bluuebunny/crossref_metadata_2025_split huggingface dataset:
Full Azimuth Multi-Rays Pre-Stack Depth Migration in the B Block
Authors: Liu Jiangtao , Yu Ming , Yu Yan , Qi Qunli , Ji Yu , Zhao Min , Chen Yingpeng , Chen Shuangting , Yang Chen , Sun Junxiao , Zhao Mingqiu , Hu Xin , Gao Junqi 
Published: October 2022

Abstract
Usually, the signal-to-noise ratio is low and velocity spatial change is severe in areas where fault traps develop. Seismic data processing brings challenges to geophysicists. It is extremely difficult to improve imaging in deep parts were faults harm wave propagation. Traditional pre-stack data migration imaging methods based on common middle points or common shot points are generated by the geophysical theory hypothesis. To overcome such kind of challenge and improve imaging, full azimuth multi-rays pre-stack depth migration was applied in the B block.
Full azimuth multi-rays pre-stack depth migration brings a new concept. Rays scan is generated from imaging point toward the surface, leading to a simultaneous emphasis on both continuous structure and discontinuous objects such as small faults and small-scale fractures. In this paper, a comparison was conducted between conventional Kirchhoff pre-stack depth migration and full azimuth multi-rays pre-stack depth migration. Sufficient tests have been carried out in the fault-developed areas. For geological attributes analysis, subsequent processing can be conducted on multi-domain gathers from full azimuth multi-rays pre-stack depth migration according to the request of geologists.
Application of this method in B block in the Middle East shows that full azimuth multi-rays pre-stack depth migration can improve the imaging quality of medium and deep layers and improve the imaging of small faults and small-scale fractures. Full azimuth multi-rays pre-stack depth migration can use isotropic and anisotropic velocity models to perform reflection and directional imaging in the local angle domain. Migration radius is defined by both aperture and angle. Information from all azimuths and angles is fully involved in the imaging process, which is beneficial to imaging small faults and fractures. Structural attributes such as dip, azimuth and continuity of the target zone can be obtained directly from gathers after migration. High-quality structural imaging results can be obtained by effective reflection enhancement processing on gathers from full azimuth multi-rays pre-stack depth migration. Diffraction wave enhancement processing can be used for geological fracture prediction.
This paper studies the principle of full azimuth multi-rays pre-stack depth migration, compares it with the conventional Kirchhoff prestack depth migration, analyses the advantages of this method in imaging principle and subsequent gathers processing, and applies it to seismic data of the Middle East B Block heterogeneous carbonate reservoir. The result shows that imaging accuracy of full azimuth multi-rays pre-stack depth migration technology is higher, especially in complex structural areas.
Seismic Motion Inversion Based on Geological Conditioning and Its Application in Thin Reservoir Prediction, Middle East
Authors: Xin Chen , Min Zhao , Jingbin Cui , Qunli Qi , Haisheng Yu , Xiaoliang Li , Dengyi Xiao , Shuangting Chen , Mingqiu Zhao , Bo Wang , Junqi Gao , Qiang Li , Bo Peng , Fuli An , Xiaoli Gao 
Published: October 2022

Abstract
With the development of exploration and development, thin reservoir prediction is becoming more and more important. However, due to the limit of seismic resolution, thin reservoir prediction has always been an important challenge in the Middle East. Thin reservoir prediction based on conventional geophysical techniques is not accurate enough to meet the requirements of development. In order to improve the accuracy of thin reservoir prediction, a new thin reservoir prediction technique is proposed.
This technical workflow main includes 4 steps: (1) Sedimentary facies identification based on multidisciplinary analysis, (2) Sedimentary facies model and seismic forward modelling, (3) Seismic response characteristics analysis and seismic data conditioning under the guide of forward modelling, (4) Seismic meme inversion and thin reservoir prediction.
The new drilled wells demonstrate the successful application of the techniques in the M field in the Middle East. The 5 layers of thin sandstones reservoir can be divided into two sets of high stand systems of sand and low stand systems of incised valley deposits. Geological model seismic forward modelling shows that the most sensitive seismic dominant frequency for effectively identifying the two groups of sandstone is 35Hz (Fig.1). Through the high resolution seismic processing, the main frequency of seismic data was optimized from 25Hz to 35Hz, which improves the recognition ability for the thin sand groups (Fig.2). Seismic facies analysis based on previous and new seismic data shows that different thin reservoir layer can be effectively identified by seismic facies. Under the constraints of seismic facies, the Seismic meme inversion can effectively predict the two sand groups (Fig.3). 51 km2 of thin reservoir favourable area was discovered and 16 wells were drilled with 91% success rate based on the new seismic inversion result in the southeast part of the oilfield.
This technology can effectively integrate geological information and seismic conditioning techniques, and improve the accuracy of thin reservoir prediction results more reasonably, which can not only provide support for the exploration for thin reservoir but also efficient development. This technique is applicable not only to thin clastic reservoir but also to thin carbonate reservoir.
The ExxonMobil Brazil Technology Collaborative: A Team of Teams Cross-Silo Leadership Experiment
Authors: Jones Gareth David , Fullmer Shawn 
Published: October 2022

Abstract
The value of breaking down silos to enable people to collaborate across organizational boundaries and disciplines is widely recognized. This horizontal collaboration stimulates innovation that can result in the development of new integrated solutions and business opportunities. Unfortunately cross-silo leadership is notoriously difficult to achieve. Effective collaboration across interfaces between Technology Development and Operating Units in many industries, including the energy industry, is a particularly stubborn challenge.
The purpose of this paper is to share an approach and results of adopting a diverse and inclusive Team of Teams model designed to develop and deploy technology for the exploration and development of assets in the prolific Brazil Pre-Salt play. Key design criteria for this Collaborative included: 1) Setting clear and aligned business priorities, 2) Appointing "Collaborative Connectors" multidisciplinary subject matter experts with leadership skills consummate to the challenge, 3) Identifying business unit "Technology Champions" as vested customers to help bridge across silos, 4) A multifaceted communication strategy built on transparency that fostered ideation and frequent updates on the Brazil business landscape to continuously test technology relevance and identify refinement / early deployment opportunities, 5) A conscious break with historical technology time frames and process paradigms to accelerate business application and value realization.
The Brazil Technology Collaborative experiment is deemed a success by several measures including: A leading count of business unit nominated "Technology Value Realized" KPI candidates, for example 1) the adaptation and integration of ExxonMobil reservoir characterization "Total Pore Systems" technology to reduce uncertainty on dynamic performance forecasts in complex lacustrine carbonates, 2) Improved sub salt seismic imaging and predictions of reservoir presence and quality from seismic inversion, 3) Geologic Process Modeling to help identify and constrain credible subsurface scenarios for uncertainty analysis, 4) Multiple comprehensive Pre Salt Field studies focusing on integrated dynamic characterization and reservoir performance (using publicly available Pre Salt data) and 5) Rapid assimilation of play wide data and interpretations in a practical tool to drive consistent subsurface evaluations across multiple teams and disciplines.
Beyond this Pre-Salt example, cross silo leadership in technology will be a critical capability and competitive advantage in the energy transition which demands organizations innovate and grow collaboration across internal functional boundaries and with multiple external partners.
Well Exposed Geological Outcrops Enhancing Reservoir Static Modeling
Authors: Prasad Prashveen , Balhasan Saad , Harrison Gbubemi , Khameiss Belkasim 
Published: October 2022

Abstract
Reservoir characterization is a critical factor in reservoir management, optimizing production, and enhancing recovery. Lack of understanding of reservoir characteristics is one of the leading causes of mistakes in constructing the static reservoir model. Understanding the three-dimensional variability of any reservoir static model requires an understanding of its depositional environment. This paper is about improving the geostatistical resolution of two or three-dimensional digital recordings by using outcrop analogs to help with small and large-scale reservoir modeling challenges. The investigation was conducted on one carbonate outcrop in Ras Al Khaimah, UAE, namely the Wadi Ghalilah formations. Initially, easily spottable characteristics of the reservoir formation were noted. Following that, the outcrop was categorized into various units. Each observed zone has provided details about the formation characteristics, the fracture and matrix network, and the lithology. Easily noticeable color changes were observed. Additionally, fossil impressions and iron-stained formations were observed at the outcrop. The layers and their thickness, matrix network, fracture network, their intensity, and orientation were observed at small-scale and large-scale. The formation characteristics hinted at the porosity and permeability of the outcrop. The observed formation characteristics and geometry properties were inputted into the static model, and subsequently, data was entered into the dynamic model to minimize the uncertainties in both the reservoir models. The areal sweep efficiency is expected to be fine during waterflooding in a small, patterned reservoir whereas water injection doesn’t appear to be a suitable option at Wasia and Thamama outcrops due to the presence of seal layers and vertical heterogeneities.
Unlocking UAE's Largest 3D Onshore Seismic Survey – Processing Challenges in Eastern Abu Dhabi
Authors: Trezzi Stefano , Seliem Abdulla , Mahgoub Mohamed , Cambois Guillaume , Glushchenko Anna , Vasilyev Pavel , Saad Al Kobaisi Abdulla 
Published: October 2022

Abstract
A 14,000 sq. km surface seismic survey was acquired onshore Abu Dhabi in recent years. With around 170 billion traces, it is the largest land survey shot in the UAE and one of the largest processed globally to date. We present here the methodology in processing this dataset to derive a high-resolution volume that surpasses benchmarks from previous exploration campaigns.
A detailed near surface model and related statics have been derived using Data-driven Image-Based Statics (DIBS) workflow. Over twenty depth tomography iterations were required to reach structural continuity and guarantee well matching, with strong interaction between interpreters and processing team to define a geologically consistent model.
Pre-imaging technologies such as surface wave modeling, 5D regularization to radial symmetry, Multiples prediction algorithms, as well as numerous iterations of multi-domain noise attenuation have been key to provide the desired level of Signal-to-Noise ratio and achieve high vertical resolution.
The project is also part of a broader work that aims to cover the Abu Dhabi Emirate with high-density surface seismic. Hence, the survey was designed and processed to deliver seamless merge and continuity with neighbor sectors, for a total of 40,000 square kilometers of data.
These efforts in seismic acquisition and processing have produced an accurate high-resolution volume that adds unprecedented levels of detail and a new geological understanding of key plays in the south-east regions of Abu Dhabi. This result has been achieved over established producing fields, as well as in new, unexplored areas. The outcome has been already proven accurate in the latest exploration campaigns and is currently being used as a benchmark to define possible new key targets.
Enabling Synthetic PLT Through Integration of Brittleness Indicator and Porosity-Independent Permeability to Improve Understanding of Expected Flow Profile in an Unconventional Reservoir: Case Study from Kuwait
Authors: Abdulkarim Anar , Abd El-Aziz Sabry 
Published: October 2022

Abstract
Mauddud carbonates in the Bahrah Field of Kuwait, with their low permeability, are often considered as unconventional reservoirs, which require multi-stage hydraulic fracturing stimulation. Optimal stage distribution is one of the key elements in this type of completion design. This paper presents the forecasting methodology for estimating the production performance of each stage which can later help to optimize stage placement in long horizontal sections.
High-resolution micro-resistivity imaging and an azimuthal sonic tool, in combination with conventional triple-combo logs and formation pressure testing, were run in a 6.125-in. section to help develop an effective and sustainable production plan, based on the petrophysical and geomechanical properties of the heterogeneous tight carbonate reservoir. The use of image data helped to evaluate the permeability distribution close to the borehole wall more accurately than conventional porosity-based permeability relationships, which showed marginal correlation with actual permeability. Sonic and density logs helped to estimate rock mechanical properties. Mobilities derived from the formation pressure build-up curve were used to normalize permeability indicators.
The porosity-independent image permeability indicator, which was developed specifically for carbonate formations and is based on the electrical conductivity distribution around the circumference of the borehole, showed fair correlation with the brittleness indicator. The brittleness indicator, on the other hand, exhibited a high degree of correlation in all completion stages with the production logging (PLT) data. The good correlation of production information with the brittleness indicator, derived from Poisson's ratio and Young's modulus, is in line with the main inputs for hydraulic fracture design, which use these mechanical properties. Both brittleness and image permeability indicators were used to improve well placement in the sweet part of the reservoir and played an important role in the success of this complex process. This process also enables the potential for synthetic PLT derivation, which can help to improve understanding of the expected flow profiles from different frac stages.
The case study presented in this paper demonstrates the promising benefits of integration of open-hole logs to derive synthetic PLT data that can improve completion design and enhance production forecasting in an unconventional reservoir. The availability of several years of production and formation pressure dynamics data also helped to extend the application of the methodology to forecast future production stability for the field.
Sequence Stratigraphy and Paleobathymetry of the Lower-Middle Miocene Succession, Gulf of Suez, Egypt
Authors: Kelany Abdel Rahman M. , Farouk Sherif F. , Kassem Ahmed A. , Abuel Majd Mohamed E. 
Published: October 2022

Abstract
In the Gulf of Suez rift basin, the Miocene sequence is a significant hydrocarbon resource. An integration of the planktonic foraminifera, and benthic foraminiferal biofacies are data used to build a detailed and fine chronostratigraphic scheme for the lower part to middle part Miocene succession in the October Field, Gulf of Suez. The paleoecologic habits and paleobathymetry of benthic foraminiferal biofacies, as well as the planktic/benthic (P/B) ratios of the studied successions, are used to determine the paleoenvironmental conditions that are in effect during the deposition of the studied Miocene successions. Elphidium biofacies are representative of the inner shelf paleoenvironment, Nonion biofacies and Siphonina/Cibicides biofacies are representative of the middle shelf paleoenvironment, Bulimina and Uvigerina biofacies are representative of the paleoenvironment outer shelf. The paleoenvironmental interpretations and chronostratigraphic for data and the nature of stratigraphic relations are integrated to distinguish five depositional sequences in the studied section. These are two in the Aquitanian/Burdigalian, one in the Burdigalian-Langhian, one in the Langhian, and one sequence in the Serravallian ages. The sequence boundaries were marked by subaerial exposures and hiatuses. A detailed correlation between the distinguished sequence stratigraphic lower-middle Miocene frame and those established in and outside Egypt is attempted. The absolute time equivalents of the planktic foraminiferal zones are adjusted by comparison with the geologic time scale of Gradstein et al. 2022. This comparison points out a more or less compatible correlation, with a few deviations that may be related to tectonic events that led to the absence of some recorded depositional sequences.
State-Of-The-Art of Carbonate Pore Type and Permeability Modelling: An Approach of Petro-Acoustic Modelling by Using Lucia Rock Fabric Number (RFN) in Central Luconia, Offshore Sarawak
Authors: Ling Kuok Hsu , Zulkiply Hapiz 
Published: October 2022

Abstract
Central Luconia province is located in South China Sea, Sarawak with development of more than 250 carbonate pinnacles and platform in Middle Miocene to Late Miocene. The study proposes a methodology that has been successfully applied and calibrated to 20 exploration or appraisal wells in both carbonate pinnacles and platform with the objective to model pore types from compressional velocity and subsequently used it for permeability prediction based on Lucia's rock fabric number (RFN). Porosity, permeability, petrography and mercury injection pressure (MICP) data of more than 2000 core plugs and sidewall core samples were analyzed to establish functions in between compressional velocity, pore types and permeability.
This paper is established based on two concepts by many authors in the past, but no publication to date has linked these two concepts together. The first concept is the poroelastic behavior of carbonate rock under constant pressure and 100% water saturation is controlled primarily by a combination of porosity and pore geometry (Wyllie et. al., 1958; Anselmetti & Eberli, 1993; Anselmetti et. al. 1997; Eberli et. al., 2003). High aspect ratio pores sample such as molds and vugs, typically has higher pore throat size. The sonic velocity of this sample will plot above Wyllie-time-average (WTA) equation. Low aspect ratio pores such as interparticle and intercrystalline pores, typically has lower pore throat size. The sonic velocity of this sample will plot below WTA equation. The second concept is the Lucia rock fabric number (RFN) which described porosity – permeability relationships for various particle- size groups in non-vuggy or interparticle porosity rocks only. However, our MICP dataset conclude that Lucia RFN number is inversely proportional to dominant pore throat size in carbonate rock with little to no presence of primary porosity. The dominant pore throat size was determined based on the apex of curve in the crossplot of mercury saturation divided by injection pressure to mercury saturation.
Carbonate Sedimentary Facies Characteristics and Model of the Lower Cretaceous Thamama Group in the United Arab Emirates
Authors: Deng Anxiong , Grover Anurag , Gao Xiaoli , Al Mesmari Abrar , Wang Ailing , Ahmed Jahan Zeb , Lv Lu , Al Shamsi Saif Ghanim , Zhao Wenhao 
Published: October 2022

Abstract
The purpose this study is to use geophysical technology, analyze the characteristics of typical sedimentary facies in the study area, extract sensitive seismic attributes, compile sedimentary facies distributions, establish a sedimentary model, and improve the understanding of the distribution law of complex carbonate reservoir in oil and gas exploration and development. The Cretaceous Arabian Basin is a typical gentle slope carbonate basin with rich oil and gas resources. The main reservoirs in the study area have complex lithology, including bioclastic grainstone, bioclastic packstone and rudstone. However, the heterogeneity of carbonate rocks is strong and the sedimentary facies change rapidly, which increases the difficulty of understanding the distribution law of reservoirs.
Based on core data, well logs, seismic data and well-to-seismic integration, the sedimetary facies study of the Cretaceous Thamama Group has been completed. Typical lithology and logging facies were identified. The logging facies were established, multi-well facies were carried out; and sedimentary characteristics were analyzed. Multi-attributes have been analyzed including amplitude, frequency, continuity and phase attributes to extract sedimentary facies maps by combining lithofacies and logging facies. Based on the above analysis results, a sedimentary model has been summarized.
According to this study, the target strata are mainly carbonate deposits of gentle slope with shoal, inner shoal and grain flat facies deposits. Four typical logging facies were identified consisting of low energy shoal, margin shoal, grain shoal and grain flat microfacies. The favorable reservoirs are mainly bioclastic grainstone and packstone formed in a medium-strong hydrodynamic environment. The sedimentary model of the study area is established to analyze the distribution of target reservoirs and guide the analysis of favorable reservoirs in the area. The Thamama Formation has stable thickness in general, the depositional environments changed from subtidal to inner shoal of restricted platform, to grain shoal and grain flat. It is concluded that the Shuaiba Formation and the Kharaib Formation of the Lower Cretaceous Thamama Group in the middle of the study area are the most favorable reservoir development formations, and the central and northern areas are the most favorable oil and gas accumulation areas.
Through this study, a more complete and instructive carbonate slope sedimentary model has been established. In addition, through the multi-attribute analysis technology and optimization method, we have completed and deepened the understanding of the distribution of the target layer sedimentary facies, and provided a new geophysical comprehensive research method. However, due to the complexity of carbonate rocks, further research is needed.