contains 2# coal. Well group name Well number contains 2# coal Well number not contains 2# coal Average well production contains 2# coal(m3/d)
    keywords: abundance; block; coal; gas; production; seam
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        item: #8 of 106
          id: iogr-1177
      author: Abdulmohsein, Zainab; Bai, Baojun ; Neogi, Parthasakha
       title: Emulsion Stability of Heavy Oil with Surfactants and Nanoparticles: DOI: 10.14800/IOGR.1177
        date: 2020
       words: 4047
      flesch: 66
     summary: Conclusions We have covered a very large area of heavy oil emulsions containing additives and found that phase separation was best in presence of the anionic surfactant. She was working in the lab as a researcher and her studies were focusing on the stability of crude oil emulsion using chemical products, such as surfactants and nanoparticles.
    keywords: emulsion; figure; nacl; nanoparticles; oil; phase; surfactants; water
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        item: #9 of 106
          id: iogr-1183
      author: Mohan, Vijitha; Qiu, Xianjie; Neogi, Parthasakha
       title: Dynamics of Drops as Confined Systems Containing Nanoparticles-Reformation of Nanoparticles and Evaporation of Water: DOI: 10.14800/IOGR.1183
        date: 2021
       words: 4558
      flesch: 71
     summary: The drop edge is practically never smooth but our measurements in Figure 5 do not show fluctuations except at high particle concentrations. Most work continues to deal with low particle concentrations and/or larger particles.
    keywords: al2o3; alumina; drop; figure; glass; particles; pet; time
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        item: #10 of 106
          id: iogr-1184
      author: Mohan, Vijitha; Neogi, Parthasakha; Bai, Baojun
       title: Heavy Oil and VAPEX Process: A Brief Review: DOI: 10.14800/IOGR.1184
        date: 2021
       words: 7607
      flesch: 70
     summary: The exact molecular weight and chemistry of heavy oil are uncertain making analysis of thermodynamic properties difficult; however, this is overcome by making use of volume fractions of heavy oil and solvent used. It is possible to correlate all properties of heavy oil with or without solvent using the volume-based approach.
    keywords: co2; concentration; diffusivity; et al; mohan; oil; properties; recovery; solvent; vapor; viscosity; volume
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        item: #11 of 106
          id: iogr-1185
      author: Dai, Cheng; Dong, Zhenzhen ; Li, Xiang; Tian, Weidong
       title: Optimization of Flowback Operations for Shale Gas Wells: DOI: 10.14800/IOGR.1185
        date: 2021
       words: 8026
      flesch: 59
     summary: The oil industry has developed a suite of tools or models to mitigate proppant flowback, including forced closure, resin-coated sands, deformable proppants, mechanical screens, fracture packs, resin injection, and surface modification agents (Shor and Sharma 2014). However, there are no standard industry practices or recommendations for well flowback to maximize well productivity and minimize proppant flowback.
    keywords: choke; closure; figure; flowback; fluid; fracture; fracturing; gas; model; pressure; proppant; reservoir; size; 𝐾𝑑 𝐾𝑠
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        item: #12 of 106
          id: iogr-1187
      author: Zhang, Fengli ; Lv, Wenfeng ; Zhou, Yongyi; Qu, Bochao; He, Yawen; Ma, Xinle; Tian, Weidong; Dong, Zhenzhen 
       title: Research on Oil-CO2-Water Relative Permeability of the Low Permeability Reservoir based on History Matching: DOI:10.14800/IOGR.1187
        date: 2021
       words: 3952
      flesch: 47
     summary: NO = exponent for calculating krow from krocw NW = exponent for calculating krw from krwiro SOIRG = irreducible oil saturation for gas-liquid table SORG = residual oil saturation for gas-liquid table SGCON = connate gas saturation SGCRIT = critical gas saturation KRGMAX = maximum krg KROGMAX = maximum krog NG = exponent for calculating krog from krogcg NL = exponent for calculating krg from krgcl PCOWMAX = maximum oil-water capillary pressure PCOGMAX = maximum oil-gas capillary pressure PCOWMIN = minimum oil-water capillary pressure PCOGMIN = minimum oil-gas capillary pressure NPOW = exponent for calculating oil-water capillary pressure NPGL = exponent for calculating gas-liquid capillary pressure Greek letters σ = oil-gas interfacial tension calculated through the MacLeod-Sugden correlation 𝜎0 = referenced interfacial tension when calculating the relative permeability eksig = gas-oil relative permeability index (dimensionless) epsig = gas capillary pressure index (dimensionless) 17 Acknowledgements The authors are grateful for financial support from the National Science and Technology Major Project (Grant No. 2016ZX05016-005 and 2016ZX05016-001), the Major Project of China National Petroleum Corporation (Grant No. RIPED-2020-JS-50214) and (Grant No. RIPED-2020-JS-50215), the project of Sinopec North China Petroleum Bureau (Grant No. 290018276) and project of Petroleum Engineering Technology Institute of SINOPEC Shengli Oilfield (Grant No. 290018276). Nomenclature krg = relative permeability of gas krgcl = krg at connate liquid saturation krw = relative permeability of water krwiro = krw at irreducible oil saturation krow = krw in the presence of the given water saturation krocw = krw at connate water saturation krog = krw in the presence of the given water saturation krogcg = krog at connate gas saturation ng = exponent for calculating krg nw = exponent for calculating krw 0.0 0.2 0.4 0.6 0.8 1.0 0 0.2 0.4 0.6 0.8 1 K rw ， kr o Sw Krw_DST1(1.2mD) Kro_DST1(1.2mD) 0.0 0.2 0.4 0.6 0.8 1.0 0 0.2 0.4 0.6 0.8 1 K rl ， kr g Sl Krl_DST1(1.2mD) Krg_DST1(1.2mD) 16 now = exponent for calculating krow nog = exponent for calculating krog Sgcon = connate gas saturation Sgcrit = critical gas saturation Sl = liquid saturation Slcon = irreducible liquid saturation, Swcon+Soirg
    keywords: co2; curve; flooding; gas; liquid; oil; permeability; pressure; saturation; water
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        item: #13 of 106
          id: iogr-1189
      author: Liu, Shiqi; Sang, Shuxun ; Wang, Tian ; Du, Yi; Fang, Huihuang
       title: Effects of CO2 on the Micron-scale Pore-fracture Structure and Connectivity in Coals from the Qinshui Basin: DOI:10.14800/IOGR.1189
        date: 2021
       words: 6702
      flesch: 60
     summary: Four groups of coal samples were collected from the Qinshui basin, China, including low- volatile bituminous coal from the Xinyuan Mine, semi-anthracite coal from the Yuwu Mine and the Xinjing Mine, and anthracite coal from the Sihe Mine. To prevent further oxidization, coal samples were wrapped in absorbent paper, hermetically sealed in plastic bags and stored at 5 °C after sample collection.
    keywords: co2; coal; et al; figure; fractures; minerals; number; pores; samples; treatment
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        item: #14 of 106
          id: iogr-1190
      author: Doan, Truc (Trevor); Vo, Minh Van
       title: Using Machine Learning Techniques for Enhancing Production Forecast in North Malay Basin: DOI:10.14800/IOGR.1190
        date: 2021
       words: 1988
      flesch: 47
     summary: An accuracy degree of production forecast is required highly based on production data from existing produced wells and future produced wells. By using a huge dataset of production data from thousands of wells in this area, a solution can be rapidly made to automatically eliminate unreliable data in given historical data from existing produced wells.
    keywords: data; figure; learning; machine; production; wells
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        item: #15 of 106
          id: iogr-1194
      author: Ghoreishi, Seyyed Ali; Sedaee, Behnam
       title: Numerical Investigation of the Most Affecting Parameters on Foam Flooding Performance in Carbonate Naturally Fractured Reservoirs: DOI: 10.14800/IOGR.1194
        date: 2022
       words: 4625
      flesch: 51
     summary: Foam injection performed very well in both water-wet and oil-wet scenarios; however, it performed better in the oil-wet case. To face the challenge, varied solutions have been proposed, including foam injection.
    keywords: effect; foam; fracture; gas; gor; injection; matrix; model; oil; permeability; recovery
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        item: #16 of 106
          id: iogr-1195
      author: Zhang, Jie; Wang, Yonghong; Shangguan, Yangnan; Yuan, Guowei; Zhang, Yongqiang; Xiong, Weiliang; Yang, Jinlong; Wang, Lili; Jin, Shuanlian
       title: Optimization Study of Polymer-Surfactant Binary Flooding Parameters in Maling Jurassic Low Permeability Reservoir: DOI: 10.14800/IOGR.1195
        date: 2022
       words: 3389
      flesch: 47
     summary: With the increase of polymer concentration, oil recovery increased. Figure 10—Numerical simulation of the effect of polymer concentration on oil recovery.
    keywords: flooding; injection; oil; polymer; production; recovery; water
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        item: #17 of 106
          id: iogr-1196
      author: Jiang, Shaolong; Zhang, Guoqiang; Yuan, Renguo; Li, Xin; Feng, Enlong
       title: Data Mining: Caliper Prediction Based on Gamma Logging While Drilling: DOI: 10.14800/IOGR.1196
        date: 2022
       words: 4263
      flesch: 47
     summary: The calculation Eq. 1 to 4 are as follows: ���43' = �1���45 + �2���44,………………………………………..………………………………….(1) ��43' = �1��45 + �2��44,……………………………………………….………………………………(2) �1 = �4345 �4445 = �43−�45 2+ �43−�45 2 �44−�45 2+ �44−�45 2,………………………………………………………………………(3) �2 = 1 − �1,………………………………………………………..…………………………………….(4) Where ��� is the caliper, in; �� is gamma, API; �1, �2 are interpolation coefficients, related to geographic location; � is distance between two wells (m); �, � are X and Y coordinates of wellhead, m. Using the interpolation calculation method, we can get the predicted gamma curve and predicted caliper curve of G43 well (expressed with ��43' and ���43' respectively). Figure 9—Scatter fitting relationship between the difference gamma and the measured caliper. 9 ����43 = 0.6872∆���43 + 13.513 (� = 0.5765),………………………….………………………….(5) ����41 = 0.6946∆���41 + 12.911 (� = 0.5635),………………………….…………………………..(6)
    keywords: caliper; curve; data; figure; gamma; glwd; response; � �
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        item: #18 of 106
          id: iogr-1198
      author: Yuan, Guowei; Shanguan, Yangnan; Wang, Min; Zhang, Jie; Du, Zhaofeng
       title: The Phase Behavior Study of Air-foam Flooding in Changqing Ultra-Low Permeability Reservoirs: DOI: 10.14800/IOGR.1198
        date: 2022
       words: 2734
      flesch: 57
     summary: The relative volume of crude oil refers to the ratio of oil-gas volume under the same temperature but different pressures to crude oil volume at bubble point pressure. The critical temperature and critical pressure of crude oil were determined to be 424.4℃ and 9.85MPa.
    keywords: air; gas; oil; phase; pressure; volume
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        item: #19 of 106
          id: iogr-1203
      author: Kieu, Bihn Nguyen; Vo, Minh Van
       title: Smart Seismic Modeling - Artificial Intelligence in the Petroleum Industry: DOI:10.14800/IOGR.1203
        date: 2022
       words: 3819
      flesch: 47
     summary: *Corresponding author: minh.vo@chevron.com 1 Smart Seismic Modeling - Artificial Intelligence in the Petroleum Industry Binh Nguyen Kieu and Minh Van Vo*, Unocal East China Sea Ltd, Chengdu, China Abstract Vertical seismic profile (VSP) data have many known advantages, if being compared to seismic data such as broader bandwidth, less attenuation, clearer under well true depth (TD) image, multiple noise differentiation, shear wave information, direct attenuation and anisotropy measurements, higher fidelity amplitude versus offset (AVO) effect, etc. However, extracting net pay directly from seismic data remains a major challenge.
    keywords: data; figure; inversion; learning; model; modeling; physics; rock; seismic; vsp
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        item: #20 of 106
          id: iogr-1204
      author: Parimontonsakul, Monthep; Lotongkum, Somwipa; Mularlee, Khunalai
       title: A Machine Learning Based Approach to Automate Stratigraphic Correlation through Marker Determination: DOI: 10.14800/IOGR.1204
        date: 2023
       words: 4669
      flesch: 51
     summary: 7 During the first model development, called as marker prediction model, the marker and non-marker data are required as input to the model. (a)The stratigraphic correlation results from the marker prediction model, elaborating few incorrect correlation identifications from connecting identical markers;(b)The stratigraphic correlation results from the marker prediction and marker association model, presenting an improved correlation identifications by complementing the error from marker prediction model.
    keywords: e r; model; p t
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        item: #21 of 106
          id: iogr-1205
      author: Mai-Cao, Lan; Truong-Khac, Hoa
       title: A Comparative Study on Different Machine Learning Algorithms for Petroleum Production Forecasting : DOI: 10.14800/IOGR.1205
        date: 2022
       words: 3001
      flesch: 54
     summary: Different machine learning algorithms for petroleum production forecast are studied in this work for efficiency comparison purpose. The objective of this work is to examine the ability of different machine learning algorithms to predict oil and gas production from historical data of a well currently producing oil from the field X (due to the operator’s requirements, the real name of the field of interest is not shared) in Southern Vietnam.
    keywords: algorithms; data; learning; machine; oil; production; test; time
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        item: #22 of 106
          id: iogr-1207
      author: Qu, Bochao; Ma, Xinle; Dong, Zhenzhen
       title: Interfacial Characterization and Minimum Miscible Pressure Study of CO2 Flooding Based on Molecular Dynamics: DOI: 10.14800/IOGR.1207
        date: 2022
       words: 5146
      flesch: 57
     summary: The NERD molecular force field defines the total potential energy function of an alkane as shown in Eq. 1. 4 �total = bonds ��� � 2 ��� − ���� 2 + ������ ���� � 2 ���� − ����0� 2 + ��ℎ�������0 + �1 1 + ���� +� �2 1 − ��� 2� + �3 1 + ��� 3� + ���������4���� ��� ��� 12 − ��� ��� 6 + ���� 4��0����� .............................................(1) The ZHU CO2 force field function takes the form shown in Eq. 2. �total = bonds ��� � 2 ��� − ���� 2 + ������ ���� � 2 ���� − ����0� 2 + ���������4���� ��� ��� 12 − ��� ��� 6 + ���� 4��0����� ,...............................................(2) Van der Waals interactions between atoms describe the interactions between atoms that are caused by non-covalent and non-hydrostatic forces that attract or repel each other.
    keywords: + �; co2; mmp; oil; pressure; − �; � +; � −; � �
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        item: #23 of 106
          id: iogr-1212
      author: Chen, Cunliang; Zhang, Wei; Yue, Baolin; Liu, Bin
       title: A New Method for Quantitative Description of Dominant Channels in High Water-Cut Stage: DOI: 10.14800/IOGR.1212 
        date: 2023
       words: 3791
      flesch: 53
     summary: Introduction At present, most oil fields in China have entered a period of high water cut, and long-term water injection development has led to the development of dominant channels in the reservoir (Moreno 2013; Fattahpour et al. 2012; Mamghaderi and Pourafshary 2013). The development of dominant channels has led to a large amount of injected water being directly produced by oil production wells, leading to ineffective circulation, exacerbating inter-layer contradictions, resulting in uneven displacement and poor development effects (He et al. 2000; Feng et al. 2009; Lerlertpakdee et al. 2014).
    keywords: channel; dominant; injection; oil; production; reservoir; water
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        item: #24 of 106
          id: iogr-1214
      author: Yanyan Sun, Jiwu Fan, Zhenping Xu, Zhichao Li
       title: Correction to: Application Of Numerical Well Testing In Strong Anisotropic Sandstone Gas Field: DOI: 10.14800/IOGR.1214
        date: 2021
       words: 127
      flesch: 50
     summary: In Strong Anisotropic Sandstone Gas Field Yanyan Sun*, Jiwu Fan, Zhenping Xu, and Zhichao Li, Changqing Oilfield, PetroChina, Xi’an, China In the original publication of this article (Sun et al. 2020), the second author's name Jiu Fan was misspelled. The correct name should have been Jiwu Fan.
    keywords: fan
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        item: #25 of 106
          id: iogr-1215
      author: Zainab Abdulmohsein, Baojun Bai, Parthasakha Neogi
       title: Correction to: Emulsion Stability Of Heavy Oil With Surfactants And Nanoparticles: DOI: 10.14800/IOGR.1215
        date: 2022
       words: 123
      flesch: 41
     summary: CORRECTION Correction to: Emulsion Stability Of Heavy Oil With Surfactants And Nanoparticles Zainab Abdulmohsein, Baojun Bai, and Parthasakha Neogi*, Missouri University of Science and Technology, Rolla, USA Copyright © the authors. The correct name should have been Zainab Abdulmohsein.
    keywords: oil
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        item: #26 of 106
          id: iogr-1219
      author: He, Yawen ; Li, Weirong; Qian, Shihao
       title: Minimum Miscibility Pressure Prediction Method Based On PSO-GBDT Model: DOI: 10.14800/IOGR.1219
        date: 2022
       words: 4084
      flesch: 52
     summary: Data Model Optimization Algorithm Output Input Parameters Mousavi et al. 2008 44 LSSVM Pure and impure CO2 MMP 5 Chen et al. 2014 85 ANN GA Pure and impure CO2 MMP 10 Choubineh et al. 2019 251 ANN MMP of different injected gas and crude oil Dong et al. 2019 ANN L2 Regularization、 Dropout MMP Saeedi and Soleimani 2020 144 ANN TLBO、PSO Pure and impure CO2MMP 8 Tian et al. 2020 152 BP ABC、DA Pure and impure CO2 MMP 5 Zhang et al. 2020 170 BP、RF、SVM Impure CO2 MMP 6 (LSSVM: Least Squares Support Vector Machines; BP: Back Propagation; RF: Random Forest; SVM: support vector machines; TLBO: CO2 Minimum Miscibility Pressure: A Correlation for Impure CO2 Streams and Live Oil Systems.
    keywords: accuracy; co2; learning; miscibility; mmp; model; oil; prediction; pressure
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        item: #27 of 106
          id: iogr-1227
      author: Chen, Yanpeng; Huang, Xiaodong; Dong, Zhen; Shi, Yu
       title: Reservoir Simulation of CO2 Sequestration in Brine Formation: DOI: 10.14800/IOGR.1227
        date: 2023
       words: 4025
      flesch: 51
     summary: Three parameters, including pH, formation pressure, and porosity, strongly related to the safety and effectiveness of CO2 sequestration were calculated and analyzed to assess the dynamic effect of CO2 injection on the saline aquifer. The effects of three factors, including CO2 injection rate, amounts of CO2 injection, and the heterogeneity of saline aquifer on the CO2 storage, were systematically investigated.
    keywords: co2; figure; formation; injection; model; pressure; tons; years
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        item: #28 of 106
          id: iogr-1229
      author: Snosy, Mohamed Fouad; El-Ela, Mahmoud Abu; El-Banbi, Ahmed; Sayyouh, Helmy
       title: Role of the Low Salinity Condensate Water during Steam Injection in Carbonate Reservoirs : DOI: 10.14800/IOGR.1229
        date: 2023
       words: 3565
      flesch: 53
     summary: This study investigates the effects of the low salinity condensed water (LSCW) and anhydrite dissolution on oil recovery during steam injection in carbonate reservoirs. The analysis of the production data of the 9 oil wells was performed to study the effect of anhydrite percentage on oil recovery.
    keywords: anhydrite; carbonate; oil; production; recovery; reservoir; steam; water; wettability
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        item: #29 of 106
          id: iogr-1242
      author: Ogolo, Naomi Amoni; Molokwu, Victor; Onyekonwu, Mike
       title: Effect of Gas Injection Rates on the Performance of a Thin Oil Rim: A Simulation Study : DOI: 10.14800/IOGR.1242
        date: 2023
       words: 3464
      flesch: 53
     summary: 7 Figures 10 and 11 are results of the GOR as gas injection rates vary, and as expected the GOR increased as gas injection rate increased from 5000 to 15000 Mscf/d. However, at gas injection rate of 2500 Mscf/d, the GOR is insignificant compared to higher gas injection rates because of the large volume of encroaching water in the reservoir.
    keywords: gas; injection; oil; production; rate; water
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        item: #30 of 106
          id: iogr-1249
      author: Shi, Qianqian; Li, Weirong; Qian, Shihao; Wei, Xin; Zhang, Tianyang; Pan, Xu
       title: Numerical Simulation of Alkali-Surfactant-Alternated-Gas(ASAG) Injection: Effects of Key Parameters: DOI: 10.14800/IOGR.1249
        date: 2023
       words: 6361
      flesch: 46
     summary: Figure 3—Comparison of oil recovery factor with and water flooding andWAG andASAG. * Corresponding author: weirong.li@xsyu.com.cn 1 Numerical Simulation of Alkali-Surfactant-Alternated-Gas(ASAG) Injection: Effects of Key Parameters Qianqian Shi, Weirong Li*, Shihao Qian,Xin Wei,Tianyang Zhang, and Xu Pan, Xi’an Shiyou University, Xi’an, China Abstract Alkali-surfactant-alternated-gas (ASAG) alternating injection is a method used to enhance oil recovery.
    keywords: asag; factor; figure; gas; injection; oil; rate; recovery; reservoir; water
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        item: #31 of 106
          id: iogr-1250
      author: Butt, Hasan; Ajaz, Osama
       title: Experimental Study on Gas Injection for Ultra Deep and High-pressure Fractured-vuggy Carbonate Oil Reservoirs: DOI: 10.14800/IOGR.1250
        date: 2023
       words: 5339
      flesch: 49
     summary: Production decline at early stages due to rapid pressure decline appears to be the main problem, and water and gas injection via huff-and-puff mode can be applied to maintain oil production. The effects of gravity stabilization and miscibility on oil production were analyzed.
    keywords: co2; gas; huff; injection; model; oil; pressure; production; puff; reservoir
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        item: #32 of 106
          id: iogr-1251
      author: Shajari, Mostafa; Malhani, Hamed
       title: Stimulation of Low Pressure Carbonates Reservoirs with a Triphase Emulsified Acid System "3PEA" of Southern Iran -Case Studies: DOI: 10.14800/IOGR.1251
        date: 2023
       words: 4457
      flesch: 60
     summary: Table 3 and Figure 5 pre-operation and post-operation rate of acidizing jobs candidate wells with low volume 3PEA system. Table 3—Pre-operation and post-operation rate of acidizing jobs candidate wells with low volume 3PEA system.
    keywords: 3pea; acidizing; bbl; pressure; rate; system; volume
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        item: #33 of 106
          id: iogr-1252
      author: Liu, Cheng; Yin, Yanjun; Bai, Ruiting; Liu, Dengke
       title: Pore-scale Imaging of Oil-brine Movement During Waterflooding with Wettability Alteration from Tight Sandstone: DOI: 10.14800/IOGR.1252
        date: 2023
       words: 3370
      flesch: 50
     summary: * Corresponding author: liucheng14@cnooc.com.cn 1 Pore-scale Imaging of Oil-brine Movement During Waterflooding with Wettability Alteration from Tight Sandstone Cheng Liu*, Yanjun Yin, Ruiting Bai, CNOOC EnerTech-Drilling and Production Company, Tianjin, China; Dengke Liu, Xi’an Jiaotong University, Xi’an, China Abstract To clarify the impact of salinity waterflooding on oil displacement efficiency and the microscopic mechanism, we have used micro-CT, nuclear magnetic resonance, high-pressure mercury injection, and other means to conduct an experimental analysis of salinity waterflooding. The results show that imbibition has little contribution to oil displacement efficiency, and the change in wettability is the main microscopic mechanism of low salinity waterflooding.
    keywords: brine; displacement; figure; imbibition; oil; pore; waterflooding
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        item: #34 of 106
          id: iogr-1255
      author: Sidi-Yacoub, Ilhem; Ahmed, Feddag; Ikram, Khelifa
       title: ASPEN-HYSYS Simulation of AREW's Multi-Stage Adiabatic Reactor with Inter-Stage Quenching for Methanol Synthesis: DOI: 10.14800/IOGR.1255
        date: 2023
       words: 5597
      flesch: 54
     summary: Figure 4—Forment's classification of fixed bed reactor models. Analysis and design of fixed bed catalytic reactors: Chapter 1pp 1-55. ACS Publications.
    keywords: bed; catalyst; gas; methanol; process; reaction; reactor; synthesis; temperature
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        item: #35 of 106
          id: iogr-1256
      author: Ajaz, Osama; Tunio, Saleem Qadir; Bhutto, Darya Khan; Soomro, Najeeb Anjum; Shams, Bilal
       title: Coalbed Methane Potential of Pakistan-A Review: DOI: 10.14800/IOGR.1256
        date: 2023
       words: 4165
      flesch: 61
     summary: Gas content in Paran basin is lower as compared to others in Table 1, whereas gas content in coals of Thar is still to be determined. b) Stable production stage: Gas production reaches the maximum while water production moves to its minimum value.
    keywords: cbm; co2; coal; content; ecbm; engineering; gas; methane; pakistan; production; recovery; thar
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        item: #36 of 106
          id: iogr-1261
      author: Zhang, Min; Li, Weirong; Yan, Shide; Wang, Zhengbo; Liu, Zhaoxia; Lin, Keze; Yi, Hongliang
       title: Exploring Influential Factors for Composite Flooding with Polymer Viscosity Reducers in Heavy Oils: DOI:10.14800/IOGR.1261
        date: 2023
       words: 7913
      flesch: 40
     summary: Conclusions In this paper, the effect of oil recovery on chemical composite flooding of heavy oil polymer viscosity reducer was studied, and the following conclusions were drawn: 1. Injecting polymer viscosity reducer composite flooding into heavy oil results in a rapid increase in daily oil production.
    keywords: concentration; flooding; injection; oil; polymer; polymer viscosity; rate; recovery; reducer; viscosity; viscosity reducer; water
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        item: #37 of 106
          id: iogr-1262
      author: Yan, Shide; Li, Weirong; Zhang, Ming; Wang, Zhengbo; Liu, Zhaoxia; Lin, Keze; Yi, Hongliang
       title: An Innovative Method for Comprehensive Optimization of Hydraulic Fracturing Parameters to Enhance Production in Tight Oil Reservoirs: DOI:10.14800/IOGR.1262
        date: 2023
       words: 7344
      flesch: 36
     summary: Figure 22—Structure of NPV fracturing parameters optimization model. The selected machine learning model with best performance is then integrated with an economic evaluation model to establish an optimization model for hydraulic fracturing parameters optimization for tight oil horizontal wells.
    keywords: data; figure; fracturing; gas; hydraulic; learning; machine; model; oil; optimization; parameters; production; recovery; reservoir
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        item: #38 of 106
          id: iogr-1263
      author: Kotb, Mohamed; Abdelalim, Galal; Abdall, Said
       title: Optimization of Oil-Gas Separation in the Production Stations at Abo-Sannan Field: Case Study: DOI: 10.14800/IOGR.1263
        date: 2023
       words: 4693
      flesch: 47
     summary: Table 3(A) provides a detailed overview of the operating conditions, including separator pressure, separator temperature, energy consumption, oil recovery, and gas recovery. Furthermore, Table 3(B) provides details on the optimum operating conditions, including separator pressure, separator temperature, energy consumption, and oil recovery, for the actual two-stages GOSP optimization case (the second case) with an RVP of (10-12) psia.
    keywords: energy; gas; gosp; oil; optimization; plant; pressure; recovery; separation; stage
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        item: #39 of 106
          id: iogr-1267
      author: Elswisy, Ahmed; Elnoby, Mohsen; Salem, Adel
       title: Prediction of Brine Hydrate Formation Temperature Using ANN-Based Model: DOI: 10.14800/IOGR.1267
        date: 2024
       words: 5097
      flesch: 61
     summary: gravity chart to extract (1469) data points of gas hydrate formation pressure, temperature, and specific gravity. To achieve highly accurate forecasts for hydrate formation temperatures in both monovalent and divalent brines, a comprehensive real dataset with a wide range of variations was utilized.
    keywords: ann; brines; data; divalent; figure; formation; gas; hydrate; model; monovalent; pressure; temperature
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        item: #40 of 106
          id: iogr-1268
      author: Hamdan Alibrahim, Mouhannad
       title: Revitalizing Heavy Oil Production A Strategic Transition from Sucker Rod Pumps to Progressive Cavity Pumps: DOI: 10.14800/IOGR.1268
        date: 2024
       words: 6690
      flesch: 51
     summary: Figure 14—Oil production rates of PCP at pressure drops. The high-water content, high sand content, and high oil viscosity are the main issues facing the Tishreen Oil Field, causing a decrease in oil production and maintenance and work-over operations.
    keywords: cavity; cost; efficiency; figure; gas; gravel; oil; pcp; pressure; production; pump; rate; recovery; sucker; wells
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        item: #41 of 106
          id: iogr-1272
      author: Ahmed, Ahmed Moawad
       title: Experimental Work of Nanoparticles-assisted Water Flooding: DOI: 10.14800/IOGR.1272
        date: 2024
       words: 1859
      flesch: 55
     summary: Nanotechnology has been tried in exploration, drilling, production, and enhanced oil recovery. The hydrophilic nanoparticles are mainly used in enhanced oil recovery for strongly oil-wet reservoirs in the wettability alteration mechanism.
    keywords: core; flooding; nanoparticles; oil; recovery; water
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        item: #42 of 106
          id: iogr-1274
      author: Li, Chen; Sun, Lichun; Sun, Hansen; Feng, Ruyong; Wang, Haiqiao; Cao, Jiaohao; Liu, Songnan; Wang, Jian
       title: Key Technology of Efficient Exploitation of Coalbed Methane in Qinshui Basin of CNOOC: DOI: 10.14800/IOGR.1274
        date: 2024
       words: 6403
      flesch: 52
     summary: The error in Table 2 are defined as, Error = �������� ��� �������−���������� ��� ������� �������� ��� ������� × 100%..................................................................................(5 In view of this feature, suspension agent, drainage aid and inhibitor are selected to improve the return of pulverized coal pressure, promote the fracturing fluid backflow, reduce the viscosity of mineral collision, and select a new type of active water fracturing fluid system.
    keywords: block; coal; coalbed; content; development; gas; methane; pressure; production; reservoir; wells; � �
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        item: #43 of 106
          id: iogr-1275
      author: Ajaz, Osama; Tunio, Saleem Qadir; Zafar, Jahangeer
       title: Carbon Sequestration in Unmined Coalbeds of Pakistan: DOI: 10.14800/IOGR.1275
        date: 2024
       words: 3853
      flesch: 58
     summary: Hence, North Dakota coalfield and Rajasthan can be effective reference projects for practical implementation of CO2 storage in Thar coalfields. The research study has recommended further directions for study to calculate exact amount of CO2 storage.
    keywords: carbon; co2; coal; emissions; figure; gas; pakistan; recovery; storage; thar
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        item: #44 of 106
          id: iogr-1280
      author: Dike, Chukwuebuka; Izuwa, Nkemakolam Chinedu; Kerunwa, Anthony; Enyioko, Nzenwa Dan; Ndoma-Egba, Enyang Lilian; Mbah, Chukwuebuka Gabriel; Ogbuatu, Ogonnaya Michael
       title: Parametric Evaluation on the Interfacial Tension Response of Agro-Surfactant: DOI: 10.14800/IOGR.1280
        date: 2024
       words: 4431
      flesch: 51
     summary: Further ACE concentration yielded IFT reduction from 6.95 to 6.92 mN/m and 6.83 at 0.5%wt and 1%wt polymer concentration, respectively. For solutions containing surfactant- containing solution, IFT value drops with increase in salt concentration until optimal salinity stage before further increase in salinity starts to increase IFT (Bera and Mandal 2015).
    keywords: concentration; cpe; ift; oil; polymer; surfactant; vae
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        item: #45 of 106
          id: iogr-1282
      author: Bera, Achinta; Komba, Tiene Bema; Vij, Rakesh
       title: A Case Study on Reservoir Management and Performance Prediction of an Indian Oilfield for Enhanced Oil Recovery : DOI: 10.14800/IOGR.1282
        date: 2024
       words: 10258
      flesch: 63
     summary: Using OFM, graphs for cumulative oil production, oil production rate, liquid production rate, water cut and gas oil ratios are generated. As of follow- up action, a total of 127 out of planned 140 wells were drilled by 1990 and resulted in oil production of 1700 4 tpd which was double of pre-FDP.
    keywords: field; figure; gas; injection; kalol; mmt; oil; pay; pay zone; performance; production; recovery; reservoir; sand; water; wells; zone k
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        item: #46 of 106
          id: iogr-1284
      author: Odo, Jude Emeka; Onyekonwu, Mike Obi; Ikiensikimama, Sunday Sunday; Uzoho, Chidinma Uzoamaka; Ekeoprar, Praise Udodchukwu
       title: Application of Proxy Models for Estimation of Cumulative Recovery Volume from a Heavy Oil Reservoir: DOI: 10.14800/IOGR.1284
        date: 2024
       words: 4737
      flesch: 47
     summary: Proxy models in reservoir engineering are known for their usefulness in approximating relationships within complex reservoir simulation models. (A) 2D Steam drive reservoir model (B) 3D Steam drive reservoir model Figure 2—Steam flooding reservoir simulation model.
    keywords: engineering; flooding; model; oil; proxy; recovery; reservoir; steam
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        item: #47 of 106
          id: iogr-1286
      author: Ahmed, Ibrahim Modibbo; Tunio, Saleem Qadir
       title: Study to Investigate the Potential of Coal Bed Methane (CBM) in Nigeria : DOI: 10.14800/IOGR.1286
        date: 2024
       words: 4229
      flesch: 52
     summary: Nigeria, with over 2 billion metric tons of coal reserves, including 650 million tons of proven reserves (Bureau of Public Enterprises 2006), has significant CBM potential. Key coal quality parameters, such as coal rank, depth, moisture content, ash content, and volatile matter, were analyzed and compared to data from prominent coal basins in the United States, Indonesia, China, India, Australia, and Canada.
    keywords: ash; basins; cbm; coal; content; energy; gas; methane; moisture; nigeria
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        item: #48 of 106
          id: iogr-1288
      author: Deryaev, Annaguly
       title: Analysis of the Commercial Evaluation of Oil Deposits using the Material Balance Method: DOI: 10.14800/IOGR.1288
        date: 2024
       words: 11355
      flesch: 46
     summary: *Corresponding author: deryaevannaguly@gmail.com 1 Analysis of the Commercial Evaluation of Oil Deposits Using the Material Balance Method Annaguly Deryaev*, Scientific Research Institute of Natural Gas of the State Concern “Turkmengas”, Ashgabat, Turkmenistan The study of the commercial evaluation of oil deposits using the material balance method is currently extremely important for the energy industry, as it helps to optimize oil production processes, increase resource efficiency, and make informed decisions on field development in the context of a changing energy paradigm and aspirations for sustainable development.
    keywords: balance; development; gas; material; method; oil; oil deposits; oil production; oil recovery; oil reserves; pressure; reservoir; reservoir pressure; volume; 𝑃0−𝑃; 𝑃0−𝑃 𝑏1−𝑏0
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        item: #49 of 106
          id: iogr-1291
      author: Yossef, Mohamed; Salem, Adel
       title: Developing Dynamic Killing Technique for Off-bottom Killing Condition: DOI: 10.14800/IOGR.1291
        date: 2024
       words: 5551
      flesch: 58
     summary: Pwf = Flowing bottom hole pressure, psi; Qsc = Gas flow rate at surface condition, scf/day; rw = Wellbore radius, ft; re = Reservoir radius, ft; T = Temperature, R; Tann = Annular fluid temperature, oF; Tei = Undisturbed formation temperature, oF; Improved Oil and Gas Recovery 17 Greek: vscrit = Critical gas velocity, ft/sec; vs = Slip velocity, ft/sec; vg = Gas velocity, ft/sec; vl = Liquid velocity, ft/sec; vsg = Superfacial gas velocity, ft/sec; vsl = Superfacial liquid velocity, ft/sec; vGo = Gas slip velocity at ZNLH condiction, ft/sec; vm = Mixture velocity, ft/sec; v∞ = Gas rise velocity, ft/sec; z = Gas compressibility factor, dimensionless; σ = Gas/liquid interfacial tension, lbm/sec2; α = Deviation angle from vertical, degree; μg = Gas viscosity, cp; μl In practice, the well blowout was effectively controlled when the pumping rate was increased to 85 bbl/min, and reignited when the pumping rate was reduced to 80 bbl/min. Figure 5—Arun Field well C-II-2 predicted dynamic killing rate.
    keywords: flow; fluid; gas; kill; killing; liquid; model; pressure; rate; velocity; � �
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        item: #50 of 106
          id: iogr-1292
      author: Saberi, Fatemeh; Vashaghian, Sara; Asoudeh, Pourya; Radwan, Ahmed E.
       title: Computational Fluid Dynamics Study to Access the Effect of Non-Newtonian Fluid Flow Variables on Drilling Mud in Annular Oil Well: DOI: 10.14800/IOGR.1292
        date: 2024
       words: 6022
      flesch: 48
     summary: Introduction Engineers in the oil and gas industry usually face non-Newtonian fluid flow in drilling activities. They obtained the velocity characteristics for Newtonian fluid flow in eccentric annular geometries (Carollo et al 2023; Saberi et al. 2024b; Saberi and Hosseini-Barzi, 2024; Saberi et al. 2023; Vashaghian et al. 2024; Zanjirabadi et al. 2024).
    keywords: drilling; effect; energy; et al; figure; flow; fluid; flux; mass; newtonian; velocity; viscosity
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        item: #51 of 106
          id: iogr-1299
      author: Molokwu, Victor; Ogolo, Naomi Amoni; Onyekonwu, Mike
       title: Gas Cap Size in Thin Oil Rims: Effect on Oil Recovery Efficiency : DOI: 10.14800/IOGR.1299
        date: 2024
       words: 3762
      flesch: 51
     summary: This simulation study investigates the impact of gas cap size on oil recovery efficiency under the influence of both strong and weak aquifers, utilizing data from a thin oil rim in the Niger Delta. The results indicate that oil recovery efficiency ranges from 29% to 31% in scenarios with large gas caps, whereas scenarios with small gas caps achieve recovery efficiencies between 49% and 62%.
    keywords: cap; caps; drive; gas; oil; production; recovery; scenarios
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        item: #52 of 106
          id: iogr-1302
      author: Hassan, Umar; Hamza, Mohammed Falalu; Soleimani, Hassan; Abdulkadir, Bashir Abubakar; Shehu Imam, Saifullahi; Saleh, Sabiha Hanim
       title: An Interaction between Moringa Oleifera Biosurfactant and Nanoparticles for Foam Stability, Interfacial Tension Reduction and Wettability Alteration: DOI: 10.14800/IOGR.1302
        date: 2024
       words: 8491
      flesch: 51
     summary: Nomenclature A = Volume of KOH solution; B = Blank ; b = Adsorption affinity coefficient, 1/mg; Ce = Equilibrium concentration, mg/L; Ci = Initial concentration, wt% or mg/L; Cf = Final concentration, wt% or mg/L; CA = Contact angle, o; CEOR = Chemical Enhanced Oil Recovery; CMC = Critical Micellar Concentration; D = Drop diameter, m; EOR = Enhanced oil recovery; FTIR = Fourier transform infrared spectroscopy; IFT = Interfacial tension; K = Freundlich constant; KOH = Potassium hydroxide; M = Mass, g; M = Molarity, mol/L; M1 = Initial mass, g; M2 = Final mass, g; Mbpd = Millions barrel per day; MS = Moringa Oleifera surfactant; MO = Moringa Oleifera oil; N = Normality, eq/L; n = Freundlich exponent; NPs = Nanoparticles; OOIP = Original oil in-place; Qe = Amount adsorbed per unit weight of the adsorbent, mg/g; Moringa oleifera (MO) is a plant native to India, commonly found in tropical and subtropical regions worldwide (Kalibbala et al. 2009)
    keywords: adsorption; chemical; concentration; contact; et al; figure; foam; gas; hamza; ift; journal; moringa; oil; oleifera; recovery; snps; surfactant; time
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        item: #53 of 106
          id: iogr-1305
      author: Babayev, Masud; Penkov, Grigorii; Asadov, Sardar
       title: Enhancing SAGD Efficiency: A Study on Steam Quality and Injection Rate Optimization: DOI: 10.14800/IOGR.1305
        date: 2024
       words: 3721
      flesch: 48
     summary: The primary challenge in heavy oil production is the high viscosity of the oil. *Corresponding author: masud.babayev2022@khazar.org 1 Enhancing SAGD Efficiency: A Study on Steam Quality and Injection Rate Optimization Masud Babayev* and Grigorii Penkov, Khazar University, Baku, Azerbaijan; Sardar Asadov, University of Tulsa, Oklahoma, USA Abstract The production of heavy oil presents a significant challenge due to its high viscosity, which limits natural flow.
    keywords: bbl; figure; injection; oil; quality; rate; recovery; sagd; steam
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        item: #54 of 106
          id: iogr-1308
      author: Shafiq, Mian Umer; Vivegananthan, Deena N.; Khan, Momna; Ben Mahmud, Hisham; Wang, Lei; Jamil, Maryam
       title: Experimental Investigation of Agricultural Wastes Effect on Drilling Mud Properties : DOI: 10.14800/IOGR.1308
        date: 2024
       words: 6538
      flesch: 56
     summary: Initially, drilling mud was formulated with clay; however, to manage high-pressure formations, a higher density mud was required, which led to the addition of heavy minerals. Disadvantages Advantages The salt can be dissolved which increased mud weight Cost-effective and cheap Hydrocarbon flow can be impeded by WBDF Environmentally friendly in some sense WBDF supports the dispersal and disintegration of clays Easy accessibility and availability WBDF is incompetent to penetrate shale or water-sensitive shale Fast penetration rate The ability of WBDF to corrode iron components To mitigate harmful environmental impacts, Hector et al. (2002) explored the use of potassium silicate in drilling mud, which was later repurposed as a fertilizer.
    keywords: additives; ash; drilling; figure; filtrate; fluid; husk; loss; mud; oil; rice; water
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        item: #55 of 106
          id: iogr-1312
      author: Anyadiegwu, Charlie Iyke; Okalla, Christian Emelu; Kerunwa, Anthony; Igbo, Solomon Chukwuebuka; Abah, Joshua Abiodun
       title: Comparative Analysis of Linear Regression and Artificial Neural Networks for Permeability Prediction in Reservoir Characterization: DOI: 10.14800/IOGR.1312
        date: 2024
       words: 5402
      flesch: 47
     summary: Traditional methods for predicting these properties often rely on linear regression models, which, while straightforward and interpretable, may not fully capture the complex, non-linear relationships present in subsurface geological formations (Leiphart and Hart 2001). The choice between linear regression models and ANNs is not merely a technical decision but one that can significantly impact the accuracy and reliability of permeability predictions.
    keywords: ann; data; dataset; gas; linear; model; network; oil; permeability; regression; reservoir
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        item: #56 of 106
          id: iogr-1313
      author: Anyadiegwu, Charlie Iyke C.; Okalla, Christian; Kerunwa, Anthony; Ebosie, Precious; Nwachukwu, Daniel
       title: Effect of Hydrate on the Deliverability of Underground Gas Storage (UGS) Reservoir : DOI: 10.14800/IOGR.1313
        date: 2024
       words: 4378
      flesch: 53
     summary: Gas hydrate management. These computations facilitated the generation of gas flow rates and the plotting of IPR and TPR curves for different hydrate thicknesses.
    keywords: deliverability; engineering; film; flow; gas; hydrate; pressure; reservoir; storage; thickness
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        item: #57 of 106
          id: iogr-1314
      author: Dong, Zhenzhen; Hou, Tong; Yang, Zhanrong; Zou, Lu; Li, Weirong; Yi, Hongliang; Liu, Zhilong
       title: Effect of Surfactants on the Minimum Miscible Pressure of CO2 with Crude oil from the Chang-8 Oilfield using Molecular Dynamics Simulations: DOI: 10.14800/IOGR.1314
        date: 2024
       words: 6416
      flesch: 43
     summary: The paper is structured as follows: the introduction reviews methods and the current state of research on reducing miscibility pressure between CO2 and crude oil; the second section outlines fundamental theories and research methods; the third section delves into surfactants’ mechanisms affecting CO2 and crude oil miscibility; and the final section presents discussion and conclusions. With prolonged simulation time, the solubility of CO2 in crude oil increases, resulting in the formation of CO2 clusters around crude oil molecules.
    keywords: co2; crude; gas; minimum; miscibility; oil; pressure; recovery; surfactant; system; temperature; tension
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        item: #58 of 106
          id: iogr-1320
      author: Kerunwa, Anthony; Ndoma-Egba, Lilian Enyang; Nwachukwu, Angela; Uwaezuoke, Nnaemeka; Enyioko, Nzenwa Dan; Duru, Ugochukwu Ilozurike; Dike, Chukwuebuka
       title: Performance Study of Afzeila Africana-Marantha Arundinacea Nanoparticles Assisted for Fluid Loss Control in Water-Based Drilling Fluid: DOI: 10.14800/IOGR.1320
        date: 2024
       words: 5790
      flesch: 57
     summary: In this study, the efficacy of polymer-assisted nanoparticles for fluid loss control was evaluated. These studies demonstrated varying degrees of success, highlighting the potential of local materials in fluid loss control.
    keywords: cmc; control; drilling; fluid; loss; mar; mud; nil; sio2; wbdf
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        item: #59 of 106
          id: iogr-1325
      author: Ezeoke, Tobechukwu; Izuwa, Nkemakolam Chinedu; Amosu, Adegoke; Oghenetejiri, Igbereyivwe; Dike, Humphery; Anyanwu, Placid; Dike, Chukwuebuka Francis
       title: Application of Thermochemical in Removing Condensate Banking in Gas Condensate Reservoirs: DOI: 10.14800/IOGR.1325
        date: 2024
       words: 5181
      flesch: 35
     summary: Abstract The accumulation of liquid near the wellbore, induced by condensate banking in gas condensate reservoirs, significantly impairs gas production rates, presenting a substantial challenge for hydrocarbon recovery. Core flooding experiments demonstrated that the injection of thermochemical fluids consistently led to higher condensate recovery than CO2 injection across all tested core samples.
    keywords: condensate; engineering; gas; injection; oil; pressure; reaction; recovery; temperature; thermochemical
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        item: #60 of 106
          id: iogr-1326
      author: Mohammed, Hussein; Okalla, Christian Emelu
       title: Modelling Annual Natural Gas Demand Forecasting Using Non-Linear Autoregressive with Exogenous Input (NARX) Neural Networks: DOI: 10.14800/IOGR.1326
        date: 2024
       words: 6051
      flesch: 48
     summary: The NARX model, known for its capability to handle nonlinear time series data with external inputs, was applied using key variables such as population, GDP per capita, natural gas reserves, and price, with the target output being natural gas demand. These findings demonstrate the effectiveness of the NARX model for forecasting natural gas demand, making it a valuable tool for energy planning and decision- making in Nigeria.
    keywords: data; demand; energy; et al; forecasting; gas; gas demand; model; mse; narx; time; training
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        item: #61 of 106
          id: iogr-1328
      author: Javanbakht, Vahid; Fatemi, Masoud; Mehrabi, Maryam
       title: Separation of Aromatic Compounds from Normal Paraffinic Petroleum Mixture Using Geopolymer Adsorbent Based on Metakaolin: DOI: 10.14800/IOGR.1328
        date: 2024
       words: 3153
      flesch: 42
     summary: The amount of aromatic removal by the adsorbent was determined using the initial concentration C0 (mg/L), and the final concentration Cf (mg/L) using the following equation, Aromatic removal (%) = C0−Cf C0 × 100% ............................................................................................................ Furthermore, increasing the adsorbent dosage from 0.001 to 0.1 g/L in petroleum samples led to an increase in aromatic compound removal.
    keywords: adsorbent; chemical; compounds; figure; geopolymer; removal; separation
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        item: #62 of 106
          id: iogr-1329
      author: Khan, Muhammad Jawad; Aziz, Sajjad; Muhammad Asad; Kirmani, Farzain ud din; Aziz, Hassan; Alakbari, Fahd Saeed
       title: Investigating the Impact of Water and Polymer Flooding Techniques on Reservoir Performance in Heterogeneous Unconsolidated Formations: DOI: 10.14800/IOGR.1329
        date: 2025
       words: 6849
      flesch: 42
     summary: This study evaluates the comparative performance of water flooding and polymer flooding with respect to oil production rates, cumulative production, recovery factors, and the timing of water breakthrough. The study further conducted a sensitivity analysis of polymer flooding, focusing on various injection well configurations, with an emphasis on the five-spot pattern, to identify the optimal injection strategy.
    keywords: efficiency; figure; flooding; oil; pattern; polymer; polymer flooding; production; recovery; reservoir; spot; water
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        item: #63 of 106
          id: iogr-1334
      author: Mohammed, Hussein; Onyejekwe , Ifeanyichukwu Michael; Onwukwe, Stanley Ibuchukwu
       title: Investigation of Locally Sourced Sand as Proppants in Hydraulic Fracturing Operations: DOI: 10.14800/IOGR.1334
        date: 2025
       words: 7034
      flesch: 61
     summary: Table 6 shows that the turbidity for quartz sand was 2.8 NTU, while for topaz sand was 3.83 NTU. The maximum closure stress level was reached at 3000 psi with a percentage of fines generated to be 10.89% for quartz sand and 10.33% for topaz sand.
    keywords: fracturing; hydraulic; oil; proppant; quartz; quartz sand; results; sand; sieve; sphericity; test; topaz; topaz sand
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        item: #64 of 106
          id: iogr-1336
      author: Uwaezuoke, Nnaemeka; Onya, Oko Emmanuel; Nnaji, Okechukwu Christopher; Dike, Chukwuebuka Francis; Onwukwe, Ibuchukwu Stanley
       title: Performance Evaluation of Palm Kernel Shell as Pitting Corrosion Inhibitor: DOI: 10.14800/IOGR.1336
        date: 2024
       words: 4883
      flesch: 51
     summary: Chinwego (2017) carried out corrosion inhibition study in NaCl using a blend of palm and jatropha leaf. Kumar and Mohana (2014) utilized pterolobium hexpetalum and celosia argentea for corrosion inhibition using weight loss and electrochemical impedance spectroscopy.
    keywords: calc; corrosion; engineering; figure; gaussian; inhibition; kernel; oil; palm; petroleum; shell; wt.%
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        item: #65 of 106
          id: iogr-1337
      author: Idudje, Henry E.; Nwachukwu, Angela N.; Duru , Ugochukwu I.; Onyejekwe, Michael I.; Onwukwe, Stanley I.
       title: Application of Electrokinetics-Assisted Flooding for Enhanced Oil Recovery in Niger Delta: DOI: 10.14800/IOGR.1337
        date: 2025
       words: 7337
      flesch: 53
     summary: X1 X2 X3 X4 Y Nano Fluid Concentration (wt %) Current density(volt) Core porosity (%) Simultaneous flooding Oil recovery (ml) 0.01 2 0.245 1 9 0.02 2 0.245 1 9.5 0.01 4 0.245 1 10.3 0.02 4 0.245 1 11.5 0.01 6 0.245 1 12.3 0.02 6 0.245 1 13.5 0.01 8 0.245 1 13.8 0.02 8 0.245 1 15.3 0.01 2 0.18 1 5 0.02 2 0.18 1 5.3 0.01 4 0.18 1 5.5 0.02 4 0.18 1 5.8 0.01 6 0.18 1 5.7 0.02 6 0.18 1 6.9 0.01 8 0.18 1 6.2 0.02 8 0.18 1 7.8 0.01 2 0.245 2 3.3 0.02 2 0.245 2 4.2 0.01 4 0.245 2 3.8 0.02 4 0.245 2 4.8 0.01 6 0.245 2 4.5 0.02 6 0.245 2 6.2 0.01 8 0.245 2 6.5 0.02 8 0.245 2 7 0.01 2 0.18 2 2.4 0.02 2 0.18 2 3 0.01 4 0.18 2 2.9 0.02 4 0.18 2 3.3 0.01 6 0.18 2 3.5 0.02 6 0.18 2 4.2 0.01 8 0.18 2 3.8 0.02 8 0.18 2 4.6 Improved Oil and Gas Recovery 16 Table 19—Surfactant core flooding experimental data. Core Porosity (%) Simultaneous flooding Oil recovery (%) 0.01 2 0.245 1 8.0 0.02 2 0.245 1 9.0 0.03 2 0.245 1 11.5 0.01 4 0.245 1 9.0 0.02 4 0.245 1 10.2 0.03 4 0.245 1 11.7 0.01 6 0.245 1 10.0 0.02 6 0.245 1 11.3 0.03 6 0.245 1 12.5 0.01 8 0.245 1 10.3 0.02 8 0.245 1 11.9 0.03 8 0.245 1 13.0 0.01 2 0.18 1 4.50 0.02 2 0.18 1 6.80 0.03 2 0.18 1 7.20 0.01 4 0.18 1 4.80 0.02 4 0.18 1 6.20 0.03 4 0.18 1 6.80 0.01 6 0.18 1 4.70 0.02 6 0.18 1 6.40 0.03 6 0.18 1 6.80 0.01 8 0.18 1 4.80 0.02 8 0.18 1 5.80 0.03 8 0.18 1 7.30 0.01 2 0.245 2 2.8 0.02 2 0,245 2 3.1 0.03 2 0.245 2 3.6 0.01 4 0,245 2 3.0 0.02 4 0.245 2 3.3 0.03 4 0,245 2 4.0 0.01 6 0.245 2 3.0 0.02 6 0,245 2 3.2 0.03 6 0.245 2 4.4 0.01 8 0,245 2 3.8 0.02 8 0.245 2 4.0 0.03 8 0,245 2 5.0 0.01 2 0.18 2 1.80 0.02 2 0.18 2 2.00 0.03 2 0.18 2 2.80 0.01 4 0.18 2 2.10 0.02 4 0.18 2 2.60 0.03 4 0.18 2 2.90 0.01 6 0.18 2 2.20 0.02 6 0.18 2 2.00 0.03 6 0.18 2 2.50 0.01 8 0.18 2 2.40 0.02 8 0.18 2 2.60 0.03 8 0.18 2 3.20 Improved Oil and Gas Recovery 17
    keywords: apg; concentration; core; eor; flooding; nanofluid; oil; recovery; seq; surfactant
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        item: #66 of 106
          id: iogr-1341
      author: Udechukwu, Mathew Chidubem; Okalla, Christian; Kerunwa, Anthony; Enyioko, Nzenwa Dan; Ohanaga , Chidera Prince; Dike, Francis Chukwuebuka
       title: Evaluation of Wax Inhibition in Crude Oil Pipelines Using Extracts from Moringa Seeds and Lime: DOI: 10.14800/IOGR.1341
        date: 2024
       words: 6932
      flesch: 48
     summary: Crude oil wax: A review on formation, experimentation, prediction, and remediation techniques, Petroleum Science 19(5):2343-2357. *Corresponding author: christian.okalla@futo.edu.ng 1 Evaluation of Wax Inhibition in Crude Oil Pipelines Using Extracts from Moringa Seeds and Lime Mathew Chidubem Udechukwu, Christian Emelu Okalla*, Anthony Kerunwa, Nzenwa Dan Enyioko, Chidera Prince Ohanaga, and Francis Chukwuebuka Dike, Federal University of Technology Owerri, Owerri, Nigeria Abstract Wax deposition in crude oil pipelines is a significant operational challenge, particularly in low-temperature environments such as offshore installations, where wax crystallization hinders flow.
    keywords: crude; deposition; extract; inhibitors; moringa; oil; petroleum; point; sample; stretch; table; wax
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        item: #67 of 106
          id: iogr-1344
      author: Aniyom, Ebenezer; Chikwe, Anthony
       title: Prediction of Leak on Gas Pipeline Using a Hybrid Machine Learning Model: DOI: 10.14800/IOGR.1344
        date: 2025
       words: 5023
      flesch: 56
     summary: Still on the application of machine learning models, Alkhudhair et al. (2022) used machine learning models to predict anomaly that exist in the pipeline. Thus, it is that form of machine learning model which works on structured dataset (data in rows and columns) with well-defined features.
    keywords: data; detection; gas; leak; learning; machine; models; oil; pipeline; � �
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        item: #68 of 106
          id: iogr-1346
      author: Kerunwa, Anthony; Emenike, Bright Udochi K.; Ekejiuba, Azunna I.B.; Uwaezuoke, Nnaemeka; Okalla, Christian Emelu; Dike, Chukwuebuka Francis
       title: Investigation of Oryza Glaberrima Nanoparticle-Assisted Fluid Loss Control in Water-Based Drilling Mud: DOI: 10.14800/IOGR.1346
        date: 2025
       words: 6532
      flesch: 52
     summary: This study evaluates the efficacy of Oryza glaberrima (African rice husk, RH)-nanosilica (NS) composites as fluid loss control agents in water-based drilling mud (WBM). The findings aim to provide insights into the potential of Oryza glaberrima nanoparticles as a sustainable and efficient alternative for fluid loss control in water-based drilling muds.
    keywords: cake; cmc; control; drilling; fluid; loss; loss control; mud; pac; wbm
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        item: #69 of 106
          id: iogr-1348
      author: Rezaei, Mustafa
       title: A Capillary Pressure-Driven Empirical Model for Permeability Estimation in Carbonate Reservoirs: DOI: 10.14800/IOGR.1348
        date: 2025
       words: 4089
      flesch: 43
     summary: The first category includes permeability models based on percolation theory, which assumes that flow paths in porous media can be represented by a single-scale aperture. The second category includes permeability models based on Poiseuille's equation and Darcy's law, which conceptualize flow paths in porous media as a collection of capillary tubes.
    keywords: carbonate; data; journal; mercury; model; permeability; porosity; pressure
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        item: #70 of 106
          id: iogr-1349
      author: Chikwe, Anthony Ogbaegbe; Okalla, Christian Emelu; Diovu, Prayer Samuel
       title: Technical Evaluation of Formation Damage Remediation in Niger Delta Clastic Reservoirs: DOI: 10.14800/IOGR.1349
        date: 2025
       words: 4888
      flesch: 44
     summary: A lower value of this coefficient implies that the wellbore is more efficient in transmitting reservoir pressure changes to the formation, which is generally a favorable characteristic for well performance. C 0.00734 bbl/psi Skin (s) 6.11 Reservoir and boundary parameters Initial reservoir pressure 6417.58 psia Permeability thickness product (k*h) 631 md×ft Permeability (k) 3.15 md Derived and secondary parameters Drainage radius (re) 214 ft Tested volume 7.0514 MMB Delta P (Total skin) 1243.59 psi Improved Oil and Gas Recovery 8 PTA Result Analysis on Well P After Acidizing.
    keywords: acidizing; damage; data; formation; permeability; plot; pressure; reservoir; skin; wellbore
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        item: #71 of 106
          id: iogr-1351
      author: Bin Marta, Ebrahim; Mohamed Soliman, Mohammed Moustafa; Khamis, Mohamed Ali; Wahba, Ali Moustafa
       title: Diagnosis and Control of Excessive Water Production in a Yemeni Oilfield: DOI: 10.14800/IOGR.1351
        date: 2025
       words: 6439
      flesch: 51
     summary: Water production has increased, and oil production has simultaneously decreased, which means these wells have a problem with water production. Water production commonly exhibits an immediate increase in tandem with oil production in wells experiencing water production issues (Figure 4).
    keywords: data; et al; figure; gas; issues; oil; production; recovery; shut; water; water production; wells; wor
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        item: #72 of 106
          id: iogr-1352
      author: Chikwe, Anthony Ogbaegbe; Okalla, Christian Emelu; Olabode, Oluwasanmi; Uduak, Abigail lnemesit
       title: A Comparative Study of the Rheological Properties Under HPHT Conditions: DOI: 10.14800/IOGR.1352
        date: 2025
       words: 5436
      flesch: 49
     summary: The analysis of the rheological properties of the samples, including the base fluid, SiO₂ nanoparticle suspensions in water- based mud, almond oil-based mud, and diesel oil- based mud, reveals significant insights into their potential applications and suitability for various industrial purposes. This pattern underscores the significant influence that SiO2 concentration has on the dial readings of mud samples under varying rotational speeds.
    keywords: almond; drilling; fluid; mud; nanoparticles; oil; properties; sample; sio2; water
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        item: #73 of 106
          id: iogr-1353
      author: Kerunwa, Anthony; Ibewuike, Chimuanya Winifred; Ndoma-Egba, Lilian Enyang; Okereke, Ndubuisi; Dike, Chukwuebuka Francis
       title: An Investigation into the Optimization of Electrically Submersible Pumps through the Application of Machine Learning: DOI: 10.14800/IOGR.1353
        date: 2025
       words: 3904
      flesch: 52
     summary: Several studies have been carried out on oil production by ESP design, but these studies have not considered the impact of these ESP design parameters in oil rate production. This striking similarity between the predicted rates from this study and the actual field data serves to validate and reinforce the effectiveness and reliability of the proposed RF-ML algorithm in accurately forecasting oil production rates.
    keywords: data; engineering; gas; model; oil; production; pump; rate; recovery
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        item: #74 of 106
          id: iogr-1354
      author: Chikwe, Anthony Ogbaegbe; Igwe, Valentine; Dike, Chukwuebuka Francis; Aghaulor, Gift; Odo, Jude Emeka
       title: Enhanced Gas Condensate Recovery by Injection of Produced Hydrocarbon Gas: DOI: 10.14800/IOGR.1354
        date: 2025
       words: 4246
      flesch: 46
     summary: Through the application of a Box- Behnken experimental design, a spectrum of parameter combinations was generated to conduct simulation experiments, yielding outcomes such as cumulative oil production and cumulative gas production. Subsequently, response surface models were constructed using response surface methodology, revealing a dependable correlation between cumulative oil production and cumulative gas production with independent parameters.
    keywords: condensate; gas; models; oil; production; recovery; reservoir
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        item: #75 of 106
          id: iogr-1355
      author: Chikwe, Anthony Ogbaegbe; Awah, Chukwudozie Ian; Dike, Chukwuebuka Francis
       title: Study On Hydrate Formation Potential in Natural Gas Pipeline: DOI: 10.14800/IOGR.1355
        date: 2025
       words: 2995
      flesch: 46
     summary: Also, precise measurement of hydrocarbon dew points is vital in achieving safe and efficient transportation through natural gas pipelines specific for single phase fluids (Shoaib et al. 2018). The study examined the formation of hydrates and the deposition of hydrocarbon slugs, which are primary concerns in gas pipelines that can lead to significant environmental damage and substantial financial repercussions.
    keywords: dew; formation; gas; hydrate; hydrocarbon; pipeline; temperature
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        item: #76 of 106
          id: iogr-1356
      author: Usuolori, Blessed Oghenevieze; Izuwa, Nkemakolam Chinedu; Kerunwa, Anthony; Nwogu, Ngozi Claribelle; Dike, Chukwuebuka Francis
       title: A Study of Geothermal Energy Prospect from Abandoned Oil and Gas Wells in Nigeria: DOI: 10.14800/IOGR.1356
        date: 2025
       words: 4460
      flesch: 49
     summary: The simulation of the wellbore heat loss for geothermal heat extraction using water and CO2 as geofluids are performed in this section. Historically, geothermal energy has been utilized for centuries in regions like Japan, Rome, and China, primarily through hot springs.
    keywords: btu; co2; energy; engineering; gas; geothermal; heat; oil; reservoir; water; wells
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        item: #77 of 106
          id: iogr-1357
      author: Elhossieny, Mohamed Saad; Attia, Attia M.; Abuseda, Hesham; Gouish, Ahmed; Salem, Adel M.
       title: Exploring the Impact of Multiwall Carbon Nanotubes on Enhancing Water-Based Mud Performance: DOI: 10.14800/IOGR.1357
        date: 2025
       words: 4081
      flesch: 49
     summary: 9 8.6 8.5 8.45 8.4 8.25 Base Base + 0.125 g MWCNT Base + 0.250 g MWCNT Base + 0.500 g MWCNT Base + 0.750 g MWCNT Base + 1.250 g MWCNT F il tr at io n , m L Base Base + 0.125 g MWCNT Base + 0.250 g MWCNT Base + 0.500 g MWCNT Base + 0.750 g MWCNT Base + 1.250 g MWCNT 0.2 0.22 0.23 0.25 0.26 0.29 Base Base + 0.125 g MWCNT Base + 0.250 g MWCNT Base + 0.500 g MWCNT Base + 0.750 g MWCNT Base + 1.250 g MWCNT C ak e T h ic k n es s, m m Base Base + 0.125 g MWCNT Base + 0.250 g MWCNT Base + 0.500 g MWCNT Base + 0.750 g MWCNT Base + 1.250 g MWCNT Improved Oil and Gas Recovery 8 Conclusions This study demonstrates that multi-walled carbon nanotubes (MWCNTs) significantly enhance the rheological and filtration performance of water-based drilling mud. Recent advances in nanotechnology suggest that nanoscale additives, such as uniformly dispersed carbon nanotubes (CNTs), can significantly improve the thermorheological performance of drilling fluids compared to conventional formulations.
    keywords: base; base base; concentration; drilling; engineering; fluid; mud; mwcnt; petroleum; viscosity
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        item: #78 of 106
          id: iogr-1358
      author: Raafat, Mohamed; Mohamed Khattab, Hamid; Moustafa Wahba, Ali
       title: Gas Recycling Optimization in Gas Condensate Reservoirs Using 3D Compositional Modeling: DOI: 10.14800/IOGR.1358
        date: 2025
       words: 5905
      flesch: 44
     summary: Upon the reduction of the flowing bottomhole pressure in gas condensate wells below the dewpoint pressure, a marked decrease in productivity is noted. To enhance the recovery of condensate from gas condensate reservoirs, an array of secondary and tertiary recovery methods is implemented.
    keywords: condensate; gas; gas condensate; injection; models; pressure; production; quality; recovery; reservoir; stb; wells
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        item: #79 of 106
          id: iogr-1359
      author: Igwilo, Chinwuba Kevin; Nduji, Obiukwu David; Uwaezuoke, Nnaemeka; Dike, Chukwuebuka Francis
       title: Performance Evaluation of Mucuna Solanie and Periwinkle Shell Inhibitors as Anti-Coating Agents for Corrosion Inhibition: DOI: 10.14800/IOGR.1359
        date: 2025
       words: 4546
      flesch: 47
     summary: A weight loss methodology was employed to assess corrosion rates under simulated acidic (HCl), saline (3.5 wt.% NaCl), and microbial (sulfate-reducing bacteria) conditions, reflecting common oilfield operational environments. Corrosion rates are modulated by environmental variables, including dissolved salts, acidic species, microbial activity, flow velocity, and temperature gradients (Schweitzer 2007).
    keywords: coating; control; corrosion; corrosion rate; environment; mucuna; pipe; rate; week
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        item: #80 of 106
          id: iogr-1362
      author: Shafiq, Mian Umer; Hisham Ben Mahmud; Lei Wang; Maryam Jamil; Sophia Nawaz Gishkori
       title: Mineral Analysis of Dolomite Formation During Carbonate Acidizing Using Chelating Agents: DOI: 10.14800/IOGR.1362
        date: 2025
       words: 6721
      flesch: 42
     summary: To address these challenges, chelating agents have been introduced as an alternative for reacting with dolomite formations. Improved Oil and Gas Recovery 8 Figure 6—Mineral mass in Guelph dolomite when reacted with chelating agents.
    keywords: acid; acidizing; agents; analysis; ankerite; calcite; chelating; dissolution; dolomite; figure; glda; guelph; hedta; mineral
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        item: #81 of 106
          id: iogr-1364
      author: Alhwayzee, Mohammed; Asad, Maaly; AL-Dujaili, Ahmed; Nasrawi, Nabeel
       title: Optimal Miscible CO2 Injection for Enhanced Oil Recovery: A Case Study of the Asmari Formation in the Abu Ghirab Oil Field, Southeastern Iraq: DOI: 10.14800/IOGR.1364
        date: 2025
       words: 4779
      flesch: 50
     summary: However, a decline in oil production is expected from late 2028 to 2030, suggesting that an alternative enhanced oil recovery (EOR) method should be considered for continued oil recovery beyond this period. Improved Oil and Gas Recovery 5 Figure 5—Stratigraphic column of Abu Ghirab (Al-Khafaji et al. 2019) Data and Methods This study offers a detailed analysis of enhanced oil recovery (EOR) methods applied to the Asmari Formation in the Abu Ghirab Field, concentrating on optimizing oil production through various injection techniques.
    keywords: co2; field; figure; gas; injection; miscible; oil; production; recovery; reservoir
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        item: #82 of 106
          id: iogr-1366
      author: Khalil, Abdulkareem Abbas; Baker, Hussain Ali; Naseef, Hiba Alaa; AL-Dujaili, Ahmed N.
       title: Effect of Residual Oil Saturation on Oil Recovery and Reservoir Performance for Mishrif Formation in Southern Iraqi Oil Field: DOI: 10.14800/IOGR.1366
        date: 2025
       words: 8753
      flesch: 52
     summary: The residual oil saturation (SOR) is the level of oil saturation above which the oil becomes movable. 1/7/1998 1/7/2002 48 3080 BU-18 1/1/2003 1/1/2007 48 3300 BU-19 1/1/2001 1/10/2002 22 2600 BU-20 1/1/2000 1/1/2001 12 2350 1/1/2002 1/6/2002 60 2550 Improved Oil and Gas Recovery 18 Figure 17—Field oil production rate (calculated vs. observed) with corresponding field pressure.
    keywords: et al; field; figure; gas; model; oil; permeability; porosity; pressure; production; recovery; reservoir; saturation; sor; water
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        item: #83 of 106
          id: iogr-1367
      author: Uwaezuoke, Nnaemeka; Henry Onyedikachi, Eruchalu; Joseph Uchenna, Anuforo; Nmesoma Noble, Emmanuel; Chibueze Valentine, Iroagba; Daniel Enyioko, Nzenwa; Ivan Onyebuchi, Nwanwe
       title: Causticized Application of Low-Carbon Lignite for PH And Fluid Loss Control in An Aqueous Mud System: DOI: 10.14800/IOGR.1367
        date: 2025
       words: 3564
      flesch: 53
     summary: It was observed that the mixture of Nigerian lignite and corn cobs had a lower fluid loss than the corn cobs and lignite considered separately. The present study undertakes an assessment of the efficacy of Nigerian lignite in mitigating fluid loss within water-based mud systems.
    keywords: control; drilling; engineering; fluid; lignite; loss; mud; petroleum; technology; water
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        item: #84 of 106
          id: iogr-1369
      author: Shamsuddin , Mohammad Na’il; Busahmin, Bashir
       title: Drilling Optimization through Rig Hydraulics Using a Mathematical Model: DOI: 10.14800/IOGR.1369
        date: 2025
       words: 3512
      flesch: 54
     summary: This paper aims to enhance drilling performance by optimizing hydraulic parameters, including flow rate, jet impact force, and equivalent circulating density, through a mathematical modeling approach. Rate of penetration against weight on bit; (b) Rate of penetration against flow rate; (c) Rate of penetration against jet impact force; (d) Rate of penetration against hydraulic horsepower.
    keywords: bit; drilling; flow; force; impact; jet; penetration; rate; rop
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        item: #85 of 106
          id: iogr-1370
      author: Ma, Xueling; Zou, Lu; Yang, Zhanrong; Hou, Tong; Li, Weirong; Lin, Keze; Yi, Hongliang; Liu, Zhilong
       title: Hydrogen Storage Optimization in the T Gas Field Numerical Simulation Insights from the Ordos Basin: DOI: 10.14800/IOGR.1370
        date: 2025
       words: 6670
      flesch: 47
     summary: At a temperature of 298 K, when the pressure increases from 0.6 MPa to 16 MPa, the density of hydrogen gas rises from 0.5 kg/m³ to 12 kg/m³. At 30 MPa, as the temperature increases from 313 K to 373 K, the density of H₂ only decreases from 20 kg/m³ to 16 kg/m³. The viscosity of hydrogen gas is minimally influenced by temperature and pressure, as depicted in Figure 3(b). Improved Oil and Gas Recovery 6 The diffusion coefficient of hydrogen gas is significantly affected by temperature and pressure, depending on the diffusion medium type, as shown in Figure 4.
    keywords: cushion; cycle; diffusion; energy; figure; gas; hydrogen; injection; pressure; production; recovery; reservoir; storage
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        item: #86 of 106
          id: iogr-1374
      author: Nguyen Hai Le, Nam; Duy, Le Nguyen Hoang; Phung, Pham Thi Van
       title: Evaluation of Orange Peel as an Eco-Friendly Additive: Influence of Concentration, Particle Size, and Temperature on Drilling Fluid Performance: DOI: 10.14800/IOGR.1374
        date: 2025
       words: 5160
      flesch: 53
     summary: This systematic approach ensured reliable comparisons of the effects of OPP particle size, concentration, and temperature on drilling fluid performance. Results and Discussions Effect of OPP particle size.
    keywords: drilling; figure; fluid; loss; mud; oil; opp; particle; size; temperature
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        item: #87 of 106
          id: iogr-422
      author: Kai Dong, Xiao Jin, Jie He
       title: Analysis of Fracture Design in a Vertical Well with a Horizontal Fracture: DOI: 10.14800/IOGR.422
        date: 2017
       words: 3356
      flesch: 53
     summary: In shallow and over-pressured formations there is a strong likelihood for horizontal fractures. Hence, horizontal fractures are common in shallow coalbed methane formations and may occur in highly over-pressured shale formations.
    keywords: case; dimensionless; figure; fracture; model
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        item: #88 of 106
          id: iogr-423
      author: Cai Wang, Gang Lei, Weirong Li
       title: Physical Models for Shale Gas Reservoir Considering Dissolved Gas in Kerogens: DOI: 10.14800/IOGR.423
        date: 2017
       words: 3035
      flesch: 51
     summary: Multiple mechanisms of Darcy flow, slippage flow, Knudsen flow, Henry law and Langmuir desorption contribute to gas flow in shale reservoirs and enhance the complexity of shale gas flow. Overall, four types of gas flow models are presented and related gas flow patterns and flow principles are explicated.
    keywords: flow; gas; matrix; model; shale; system
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        item: #89 of 106
          id: iogr-424
      author: Gang Lei, Cai Wang, Yuan Tian, Limin Yang
       title: An Analytical Equation to Predict Oil-Gas-Water Three-Phase Relative Permeability Curves in Fractures: DOI: 10.14800/IOGR.424
        date: 2017
       words: 5574
      flesch: 62
     summary: However, oil phase relative permeability is function of all-phase saturations. Gas saturation decreases oil phase relative permeability with a given oil saturation, while the viscosity ratio increases it.
    keywords: fracture; gas; oil; oil phase; permeability; phase; water; 𝑃1−𝑃2; 𝑃1−𝑃2 𝐿
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        item: #90 of 106
          id: iogr-425
      author: Uchenna Odi
       title: Incorporation of Homogenizer in Nanoemulsion Injection Scheme for Enhanced Oil Recovery: DOI: 10.14800/IOGR.425
        date: 2018
       words: 6960
      flesch: 50
     summary: Nanoemulsion injection is possible when the bottom hole injection pressure (PBHP) at the reservoir’s sand face is greater than the pressure in the reservoir. 3 Figure 1—Nanoemulsion injection system.
    keywords: diameter; dissipation; energy; figure; homogenizer; injection; nanoemulsion; oil; pressure; pump; scale; size
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        item: #91 of 106
          id: iogr-426
      author: Shanshan Liu
       title: Comparison of Fracturing Treatment Design with an in-house Code, MFrac and FracPro: DOI: 10.14800/IOGR.426
        date: 2018
       words: 3578
      flesch: 67
     summary: �� ℎ��� � − 2��� � − (��� + 2��) = 0,…...…………………………………………………….…………(4) ������� = ���� ,...………….…..…………….……………………………………………………….….(5) ������� = ������� − �����,..…….…………….…………………………………………..……..………(6) � = ����� ������� ,.…………………………………….………………………………………………....…….(7) ���� = ���� ,…………………………………………………………………………………………….(8) ��+ = 1 �� −� � ��(�) �+� �−� ��� ,….……..…………………………………………………………...…….(9)
    keywords: case; fluid; fracture; proppant; results; � �
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        item: #92 of 106
          id: iogr-427
      author: Shuai Liu, Han Li, Peter P. Valko
       title: A Markov-Chain-Based Method to Characterize Anomalous Diffusion Phenomenon in Unconventional Reservoir: DOI: 10.14800/IOGR.427
        date: 2018
       words: 8976
      flesch: 59
     summary: Although it may be called as one of the thoroughly investigated topics in this field, we would like to propose a new perspective for this equation when the porous media has a micro-structure in the form of complex fracture network. Mainly based on the mailto:shuailiu15@gmail.com 2 solutions to the single-phase diffusivity equations, Blasingame et al. (1986a, 1986b, 1988, 1989) rigorously derived the rate-decline relation and developed a method to extract the formation properties, such as permeability, drainage area, and hydraulic fracture length by analyzing the flowrate-time data.
    keywords: case; diffusion; diffusivity; figure; flow; fracture; matrix; model; msd; network; node; paper; reservoirs; time
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        item: #93 of 106
          id: iogr-428
      author: Zhenhua He, Benchun Duan
       title: Dynamic Study on the Fracture Interaction and the Predominant Frequency of the Induced Microseismic Signals During Hydraulic Fracturing: DOI: 10.14800/IOGR.428
        date: 2018
       words: 5496
      flesch: 60
     summary: Hydraulic Fracture Propagation across a Weak Discontinuity Controlled by Fluid Injection. Influence of Geologic Discontinuities on Hydraulic Fracture Propagation (includes associated papers 17011 and 17074).
    keywords: figure; fractures; fracturing; frequency; hydraulic; model; nfs; rupture; signals
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        item: #94 of 106
          id: iogr-429
      author: Hao Wang
       title: Sensitivity Calculation by Adjoint Method: An Application to Reservoir Simulation: DOI: 10.14800/IOGR.429
        date: 2018
       words: 4451
      flesch: 63
     summary: [𝛻𝑦𝑛(𝑓𝑛)𝑇]𝜆𝑛 = −[𝛻𝑦𝑛(𝑓𝑛+1)𝑇]𝜆𝑛+1 − 𝛻𝑦𝑛𝛽,…………..………………..……………….…………(1) where 𝜆𝑛 is the vector of adjoint variables at timestep n, and given by 𝜆𝑛 = [𝜆1 𝑛, 𝜆2 𝑛, … , 𝜆2𝑁 𝑛]𝑇,…………………..………………..……..….……………………………..(2) where 𝑁 is number of gridblock. 𝑑𝑦0 = 0.……….………….……………………………………………………………………………(3)
    keywords: adjoint; figure; matrix; permeability; reservoir; sensitivity
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        item: #95 of 106
          id: iogr-430
      author: Mohan, Vijitha; Neogi, Parthasakha
       title: Extraction Rate in Vapor Assisted Extraction of Heavy Oil (VAPEX) : DOI: 10.14800/IOGR.430
        date: 2019
       words: 2141
      flesch: 70
     summary: 𝐹𝑟 𝑅𝑒 = 4 × 10−6𝐴𝑟1/2𝑆𝑐1/4...………………………………………………………………………….…...(16) Results and Discussion Eq. 16 and the data (Nenninger and Dunn 2008) have been plotted in Figure 2 using the specific gravity of heavy oils to be 0.9. Her research interests lie in heavy oil recovery.
    keywords: data; dependence; gravity; oil
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        item: #96 of 106
          id: iogr-437
      author: Deng, Baorong; Zhang, Jiqun; Chang, Junhua; Li, Xinhao; Li, Hua; Li, Xianing
       title: A New Production Splitting Method Based on Discrimination of Injection-Production Relation: DOI: 10.14800/IOGR.437
        date: 2019
       words: 4113
      flesch: 46
     summary: Production wells and water injection wells distributed in different sand bodies are disconnected. 2) Water injection wells or production wells drilled in the mudstone area are disconnected. Production wells may connect in multiple directions.
    keywords: figure; injection; layer; oil; production; water; wells; � �
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        item: #97 of 106
          id: iogr-441
      author: Lv, Jianjiang; Yuan, Jianbo; Vo, Minh; Zhang, Juanliang
       title: Hydrate Management with Real Time Data Visualization : DOI: 10.14800/IOGR.441
        date: 2019
       words: 3292
      flesch: 50
     summary: Figure 11—Sour gas hydrate formation temperature at the second choke downstream at fixed pressure and various MEG injection rate. Figure 12—Sour gas hydrate formation temperature at pipeline inlet at a given pressure & various MEG rates.
    keywords: figure; formation; gas; hydrate; meg; pressure; temperature; water
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        item: #98 of 106
          id: iogr-444
      author: Jiang, Yun; Shi, Yang; Zhao, Liang; Yang, Xianyou; Li, Yue; Yu, Yue; Gao, Ying; Wang, Meng
       title: Water Block Damage and Its Solutions for Tight Gas Reservoirs in Dabei-Keshen Area : DOI: 10.14800/IOGR.444
        date: 2019
       words: 3781
      flesch: 51
     summary: Conclusions 1) Water block index, WBI, is applied to evaluate the damage degree of water block, and WBI of selective core samples from the targeted zone is 70%, belonging to the type of strong water block. 2) To investigate the mechanism of water block and put forward corresponding measures, water block index (WBI) is developed to estimate the damage degree of water block and thermo-stable surfactant systems are optimized to clean up water block through interfacial tension tests, wettability tests and spontaneous imbibition.
    keywords: block; damage; degree; gas; permeability; reservoir; water; wbi; � �
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        item: #99 of 106
          id: iogr-445
      author: Zhixin Ma, Ji Zhang, Wen Xue, Wensheng Wang, Bin Fu, Weifeng Sun, Qianqian Fan, Ya Li
       title: Technology and Application on Reservoir Architecture Characterization Based on Sandbodies Spatial Orientation : DOI: 10.14800/IOGR.445
        date: 2019
       words: 4732
      flesch: 54
     summary: Ma et al. 2008; Zhou et al. 2008; Bai et al. 2009; Liu et al. 2011; Li et al. 2011; Zhang et al. 2013). The two main plane combinations in the single channel sandbody of Shihezi group 8th section in research are: banded channel which width is 1000~2000m and sheet scale channel which width is 1500~4000m. 2) The main reservoir configuration units include the channel bar, braided river channel and flood plain.
    keywords: bar; channel; configuration; et al; figure; gas; reservoir; river; sandbodies; sandbody; shihezi
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        item: #100 of 106
          id: iogr-447
      author: Xu, Qingyan; Guan, Rongliang; Wu, Cong
       title: Comparison of Development Effects for Two Different Combined Well Patterns with Horizontal Wells and Vertical Wells : DOI: 10.14800/IOGR.447
        date: 2019
       words: 1464
      flesch: 45
     summary: Normally horizontal wells are deployed combined with vertical wells, in which way effective injection- production well network system could be established. However, horizontal wells could be water injectors as well as oil producers and the same is true for vertical wells.
    keywords: development; pattern; pressure; wells
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        item: #101 of 106
          id: iogr-453
      author: Wang, Zhen; Wang, Xiang; Duan, Weigang ; Li , Fajun; Chen, Fei 
       title: Well Production Real-Time Intelligent Monitoring Based on Convolutional Neural Network: DOI: 10.14800/IOGR.453
        date: 2019
       words: 4273
      flesch: 56
     summary: The output of each layer is a series of feature maps. The output of feature maps obtained in the last feature extraction stage is used as input to the classifier.
    keywords: cnn; convolution; diagram; feature; indicator; layer; model; network; training
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        item: #102 of 106
          id: iogr-454
      author: He, Lei; He, Yilin; You, Liangrong; Li, Feng ; Zhang, Fang
       title: A New Method for Estimating the Peak Gas Rate : DOI: 10.14800/IOGR.454
        date: 2019
       words: 1800
      flesch: 63
     summary: Base on the theoretical research and numerical simulation analysis, correlations of pressure drop rate as a function of increment of gas rate and reservoir pressure were established for three types of wells, respectively (Figures 4 through 6). Figure 4—Correlation of pressure drop rate and increment of gas rate of type I well.
    keywords: gas; mpa; pressure; rate
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        item: #103 of 106
          id: iogr-455
      author: Zhang, Rixing; Nasr-El-Din, Hisham ; Jin, Xiaochun; Wu, Jun Jim; Pérez, Lisa M. 
       title: Multiscale Investigation of a Less-Damaging Friction Reducer to Mitigate Formation Damage in Unconventional Shale Reservoirs: DOI: 10.14800/IOGR.455
        date: 2019
       words: 6693
      flesch: 57
     summary: 20ps Simuation 200ps Simuation 11 Table 4—Transmittance results of HPAM FR solution with different salts. To accelerate simulations, one molecule of PAM polymer with 20 repeating units was used instead of hundreds of thousands of repeating units PAM in each cell.
    keywords: concentration; damage; figure; formation; fracturing; frs; gas; hpam; ions; metal; polymer; production; salt; slickwater; solution
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        item: #104 of 106
          id: iogr-456
      author: Yu, Yue; Vo, Minh; Xiao, Chaohong
       title: Reservoir Surveillance and Production Optimization Workflow from Real Time Data Advantage at A Joint Venture Gas Project : DOI: 10.14800/IOGR.456
        date: 2019
       words: 3202
      flesch: 46
     summary: Starting with the well where both surface and downhole pressure data are available, the Petroleum Engineering model has been built and it helps calculating the gas compressibility z factor under specific production condition (i.e., from gas composition, including H2S and CO2, and non-linear temperature profile along the wellbore). Appropriate correlations are loaded to convert the surface pressure data to downhole pressure data, and the results are compared with the actual PDHG data measured directly from the downhole gauge.
    keywords: data; development; field; figure; gas; pressure; production; reservoir; surveillance
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        item: #105 of 106
          id: iogr-457
      author: Sun, Yanyan; Fan, Jiwu; Xu, Zhenping; Li, Zhichao
       title: Application of Numerical Well Testing Technology in Strong Anisotropic Sandstone Gas Field: DOI: 10.14800/IOGR.457
        date: 2019
       words: 2084
      flesch: 45
     summary: This study compared the difference between numerical well testing and analytical well testing, and summarized the key points of numerical well testing analysis technology, formed technical ideas of numerical well testing, proposed an interpretation workflow on the typical numerical well testing, and estimated the distribution of the main parameters, such as effective permeability reservoir, fracture half- length, and fracture conductivity, and so on. The Difference between Numerical Well Testing and Analytical Well Testing The difference between numerical well testing and analytical well testing is that fluid seepage equation in the porous media are solved by different methods.
    keywords: figure; gas; numerical; reservoir; testing
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        item: #106 of 106
          id: iogr-458
      author: Vo, Minh; Yu, Yue; Lv, Jianjiang; Zhang, Junliang
       title: Surface Pressure Data for Well-Test Analysis at a Joint Venture Gas Project in Sichuan : DOI: 10.14800/IOGR.458
        date: 2020
       words: 3508
      flesch: 59
     summary: From the subject matter experts of pressure transient tests, this is one of the most significant challenges to surface test, a so-called the wellbore cooling effect.  Leveraged the conversion technology from surface pressure data to bottom-hole pressure data and elementary analysis with Halliburton in-house developed mode, which helped to ensure high- quality work.
    keywords: data; figure; gas; pressure; reservoir; test; wellbore; wellhead; wells
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