bluuebunny/crossref_metadata_2025 huggingface dataset:
Optimizing a Complex, Uneven and Low-Resolution Reservoir While Using Dynamic Dataset for Structure Definition
Authors: Ahmed Sheraz , Waqas Ghulam Muhammad , Sheikh Hafiz Mustafa Ud Din , Abrar Saad Bin , Siddiqui Majid
Published: March 2023

It is well established that the oil & gas industry has long surpassed its plateau for large discoveries. Thus, many companies have shifted their focus to cost-constrained policies for hydrocarbon discovery, making it difficult to have a strong sub-surface definition. Add the structural uncertainties and complexities of new discoveries in this scenario, the optimized field development becomes a real challenge. This study presents the development strategy established for a reservoir, with low seismic resolution, using the integrated dynamic data to define the reservoir structure and optimize its recovery.

This paper focuses on a relatively new discovered formation in one of the oldest gas giants in Pakistan. The productive sandstone units are in beds with thicknesses ranging from 10-50m, separated by mudstone intervals. The low seismic resolution has posed a major challenge in finding the sweet spots for hydrocarbons above Gas-Water-Contact (GWC)-resulting in 60% well failures. Therefore, a workflow was developed to analyze various dynamic datasets in conjunction with the re-interpretation of seismic to delineate the reservoir structure. This included re-interpretation of MDT data and formation gradients, core re-evaluation, critical analysis of reservoir pressure variation, well failure analysis, thickness maps and PVT properties.

The first four wells drilled in this reservoir had two successes, both in the Western compartment. However, sudden water production loaded up these wells only after 123 BCF production, which was a lower recovery as compared to GIIP estimates. After further geological evaluation and 3D seismic re-acquisition, more wells were drilled – revealing another deposition with a different GWC, but only 1 well was successfully completed as a producer, adding around 38% more reserve, while the others were again unsuccessful due to high structural uncertainty. This led to the development of a detailed algorithm for integrating dynamic data set with seismic re-interpretation and thickness mapping with the help of which two more wells were drilled and added around 22 % more reserves to the current mix. The dynamic data of these wells have now been further evaluated which revealed that the two compartments are in fact in communication with each other despite having a 60m difference in their GWCs. Finally, two more wells are now planned which will add around 10-20 % more recoverable volumes, giving an overall EUR of ~80% from these compartments.

The main achievement of this workflow is a robust algorithm to integrate the dynamic data with geological interpretation to delineate a low-resolution reservoir since the seismic interpretation cannot be solely relied upon for developing such reservoirs. The paper also illustrates the robust engineering models and data analyses in a more systematic manner to ensure optimum locations for future wells to access, the otherwise, undrained locations.
Multi-Well Distributed Fiber Optic 3D VSP Acquisition Technology for Offshore Exploration in the Middle East
Authors: Li Qingfeng , Zhao Jilong , Fan Yangshuan , Huang Dong , Yu Gang
Published: March 2023

With the development of distributed fiber optic acoustic sensing technology in the field of borehole seismic surveys, more and more oil fields choose to pre-install fiber optics in the well in advance for borehole seismic data acquisition or fluid detection. In 2022, ADNOC completed the world’s first multi-well DAS VSP and OBN joint acquisition survey in the Persian Gulf, with the fiber placed outside the tubing, relying on the offshore high-density OBN acquisition survey, completing a total of 13 wells for DAS VSP acquisition. The DAS VSP raw data spacing interval is 1 m, the sampling interval is 1 ms, and the offshore air guns are staggered at a density of 25 m × 25 m. This study will focus on the determination of multi-well DAS VSP data acquisition area, data analysis for different Gauge Length, and raw data quality control.
An Innovative System to Contain Well Integrity Problems and Maximum Operational Excellence
Authors: Alqahtani Abdullah Mubarak , BenAmara Abdel
Published: March 2023

Well integrity is one of the most critical elements for prolonging life of producing wells. A good integrity program will ensure safe, cost effective operation, whilst avoiding any environmental related issues. To improve well integrity monitoring and control and promote operational excellence by having real-time monitoring of tubing-casing annulus, and have the ability to relieve pressure at any time without the need to visit the well site. An innovative system was designed to be an integral part of the well completion, preferably below tubing hanger below sub surface safety valve, to relieve pressure from tubing-casing annulus to the tubing. The system allows real-time monitoring of both annulus and tubing and enables relieving high annuli pressure to the tubing remotely or by having a set point activation.

The system is tailored to make advantage of the digital oilfields platform to provide robust data real-time monitoring of annuli anomalies and help contain the problem. The innovative system enables unmanned operations and continuous monitoring and control of annuli anomalies. It helps contain well integrity problems till the workover rig is available to salvage the problem. This safe routine and convenient eliminates the needs for wellsite visits that are at high cost and sometimes not possible, especially in offshore operations. In addition, it alleviates the need to vent gases to atmosphere and avoid environmental and human safety issues. The system can also help validate data by monitoring fluid gradients in tubing and annulus, which help get better diagnosis for well integrity anomalies.

This unmatched system is the only tool that is designed to have an integrated system that will monitor pressures and gradients in tubing and annulus, which provide an advanced diagnostics of annuli problems. In addition, it can help contain the annuli problem by continuously reliving the pressure into tubing, as needed, without human intervention.
Onshore Abu Dhabi Carbonate Saline Aquifer CO2 Storage Site Selection - An Integrated Technical Feasibility Study
Authors: Xu Siqing , Baslaib Mohamed , BinAmro Ahmed , Keebali Aaesha
Published: March 2023

Carbon Capture and Storage (CCS) technologies help reduce carbon dioxide emissions from large point sources, such as power plants, gas processing facilities and other industrial facilities. It involves capturing CO2 emissions, transporting the captured CO2 to storage location, and securely storing underground for a long time. The term permanent storage is very often used. CCS technologies involving storage in underground geological formations are well established, and there are current a number of such ongoing projects, together with an increasing number of projects in the planning phase.

Saline aquifers can be leading CO2 permanent storage candidates. Deep saline formations or deep brine reservoirs exist world wide, making them potentially accessible CO2 storage candidates. However, not all saline formations can be considered suitable for long term commercially viable storage candidates. A number of critically important factors must be taken into account/verified, for example, CO2 containment assurance, social and environmental impact, and project commercial aspects. A project feasibility is normally recommended as a first step, whereby potential saline aquifer candidates are screened, ranked against for example accepted best international guidelines and criteria. Detailed feasibility study can follow once top ranked suitable candidate(s) are identified.

A comprehensive multi-discipline study was carried out looking at the potential for CO2 sequestration in deep saline aquifer formations within onshore Abu Dhabi. The area of interest is very large in scale (regional scale) and consists of multi stacked saline aquifer formations. The study has the added complexity that the same saline aquifer formations may be shared with near-by hydrocarbon exploration and production activities. The objectives were to analyze available geological data, oil field production and injection data, identify key constraining factors especially concerning CO2 containment assurance, arrive at regional storage capacity range estimates, and demonstrate site CO2 storage feasibility.

Considerable amount of geological data and studies are available, which can assist with regional Onshore Abu Dhabi saline aquifer formation geological characterization for CO2 storage assessment. The characterization synthesis forms the study basis. Dedicated regional scale 3D saline aquifer formations compositional dynamic models were constructed, capturing the key CO2 sequestration processes/mechanisms. Storage capacity estimates were obtained from the dynamic model – the results will be published separately. A comprehensive Risk Assessment was carried out. Risk assessment approach and MMV plan development are shared.
Field Evaluation and Assessment of Wellbore, Casing and Cement Integrity During Critical High-Pressure Operations in Existing and Abandoned Wells
Authors: James Abraham Jocin , Amani Mahmood
Published: March 2023

With the declining access to ‘easy oil’ and an increase in energy demand, oil and gas producers are increasingly focusing on producing from more challenging unconventional reserves. This can especially be seen from the widespread proliferation of fracturing operations, during which a production well is purposely hydraulically fractured by injecting fracturing fluids at elevated pressures. However, in many operations, especially in deep reservoirs, casing deformations or cement layer integrity failures are observed. Therefore, it is necessary to thoroughly understand wellbore integrity issues for ensuring safe fracturing operation.

A decay in the mechanical properties of steel and cement is expected after exposure to different operations, pressures, temperatures and fluids over time, which can significantly degrade the thickness and burst pressures ratings of the casing string. In this study, the degree of casing wear developed due to routine operations as well as corrosion and erosion in existing conventional wells is calculated using drilling and completion program datasets. Casing wear depends on several factors such as rate of penetration, rotary speed, wellbore orientation, as well as wellbore wear constants. These parameters are used in various models to calculate the wear volume, which is then correlated to an average percentage reduction in thickness of the casing string. This is then used as an input parameter for a finite-element analysis of casing-cement interaction under different scenarios, especially focusing on stresses in the connections.

Analyses show that long term wellbore integrity does indeed depend on the quality of the casing program, cementing job as well as the minimization of human errors. The design of fracture treatments should therefore consider weak points around the casing and the cementing layer, especially those arising due to casing wear. Based on calculations, casing wear losses of over 40% of the initial volume can occur during the operational life cycle of a well, leading to a considerable decrease in thickness and burst ratings of the casing string. Finite element simulations show that varying stress concentrations in the steel and cement components can lead to fatigue and failure through tension and compression. Depending on the extent of casing wear, stresses above the unconfined compressive strength of common cement formulations are observed. If not accounted for, these lapses can lead to cement integrity issues and a critical well integrity failure.

The results of this work can be used as a simpler field evaluation to determine actual casing and cement properties over the operational lifespan of a well and provide a methodology to assess the effects of wear on the casing, connections and the cement layer. This should be correlated to the integrity of the wellbore under different conditions before starting fracturing operations.
3D OBN High Resolution Seismic Acquisition Design for Better Sub-Surface Imaging, Cheleken, Caspian Sea
Authors: Rondon Aldrin , Rouis Lamia , Khdhaouria Mourad , Ameish Giamal , Xiaoliang Li
Published: March 2023

The Cheleken contract Area lies in the Turkmenistan sector of the South Caspian Sea, over an area of 920 Km2 and in water depth of 10 to 40 m. Located in a complex wrench faulted system orientated WNW-ESE from the Apsheron Peninsula in Azerbaijan to the Cheleken Peninsula in Turkmenistan, the cheleken fields have a large thickness of stack sand and shale reservoirs, with significant areal and vertical variation.

The presence of strike slip faults, gas Chimney, H2S in some reservoir fluid, and low sweep efficiency due to the aforementioned geological complexities are challenges that need to be addressed.

In 2004, the first seismic acquisition campaign was carried out by Dragon Oil in order to get a full dataset of seismic data covering the whole field, the acquisition technology considered for this dataset was Ocean Bottom Cable (OBC) and it was designed to cover the entire stratigraphic column down to deeper sections (approximately 7000 meters), therefore, deep objectives were not properly imaged due to technical limitations at that time. Seismic resolution was compromised and this OBC technology couldn't account for surface obstructions among other technical and logistic limitations.

In 2015, Dragon Oil started with the idea to acquire a new seismic dataset with improved technology to aid in the better definition of sub-surface targets and define a more detailed and reliable structural framework as input for the Static and Dynamic Modeling Process.

The ultimate goal of acquiring a new seismic dataset considering OBN Technology, was to define an optimal drilling strategy based on a more robust and reliable static and dynamic modeling of the field.

Ocean Bottom Node Seismic has emerged as an effective technology for seismic exploration/development in numerous challenging acquisition environments with the key added value of higher data quality and much better seismic imaging.

By placing receivers on the seafloor and decoupling the source from these receivers, the recorded data offers high quality imaging through improved multiple suppression and better subsurface illumination, without limitations existing with conventional streamer operations.

Full Azimuth, long offset illumination, high fold are characteristics of Ocean Bottom Node (OBN) acquisition technology and it's proven successfully in extremely complex structural/stratigraphic environments and highly obstructed areas. This technology unfolds a wide range of geophysical options to generate a detailed geomodel of the field and also unlocks additional technical studies and seismic analysis.
The Magic Bullet for Safety Citizenship: The Combined Impact of Leadership and Safety Culture
Authors: Egbe Shama Ratnam
Published: March 2023

High-risk organizations are continuously striving to minimize risks and establish a safe working environment. While technology and high standards are crucial, a core aspect of an effective safety management system lies in safe human behavior. The primary aim of this study was to provide an understanding of some of the human and organizational factors that influence safety behavior of employees in the oil and gas industry.

Transformational and transactional styles of leadership were explored along with assessing safety culture with a view to understand their influence on safety behaviors. The commonly investigated form of safety behavior is Safety Compliance, which is seen as the answer to achieving positive safety results. However, in order to go above and beyond, in other words, taking ownership and accountability of safety, another form of behavior is crucial, called the Safety Citizenship Behavior (SCB), which has gained a lot of attention in the past years. In addition to leadership styles, various leader attributes (e.g. leader fairness, trust) were examined in terms of their influence in safety context.

Data was gathered from about 200 employees in the oil and gas sector using the highly recognized measures like the Multifactor Leadership Questionnaire. Mediation and moderation effects were tested based on Baron and Kenny's guidelines.

The results highlighted interesting findings as they threw light on the pivotal role played by trust in influencing safety behaviors, particularly SCBs. Similar effect was seen with regards to fairness and personal identification with the leader; due to its strong correlation with trust. In addition, safety culture, which has been emphasized in the safety/risk literature over 40 years also showed up as a stronger predictor of safety compliance, whereby subordinates’ safety compliance was reinforced with a strong safety culture.

The augmentation effect of transformational leadership, which is known to build on transactional leadership were also investigated, however, the results did not offer as much support as in the literature. This brings into question the considerable emphasis placed on transformational leadership, particularly where prioritization of safety is key.

The results will aid organizations analyze their safety leadership training programs. Further, it also helps leaders understand key attributes they need to embed in interactions with their immediate and wider teams to bring about positive impact on safety. Lastly, the study also highlights the concept of SCB, which is a significant aspect in building an accountable and mindful safety culture.
Measuring Maturity of Well Integrity Management - Analysis of Well Integrity in Brownfield Using Maturity Models for Prolonged Well Lifecyle
Authors: Yakoot Mostafa Sa'eed , Salem Adel Mohamed , Mahmoud Omar
Published: March 2023

Well integrity (WI) is a growing concern in the oil and gas (O&G) industry as fields mature and WI problems increase. In project management, maturity denotes having perfect condition to attain the organization's objectives. Applying the same principle to O&G industry, provides a pathway and basis to achieve excellence in WI management in O&G fields. Maturity of WI management has a direct impact on performance, assurance, compliance, and most importantly operation safety.

A case study from a brown field has been conducted to evaluate the effect of WI management maturity on field performance. The application of well integrity management system (WIMS) in an offshore brown oilfield has been studied. The journey of WI maturity has been presented in detail. All maturity phases have been analyzed starting from program initiation, up to predicting WI failures using machine learning (ML) algorithms.

Three maturity models, that have been developed by different organizations and individuals, were selected for benchmarking of measured maturity level in the WIMS applied. They were selected as they show independency from industry/organization's type. The three models are; organizational project management maturity model (Opm3), capability maturity model integration (CMMI), and Kerzner project management maturity model (KPMMM).

The attained results indicated that K-PMMM provides the best description and level determination of maturity level with WIMS applied. Moreover, it is highly recommended to implement maturity models by including all processes and subsystems in the WIMS, to have better resolution of system gaps.
Seismic-based Reservoir Dynamic Characterization During Reservoir Development
Authors: Wang Bo , Chen Jine , Nie Qihai , Chen Xin , Xiao Dengyi , Qi Qunli , An Fuli , Peng Bo , Gao Xiaoli , Li Qiang
Published: March 2023

Seismic data plays a crucial role in reservoir characterization. Quantitative seismic reservoir characterization workflow aims to extract reservoir properties from seismic data to identify sweet spots for exploration, appraisal and development drilling. This is all the more true if the data is to be used in 4D seismic surveys (Time-lapse seismic) for reservoir monitoring. 4D seismic data can help to capture the reservoir change, realize the reservoir dynamic characterization and facilitate an enhanced understanding for reservoir potential, so as to have the better business decisions and optimized field development plans. In this study, use a SAGD (Steam-Assisted Gravity Drainage) field to demonstrate how to extract reservoir dynamic change and evaluate the reservoir performance from 4D seismic data.
A Probabilistic Method to Populate Petrophysical Groups on Routine Core Analysis Data from Mercury Injection Capillary Pressure Domain
Authors: Celma Rafael , Lavenu Arthur Philippe
Published: March 2023

Analyzing capillary pressure (Pc) is one of the most common methods to create petrophysical groups in carbonates, since the Pc explains the moment when the fluid starts moving in the porous media, how easy or hard is the displacement of the fluid and when there is no further displacement (irreducible saturation of the porous media).

In comparison to routine core analysis (RCA) data, MICP dataset is rather small. However, utilizing all the spectrum of data is critical, more specifically in highly heterogeneous carbonates, hence the need to populate petrophysical groups from MICP to RCA space.

To determine the petrophysical groups from the MICP the following parameters were used: entry pressure, normalized porosity, permeability, rock quality index, and the hyperbolic tangent of each to the MICP samples. The petrophysical groups generated by this method give a very discrete clustering where the ranges of porosity and permeability are well defined. For distributing petrophysical groups from the MICP domain into the RCA domain, a Bayesian Inference approach in the porosity permeability space was used. Porosity and permeability standard deviation and mean for each of the petrophysical groups, were used to build a probability density functions (PDF) which will be taken as our probable scenario to feed the Bayesian Algorithm.

The results from 350 MICP samples show that we could establish a reliable petrophysical groups distribution over 7000 RCA samples. In a second stage, petrophysical groups populated in the RCA space were used to train our logs and create a continuous curve of petrophysical groups that will support the property distribution in our 3D model.
Erosion Rate in a Complex Pipeline Using CFD
Authors: Marrah Aimen , Rahman Mohammad Azizur
Published: March 2023

The main objective of this study is to simulate the dynamic behavior of entrained solid-particles in a pipe flow and its role in the erosion process. A detailed parametric study changing the solid particle diameter, flow rate, pipe diameter, fluid viscosity, and solid particle density was performed to find the critical parameter that affects erosion in a pipeline. To fulfill the objectives of the study, a Computational Fluid Dynamics (CFD) simulation was conducted for water-solid flow within a complex pipeline geometry with rapid alterations in flow directions. The simulation was performed using ANSYS Fluent code. Three different turbulent models: k-epsilon (k-ε), k-omega (k-ω) and Shear Stress Transport (SST) have been compared to find out the best turbulent model validating the simulation results with the experimental results. Flow instability, turbulence, and erosion have been quantified for different sand particle size of 10, 70, 100 and 200 microns and different inlet liquid velocities of 20, 25, 30, 35 and 40 m/s. The inlet velocity has a remarkable effect in the erosion rate. We have observed that if the inlet velocity is increased from 20 m/s to 40 m/s, the erosion rate is increased from 1.73 x10−4 kg/m2.s to 2.11×10−3 kg/m2.s, respectively at a constant particle size of 200 μm. We have also observed that if the solid particle size is increased from 70 μm to 100 μm, the erosion rate is increased from 5.79 × 10−4 kg/m2.s to 8.03 × 10−4 kg/m2.s, respectively, at a constant velocity of 40 m/s. Previous studies have studied the effect of sand particles on the erosion of an elbow; however, this work introduces a complex pipeline which has three elbows and an arch. This study can be utilized for quantifying the erosion rate in complex pipeline geometry with larger pipeline diameters and varying fluid properties.
A Novel Approach for Estimating Formation Permeability in a Highly Heterogeneous Reservoir in Middle East
Authors: Celma Rafael , Lavenu Arthur
Published: March 2023

Estimating flow in the reservoir is critical for production forecasting, 3D modeling and field development. Laboratory experiments are the main source of information for the permeability, but the results might be impacted by a high degree of reservoir heterogeneity, as well as by the upscaling from core to log. The studied reservoir displays a complex lithology — limestone and dolomite – where dolomitization appears to be a clear reservoir rock quality enhancer. High permeability streaks can be related to dolomitized intervals, however a simple porosity vs. permeability function cannot capture the large variation of this property (from 0.1 to 5000mD)

In this study, the volumetrics computed from a comprehensive petrophysical model that includes the integration of core descriptions, XRD, and gamma ray spectroscopy to properly estimate the fractions of limestone, dolomite, clay, and heavy minerals were used. A core to log correlation was made and it clearly showed how the dolomitization improves our reservoir properties, in particular the permeability. Trends functions were established based on the stratigraphy and on the content of limestone/dolomite. These trends were used to train a fuzzy logic model supported by other logs such as: normalized porosity and density-neutron vector angle/length. The vector angle/length are coordinate transforms to convert neutron density into linear independent vectors.

This approach addresses the large variation of permeability related to the strong diagenetic footprint onto the reservoir. The results were compared to permeability from core and KH from PTA analysis, and displayed an error of less than 5%
Estimation of Crack Density using Digital Rock Physics and Experimental Velocity Data
Authors: Chen Jianming , Zhang Haiyang , Arif Muhammad , Tu Yunzhong , Wang Xiaosai , Bouchaala Fateh , Nizamuddin Syed
Published: March 2023

The subsurface geological formations demonstrate a range of porosity including cracks. This characteristic significantly affects the propagation of elastic waves in rocks. In this context, Tang's method relies on crack density and aspect ratio as two important parameters. In this new theory, the crack density and aspect ratio can be obtained by inverting the measured velocities (Vp, Vs) of rocks versus different effective confining pressures under dry and fluid-saturated rocks conditions, which is one way to get the crack density value. Another way to calculate the crack density directly is using X-ray CT images to count the cracks in the core plug rock samples. Finally, after using the two different ways to get crack density value, the relationship between crack density value results in two different methods could be revealed.
Investigation of Critical Requirements for Enhanced Oil Recovery using Lateral Wells in a Layered Reservoir
Authors: Adewole Ezizanami Stephen , Arukhe James Ohioma , Azagbaesuweli Gregory Azuka , Akeredolu Kolawole Peter
Published: March 2023

Enhanced oil recovery from a vertically-stacked layered reservoir with lateral wells completed in the layers is often challenging due to inadequate understanding of the complex dynamics of the displacement process. A mobility ratio, which considers reservoir layers, well design and fluid properties, is derived to search for stability condition in the displacement process. Fluid displacement in real time is considered.

Displacement stability is monitored using mobility ratio derived from pressure distribution for each lateral well completed in each layer of the reservoir, and the enlarged single reservoir. Any well can be used for injection, depending on displacement and injection fluid type. Crossflow interface is assumed as responsible for communication between the layers. A computer program is written to compute mobility ratios in real injection time. Fluid injection time at which mobility ratio is greater than unity and as high as 10 is identified for any well design, layers, and injection fluid properties.

Complete individual layers dimensionless pressure characterization, using layers interface conditions, gives an expression for mobility ratio of interlayer displacement process involving lateral wells. Depending on the nature of injected fluid and overall recovery objectives, any of the layers can be selected for injection or production. Basal waterflooding and gas cycling and crestal gas injection can be studied directly using the expression derived for mobility ratio. The ratio derived gives indication of the duration of optimum clean oil production for any combination of fluid injected. The mobility ratio is affected by individual layer well design, layers fluids and injected fluid breakthrough time. Ratios of well lengths affect length of time of oil production. Longer oil production is possible if the wells have unequal lengths. If the top layer permeability is larger than the bottom layer permeability, waterflooding yields prolonged oil production. Viscosity ratios only slightly affect stability. However, if the bottom layer is used for injection, gas injection for gas cycling, gives appreciable results. Water-free oil production increases as the spacing between the layer wells increases. But well spacing beyond a certain limit does not contribute to further increment in oil production.
Innovative Integrated Workflow to Reduce Uncertainties and Improve Hydrocarbon Recovery
Authors: Boudiba Younes , Pisharat Maneesh , Kelkouli Mohamed , Nettari Ferhat , Meddour Nordin , Seddar Bilal , Babbouchi Reda, Adam , Berbra Abdelhakim
Published: March 2023

In producing fields, remapping reservoir fluid content and new contacts are some of the most important objectives in pursuit of optimized well productivity. Wireline logs and formation testing (FT) data are widely used for this purpose. Continuous fluid data from advanced mud gas (AMG) analysis with downhole logs can be used to generate a comprehensive data set for reservoir evaluation. Each method has its limitation and advantage. Combining and interpreting the output from the fundamentally different data sets require an experienced petrotechnical expert with specific skill sets.

To calculate hydrocarbon volume, and estimate and forecast reserves, formation fluid evaluation has primarily relied on a traditional method that depends heavily on formation pressure measurements. This was achieved through the analysis of gradients and local fluid contacts. This approach can be misleading for brownfields, where a sizable amount of producible hydrocarbon is left in the reservoir.

For characterizing formation fluid, a novel approach using complimentary technologies was adopted. For early hydrocarbon detection and FT program optimization, AMG data were first gathered while drilling. Post-drilling openhole (OH) logs, formation pressure, and fluid data were acquired not only to verify the AMG findings, but also to fill in the gaps regarding water-swept zones, reservoir pressure and depletion, exact fluid contacts, and fluid characteristics to reduce uncertainties.

During the job execution, AMG data were effectively used to provide early formation fluid identification and contacts. This information was used to optimize the wireline advanced fluid analysis stations. AMG analysis identified multiple fluids (wet gas, gas condensate, oil, and water) and revealed a much greater complexity of the reservoir, which could not be achieved with standard formation evaluation or other fluid contact identification techniques based on regional gradient analysis. The fluid types and contacts identified by AMG were then confirmed by the wireline downhole fluid analysis. Using this workflow, a high potential recoverable hydrocarbon oil was identified over a reservoir that was classified as a water zone based on initial evaluation and knowledge.

In this field, an innovative method was adopted for reservoir fluid characterization. This approach, based on digital integration and a unified workflow, was used successfully for fluid contact identification, targeted fluid sampling, and identifying and recovering more hydrocarbon from the swept zones.
How to Achieve Operational Excellence through Digital Transformation
Authors: Hegazy Mahmoud Ibrahim , Alsawi Kamel Abdelhamid , Atwa Mohamed Said , Sayed Mahmoud Sayed , Bakeer Mohebat Mady , Rezk Ramy Sayed , Fouda Ahmed Mohamed
Published: March 2023

Achieving operational excellence in oil and gas industry has a great importance due to their high impact on operational efficiency and effectiveness by proper use of human resources, process, innovation and technology which will positively support the quick decision making, eliminate wastes, maximize the system capacities, optimizing the expenditures and resources.

Methods, Procedures, Process

Operation Management System is an inhouse customized cost-effective software to collect, organize, calculate, allocate and analyze big data from different disciplines which helps oil and gas company operations in many ways to overcome business challenges, data management, enhance workflow efficiency, integrate between different disciplines, save time and cost. Each discipline in each company uses its own workflow and data processing technique which may leave gaps in the interconnections between them. These gaps require work duplication to cover overlap areas.

Results, Observations, Conclusions

Using Operations Management system achieves Generate Global database for all company assets production for better management for asset, well performance, target achievements and automatic notifications for targets over dues DFL, well tests, etc. also, allocate all wells in GIS Map for easy and quick access to well data.

It provides cost control tool over the contract by real-time allocation for actual costs and invoices. Digitalizing all the contracts data and track contract administrative. It provides a smart notifications tool for contracts list that will be expired after 6 months.

Real-time allocation for expenditures over the budget accounts directly from invoices and warehouse modules. it shows budget inception to date, Variance and forecast with option to display cost breakdown just by one click.

Smart Tool for Tracking Invoices process as per Company Cycle to make use of early payment discounts. Automatic review for invoices as per cost reference (Contract or purchase orders) and allocate actual cost directly to both budget accounts and contract.

Manages the process of administering receiving, issuing and approving the tenders of the business. It also provides access to all the tender archived data.

Novel/Additive Information

It helps to detect problems sooner, boost collaboration and improve responses, for safer, more reliable, and more efficient operations.
Optimization Design of CO2 Pre-Pad Energized Fracturing for Horizontal Wells in Shale Oil Reservoirs: A Case Study of the Ordos Basin
Authors: Zang Yuxi , Wang Haizhu , Abderrahmane Hamid Ait , Wang Bin , Wang Tianyu , Tian Shouceng , Stanchits Sergey , Cheremisin Alexey
Published: March 2023

An improved recovery technique using carbon dioxide (CO2) pre-pad energized fracturing is presented to address the issue of low recovery in depleted development of shale reservoirs in the Ordos Basin. This study quantitatively evaluates the effect of CO2 pre-pad energized fracturing under different engineering and geological parameters. The geological model of the target block was created in GOHFER using field logging data from the Ordos Basin oilfield. By coupling the reservoir simulator CMG, a three-dimensional wellsite-scale long horizontal mechanism model was established, considering the artificial hydraulic fracture model. The influence of engineering parameters and geological parameters on CO2 distribution was quantitatively evaluated.

According to the outcomes of the simulation, the production potential of shale oil reservoirs can be significantly increased by using the CO2 pre-pad energized fracturing development method. Important engineering factors affecting the stimulation include the CO2 injection volume and soaking time, and the geological factors include the porosity, permeability, and layering. When the injection amount reaches a certain level, the growth of CO2 sweep area decreases. With the increase of immersion time, the CO2 sweep range gradually increases. Reservoir porosity and permeability affect CO2 sweep in the lateral direction. Considering the front slick water fracturing fractures, the impact on the CO2 sweep range is not apparent.

Combined with GOHFER and CMG numerical simulation software, this study can realize the refined description of reservoirs considering artificial hydraulic fracture networks. According to the CO2 injection range, the effect of CO2 pre-pad energized fracturing under different engineering and geological conditions can be quantitatively evaluated. This study can be used as a reference CO2 pre-pad energized fracturing of shale oil reservoirs in the Ordos basin.
Breaking New Ground. Enhancing Polycrystalline Diamond Compact (PDC) Bit Performance in Chert Formations through Use of Shaped Cutter Technology
Authors: Abdelrazik Mohamed , Ismail Ahmed , Suleiman Ahmed , Hanafy Hatem
Published: March 2023

Cherty formations are notoriously challenging for fixed cutter drill bits and present a costly challenge for operators who routinely experience short intervals and numerous trips. The predominant limitation is short bit life due to mechanical failure of the cutters. This paper details how an inter-company collaboration led to the development of a design philosophy and a novel shaped cutter technology that resulted in a step change in drilling efficiency and drilling consistency in chert formations.

A collaboration between companies was initiated that commenced with a comprehensive study into the cutter-rock interaction to identify the failure mechanism of chert. The results of the research were then used to determine the critical design levers required to overcome these challenges, extended bit life and maximize drilling efficiency. Two fixed cutter drill bits in the 6-in. and 8.5-in. hole sizes that incorporated the new design philosophy and shaped cutter technology were designed. These bits were then field tested in the Egypt Gulf of Suez interbedded carbonates application characterized with the presence of dark brown chert.

The new 6-in. and 8.5-in. designs were tested twelve times across four different fields. The runs were then evaluated against durability, rate of penetration (ROP) and cost per foot (CPF) compared to field offsets. In the 6 in. section, the new design drilled the entire section of 3,369-ft that includes 381-ft cherty formation with one bit compared to three bits previously required to drill the same interval. For the same offsets, an improvement of between 50-85% in ROP was achieved. The CPF assessment demonstrated drilling cost reduction between 24-75% across the fields tested. In the 8½ in. section, the new design drilled the entire section of 6,141 ft that includes 296-ft cherty formation with one bit compared to four bits previously required to drill the same interval. ROP wise, an improvement between 59-178% was achieved which corresponded to a CPF reduction of between 41-69% across the fields tested. These field tests demonstrate ground-breaking results in the durability, ROP and CPF performance metrics measured. Furthermore, the number of runs and diverse nature of the fields tested demonstrate the consistency of this new approach to drill cherty formations with full directional control and mitigating downhole vibration severity.

A re-examination of the failure mechanism of chert drilling and the root cause behind drilling deficiencies in cherty applications conducted in a collaborative environment has paved the way for a step change in drilling performance. Novel design philosophies were created, laboratory tested, and field validated for consistency of the trials. As the drilling industry continues to explore unchartered applications to ensures cost efficient solutions is paramount to success
Data Science Techniques for Unbiased & Efficient Production Analysis
Authors: Jordan Colin Lyle , Koochak Roozbeh , Roberts Martin
Published: March 2023

Analyses have been widely applied in production forecasting of oil and gas production in both conventional and unconventional reservoirs. In order to forecast production, to estimate reservoir properties, or to evaluate resources, various statistical and machine learning approaches have been applied to various reservoir analysis methods. Nevertheless, many of these methods are suboptimal in detecting production trends in different wells due to data artifacts (noise, data scatter and outliers, inadequate SCADA systems, production allocation problems) that obscure unit reservoir signals, production trends, and more leading to large forecast error, or fail due to lack of data access (inadequate SCADA systems, missing or abhorrent data, and production allocation problems). This work outlines a method that is currently being used in a commercial setting which combines advanced analytics and machine learning with a modern cloud architecture, provide rapid, repeatable, unbiased estimates of original hydrocarbon -in-place (OHIP), estimated ultimate recovery (EUR), and remaining recoverable (RR), and even deliverability forecasts - all in the presence of abhorrent data.
Development of Emulsified Acid System using Organoclays
Authors: Mahmoud Ali Adel , AL-Dogail Ala Shafeq , Gajbhiye Rahul Narayanrao , AlSultan Abdullah Saad
Published: March 2023

Matrix acidizing technique is used to enhance the production of hydrocarbons from a reservoir, especially in low permeable reservoirs and in the case of formation damage. In carbonate reservoirs, acid stimulation jobs are challenging due to the acid's strong reactivity with the formation. Thus, the ability to create wormholes will be limited. Wormholes allow hydrocarbons to be produced by flowing into the wellbore. Emulsified acids system helps to overcome this challenge by reducing face dissolution. Recently, Pickering emulsions have attracted attention due to their easy preparation and enhanced stability features. In Pickering emulsions, solid microparticles that localize at the interface between liquids are used as stabilizers instead of surfactants.

The preparation of emulsified acid system (EAS) is a complex process sensitive to several parameters governing the properties/feature of the emulsified system. The parameter includes mixing the aqueous and oleic phase, the rotational speed, the time of mixing, and the quantity of emulsifying agent (organology). It requires performing several experiments to identify the proper procedure and optimum range of the parameters affecting the emulsified acid preparation of desired properties.

In this study, several experiments were performed using three types of organoclays (OC) namely Claytone-SF (strong), Claytone-EM (medium), and Laponite-EP (weak). Thermal stability tests were carried out at room temperature, 80ºC, and 120ºC. Rheology tests were performed for the most stable emulsions. This study investigated the potential of using special nanoparticles as emulsion stabilizers instead of surfactants. A proper sequence of the component mixing and optimum range of the factors affecting the emulsion preparation and properties were identified. This work aims to study the parameters involved in the emulsified acid preparation and optimize them to obtain a stable EAS.
Numerical Investigation of Hybrid Carbonated Smart Water Injection (CSWI) in Carbonate Cores
Authors: Hassan Anas Mohammed , Al-Shalabi Emad W. , Ghosh Bisweswar , Tackie-Otoo Bennet N. , Ayoub Mohammed Abdalla , Adel Imad A.
Published: March 2023

Carbonated smart water injection (CSWI) is a potential hybrid EOR technology under development. The process involves dissolving CO2 in smart water ripping the benefits of the synergic effect of CO2 injection and smart water. Based on the experimental laboratory data, including core flood experiments, this paper presents numerical investigations of the combined impact of dissolving carbon dioxide (CO2) in smart water (SW) on oil recovery in carbonate cores. An advanced processes reservoir simulator was utilized to build a core-scale model. Both the physics of smart water flooding as well as CO2-gas injection were captured. The generated model was validated against the coreflooding experimental data on hybrid CSWI, including cumulative oil production (cc) and oil recovery factor (%). The Corey's correlation relative permeability model was used for capturing the multiphase flow. The numerical model was used to understand the underlying recovery mechanisms and crude oil-brine-rock interactions during CSWI. The model was further utilized to perform sensitivity analysis of different parameters and to optimize the CSWI design.

Based on the numerical results, the experimental coreflooding data were accurately history-matched using the proposed model with a minimal error of 8.79% applying the PSO-based optimization method. Moreover, this history-matched model was further used for sensitivity analysis and optimization of the CSWI process. The objective functions for sensitivity analysis and optimization are based on minimizing the history-matching global error and maximizing oil recovery. The optimized design was achieved by performing a sensitivity analysis of various input parameters such as oil and water saturations (Soi and Swi), DTRAP (i.e., relative permeability interpolation parameter). On the other hand, in terms of maximizing the oil recovery while minimizing the usage of injected CSW solutions during CSWI, the optimal solution via the PSO-based approach achieved a cumulative oil recovery of 55.5%. The main mechanism behind additional oil recovery with CSW is due mainly to wettability alteration and ion exchange between rock and brine. Additionally, CSWI was found to be more efficient in releasing trapped oil compared to waterflooding, indicating the synergic effect of dissolved CO2 in SW solutions. Based on this research, the envelope of CSWI application in carbonates for CO2-storage is expected to expand. This study presents one of the few works on numerical modeling of the CSWI process and capturing its effects on oil recovery. The optimized core-scale model can be further used as a base to build a field-scale model. This promising hybrid CSWI process under optimum conditions is expected to be economical and environmentally acceptable, which promotes future field projects.