bluuebunny/crossref_metadata_2025_split huggingface dataset:
Patronage Factors and the Behavior of Customers towards Islamic Banking in Nigeria
Authors: Aigbovo Omoruyi 
Published: October 2022

In this study, the selection criterion for Islamic banking in Nigeria was examined. Thus, the study investigates whether variables like; rate of return, Islamic teaching, bank’s reputation and service quality account for why customers patronize Islamic bank (Jaiz bank) in Nigeria. The general behavior of customers towards Islamic banking in Nigeria was also investigated. A survey research design was adopted and all the customers of Jaiz bank branch in Herwa Gana Ward, Commercial Area of Gombe Local Government Area constitute the population of the study. A suitable sample of 60 respondents was the study's focus. The respondents were chosen using a convenient sampling strategy. 52 of the 60 administered surveys were deemed to be valid. The data were examined using simple percentages, descriptive statistics, correlation, and regression. It was discovered that in Nigeria, customers' attitudes toward Islamic banking are significantly influenced by the rate of return, Islamic principles, and bank reputation. In order to draw in more clients, the study advises Jaiz Bank to build upon its positive reputation and enhance the quality of its services. They can also promote the religious traditions in their advertisements to attract customers who are motivated to benefit from interest free banking services.
Plio-Pleistocene Planktic Foraminiferal Biochronology of ODP Site 762B, Exmouth Plateau, Southeast Indian Ocean
Authors: Singh Ashutosh K. , Sinha Devesh K. 
Published: October 2022

ABSTRACTThe Indonesian Throughflow region connects the tropical Pacific Ocean with the eastern Indian Ocean, and variability of the Throughflow during the Plio-Pleistocene has been related to major climate shifts at the global level. Planktic foraminiferal biostratigraphy integrated with magnetochronology provides a robust time framework for assigning age control to major paleoceanographic events. Understanding of the coupled histories of the El Niño Southern Oscillation, Western Pacific Warm Pool, Indonesian Throughflow, and the eastern Indian Ocean has greatly benefitted from the chronological framework provided by planktic foraminiferal biostratigraphies from these regions. Ocean Drilling Program (ODP) Hole 762 lies under the influence of the Leeuwin Current, originating from the Indonesian Throughflow. Multiproxy data have been collected from Hole 762B and other nearby sites for paleoceanographic interpretation. However, a detailed planktic foraminiferal biostratigraphy integrated with magnetochronology is not available from this site. We provide here the sequential order of planktic foraminiferal First Occurrence (FO) and Last Occurrence (LO) events, which allowed us to divide the examined section into seven biostratigraphic zones. The biostratigraphy was integrated with magnetostratigraphy using revised ages of magnetochrons, which yielded biochronological age estimates for planktic foraminiferal events. A major planktonic faunal turnover between 3.4 and 2.7 Ma is probably related to the onset of the Northern Hemisphere glaciation and related changes in the Indonesian Throughflow. We have compared our numerical age estimates with published ages from other parts of the world. The diachronism observed probably is related to the local oceanographic setting of ODP Hole 762B, which has been alternatively influenced by changing strengths of the warm Leeuwin Current and the cold west Australian Current. The biochronology established here will be useful for correlating paleoceanographic events in the region.
Medhat M. Kamal 2023 SPE President
Authors: Kamal Medhat M. 
Published: October 2022

Medhat (Med) M. Kamal
Medhat (Med) M. Kamal is a Chevron Fellow Emeritus and an Honorary Member of SPE. He previously worked for Cairo University, Amoco Production Company, Flopetrol Schlumberger, and ARCO Exploration and Production Company.
Kamal has more than 45 years of industry experience in well testing, reservoir description, and production and reservoir engineering.
He was an SPE Distinguished Lecturer in 1997–1998 and 2018–2019 during which he presented his lectures more than 80 times in 35 countries. He served as a member and chairman of SPE Annual Meeting Well Testing subcommittee and textbook and monograph committees, and as executive editor, associate editor, and technical reviewer for SPE Reservoir Evaluation & Engineering and the Journal of Petroleum Technology. He chaired the first SPE conference on research and development in 2007 and the Western Regional Meeting (2019). He served on the boards of directors of Mid-Continent, Gulf Coast, Dallas, and Golden Gate sections of SPE and chaired the Dallas and Golden Gate sections. He also served on the SPE International Board of Directors (2007–2009) as the Regional Director of Western North America.
Kamal has been recognized with several regional and international awards including the SPE Cedric K. Ferguson Medal, SPE Formation Evaluation Award, SPE Distinguished Service Award, SPE North and East Texas Regional Service Award, and the Texas Petroleum Engineer of the Year Award.
He holds a BSc in petroleum engineering and an MSc in engineering from Cairo University and an MS and PhD in petroleum engineering with a minor in computer science from Stanford University.

Let’s begin with a brief introduction of the theme you’ve selected for your presidency, Petroleum++. What will you be emphasizing?
There are three elements to this theme: petroleum, the first plus, and the second plus. Let me explain them one at a time.
“Petroleum” refers to the challenges petroleum engineers face now and for the foreseeable future to provide the world with the hydrocarbon energy it needs. By hydrocarbons, I mean oil and natural gas, not coal.
We can think of the entities that study and predict the world’s future need for energy as three groups: the government entities like the US Energy Information Administration (EIA) and the European Union International Energy Agency (IEA); the major international operators like ExxonMobil, Shell, etc.; and the national oil companies. The predictions provided by all three groups indicate the oil and natural gas share in the energy mix may decline slightly from a little over 50% currently to a little below 50% by 2050. However, the needed volume of hydrocarbons will increase as the world population moves from around 8 billion now to about 9.8 billion in 30 years and as the standard of living continues to improve in the developing regions such as Africa and Asia.
When we look at the world’s current reserves and the current technology to produce these, you can add things up and see that we must continue our technical advancements to meet the growing demand for energy.
Big Fracs That Add More Oil May Also Mean More Water, and That Can Be All Right
Authors: Rassenfoss Stephen 
Published: October 2022

A few years ago, Occidental Petroleum managers were puzzled by why their recent Permian Basin wells were producing more water per barrel of oil, so they asked some engineers to figure out what was wrong.
Their concern was understandable. While the company’s well evaluation system was supposed to screen out prospects likely to become big water producers, the amount of water flowing out of wells in the Delaware Basin drilled after 2018 far exceeded volumes from previous years.
“We found that newer wells had a steeper increase in water cut over time than older wells,” the coauthors of an Occidental paper wrote about the work done to answer the question. They added, that “pre-2018 wells had an average water cut increase of 4% in the first 300 days (after cleanup) and then stayed relatively flat after 300 days, whereas post-2018 wells’ water cut increased at an average of 12% in the first 300 days and 16% in the first 600 days before reaching a plateau” (URTeC 3720245).
Those trends, plus wells ultimately reaching an 80% water cut, suggested that a string of wells may have been drilled into water aquifers. While that is a risk in the Permian, the evidence suggests that the geology in the wells they compared was similar before and after 2018, even though the water cut levels were not.
A big difference was how the wells were fractured. In 2018 Occidental began doing bigger fracturing jobs, using more water and sand per foot, which increased the number of stages and fracturing clusters.
Those changes added oil production because “high conductivity speeds production and enhances the well’s net present value,” said Samuel Amadi, a senior reservoir engineering advisor for Occidental, while presenting the paper at the recent Unconventional Resources Technology Conference (URTeC).
Based on production records, the water/oil ratio also was higher. Using data from comparable wells before and after the completion design changes, a model was created that quantified the relationships between fracturing designs and the oil, water, and natural gas flowing out of Occidental wells.
“One recurring observation in all these completion scenarios is that a better-completed well will have higher fluid withdrawal and a steeper water cut trend after cleanup than a poorly completed well for the same reservoir and operating conditions,” the paper’s authors wrote.
A coauthor, Xueying Xie, principal and manager of unconventional recovery design at Occidental, added that based on her team’s simulations, “we know we are not doing something wrong. This is doing a better job. It speeds production.”
But unlike a well drilled through a fault connecting it to an aquifer, there was a limit to the water produced from these extremely tight formations. Like the oil production in more aggressively completed wells, the water production peaked at a higher level than the less intensely fractured wells but declined over time to a similar level.
“On the water production side, just the pace changes,” Xie said.
Silixa Chief Expects CCS Boom To Create “Huge Opportunity” for Fiber Optics
Authors: Jacobs Trent 
Published: October 2022

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Fiber optics represents one of the biggest technological success stories in the recent history of the oil and gas industry.
A single fiber-optic cable installed outside the casing, inside the tubing, can deliver a wealth of data over a well’s life cycle. It can sense minute shifts in acoustics, temperature, and has recently been developed to detect changes in near-wellbore strain—all prized clues as to what is helping or hurting productivity.
But less than a decade ago, the ultrathin glass cables were considered exotic, and only a handful of first adopters dared to deploy them downhole. The sensing technology has, of course, gone on to become a mainstay of subsurface diagnostic programs for operators working across the planet.
Now, with their skills sharpened in the upstream industry, many fiber-optics developers are gearing up for what appears to be a coming boom in carbon capture and storage (CCS) capacity.
Among them is UK-based Silixa.
Founded in 2007, Silixa’s innovations have improved on the spatial resolution of fiber measurements and enabled real-time monitoring of fracture growth and production. Last year, the company installed the world’s first subsea distributed acoustic sensing (DAS) system for BP to enable 4D seismic acquisition in the Gulf of Mexico.
Glynn Williams, CEO of Silixa, shares in this Q&A how all this experience points to fiber having a major role to play in the rise of the CCS sector—especially when it comes to safety and regulatory matters.
His background features more than 30 years spent in the upstream industry’s data acquisition arena. Williams also holds a degree in mining engineering from the University of Wales and is a member of SPE.

Where do you see the carbon sequestration sector headed—is an inflection point coming?
This now consumes a lot of my time.
We see CCS as a huge opportunity because we’ve been engaged with the sector for a long period of time.
For the type of solutions that we deliver, we can extract perhaps $1 of value for each ton per year of CO2 that is stored. When you look at the projections by the IEA, which suggest we may be storing over 7.5 gigatons of CO2 by 2050, that relates to $7.6 billion of value.
That’s if we were to be successful in securing all of that—there will be other players alongside us. But to this point, we’ve provided services to 17 CCS sites going back as early as 2012.
So, we’ve got a track record with our environmental business unit that serves CCS, and we’re seeing in the current period a twofold increase in pipeline opportunities. We feel that particular business unit will account for 40% of our overall pipeline in 2023.
Technology Focus: Field Development (September 2022)
Authors: Wilson Adam 
Published: October 2022

In this month’s Field Development feature, SPE conference authors place an emphasis not only on original research and findings but also on validation and refinement of existing techniques that may not have received thorough attention in the literature. As operators strive to achieve the greatest returns possible from technically, environmentally, and economically challenging plays, they are driven to innovate new approaches and to fine-tune existing ones.
In paper SPE 206267, the authors investigate the performance of a distributed quasi-Newton (DQN) derivative-free optimization (DFO) method, which, they write, had not yet been validated by realistic applications or compared with other DFO methods. They integrate DQN into a versatile field-development optimization platform designed for iterative work flows enabled through distributed parallel flow simulations. The method was field-tested on two realistic applications and identified the global optimum with the least number of simulations and the shortest run time on a synthetic problem with a known solution.
The authors of paper SPE 207146 create and evaluate a development plan for an oil field discovered in a remote offshore environment in the Niger Delta. Because the oil in place was uncertain, a probabilistic approach was used to estimate the stock-tank oil originally in place using low, mid, and high cases. Keeping in mind governmental regulations to maintain the reservoir pressure above bubblepoint, the authors propose a development plan that is marginally base modeled and, despite the uncertainty of oil prices in the market, able to cover any unforeseen situations.
Finally, the authors of paper SPE 208882, addressing the challenge posed by cumbersome integrated technical work flows for multiwell fracture modeling and reservoir simulation, use tools existing in the literature to quantify the effect of changing well spacing on well productivity for a given completion design using a simple, intuitive empirical equation. After describing and qualifying the use of their approach, they apply it to a case study from the Permian Basin.
Recommended additional reading at OnePetro: www.onepetro.org.
OTC 31151 - Autonomous Subsea Field Development—Value Proposition, Technology Needs, and Gaps for Future Advancement by Giorgio Arcangeletti, Saipem, et al.
SPE 206533 - Field Development Optimization Using Machine-Learning Methods To Identify the Optimal Waterflooding Regime by Alexey Vasilievich Timonov, Consultant, et al.
URTeC-2021-5301 - Unconventional Reservoir Development Performance Reviews—the Northern Midland Basin Case Study by Hongjie Xiong, University Lands, et al.
Technology Focus: Oilfield Chemistry (September 2022)
Authors: Fuller Michael J. 
Published: October 2022

The technical arena of oilfield chemistry is no longer an area of interest only to production operations. When completions operations (including hydraulic fracturing) yield wells with a low productivity index (PI), all chemical constituents introduced downhole (e.g., drilling, completions, and stimulation) are scrutinized for deleterious interactions with the mineralogy, formation fluids, and one another. Field-relevant work flows and improved test methods are critical to the investigation of root causes for a low PI.
Several studies have been published showcasing new additives and fluids that can improve well productivity. However, often the methods to select and optimize these products do not account for the uncertainties and challenges of an actual wellsite (e.g., sample collection and integrity, challenging surface conditions, and representative samples).
Operators must challenge themselves first to document and rank the most likely causes of low or declining well productivity using actual well samples and parameters. Then, collaboration with chemical and service providers is used to technically justify (a) the selection and optimization of chemical additives to maintain or stimulate productivity on existing producers and (b) the optimization of additives for future well completions in the same reservoir.
The selected papers represent sophisticated work around the phenomena of scale and precipitation that can have dramatic effects on productivity, specifically in shale and tight completions. These papers include comprehensive work flows to analyze recovered samples (to confirm damage identification) as well as improved methods to analyze the concentration of scale inhibitor in produced water with enhanced simplicity and accuracy. The selections also include integrated studies of the phenomena of chemical species at critical interfaces (formation, cement, and casing) that can seed production of damaging deposits, with an eye toward prevention of their effects on productivity.
Recommended additional reading at OnePetro: www.onepetro.org.
SPE 205284 Surfactant and Friction-Reducer Interaction in High-Salinity Slickwater Fracturing by Abdelrahman Kotb, Texas A&M University, et al.
SPE 209507 The Oda Field: From Scale Prediction to Reality—Why Squeezing Was Not Necessary Despite a High Calcium Sulphate Risk by Baard Kaasa, Scale Consult, et al.
URTeC 208302 A Flexible Biomimetic Superhydrophobic and Superoleophilic 3D Macroporous Polymer-Based Robust Network for the Efficient Separation of Oil-Contaminated Water by Fahd I. Alghunaimi, Saudi Aramco, et al.
An Integrated Management of Change Program (MOC) for Oil and Gas Industry through Blockchain Technology and Smart Contracts.
Authors: Laskar Sandipan 
Published: October 2022

Abstract
New Technologies (blockchain, autonomous cars, artificial intelligence, and the internet of things) are revolutionizing industries such as finance, banking and transportation by improving efficiency and effectiveness in these businesses around the world. However, not much work is done on applying these technologies in the oil and gas industry. So, a tremendous opportunity exists to leverage these new technologies for possible applications in oil and gas. This paper explores the application of blockchain and smart contracts in managing an effective Management of Change (MOC) program and integrating it with operations to process real-time changes leading to faster and safer decision making. The paper is divided into two sections; the first provides an overview of the technology, and the second focuses on integrating smart contracts and blockchain technology to leverage the MOC program. This paper could be used to roll out new and improve existing MOC programs.
The application of emerging technologies such as distributed ledger and smart contracts are still at the rudimentary level for oil and gas with few applications around trading and logistics. This paper unlocks the possible application in managing changes in the oil and gas, which will provide a solid platform for future innovations. The oil and gas industry are moving at a faster pace to achieve the next level of efficiency and effectiveness for sustainable growth, the key will remain in the early adoption of these emerging technologies for safer operation. The application mentioned in this paper will provide a company with an additional competitive advantage as they could effectively manage their data to make faster decisions; and achieve higher efficiency and safer operations simultaneously.
RFID-GPS Enabled Project Material Control
Authors: Sahoo Subrat 
Published: October 2022

Abstract
Material control plays a vital role in the success of any construction linked Project. Any deviation in material identification and traceability due to human error, leads to cost and time impact due to shortages, delays due to re-ordering and price escalation. Radio Frequency Identification (RFID) device coupled with Global Positioning System (GPS) technology helps in maintaining real-time material database, with real-time location of materials at all stages of the project. RFID technology helps in the material identification and RFID tags are used for locating the materials utilizing the contact-less RFID reader. GPS technology helps in material positioning segment indicating the material location in the designated grid. RFID and GPS together establish their coordinates which instantly detects the material position and indicates an image of the storage yard digitally on the screen that eases material traceability in the designated space. Implementation of an RFID-GPS enabled material control system creates a dynamic material database that brings in transparency and real-time information on material status.
RFID-GPS system enables ‘End to End’ Material Tracking with updated real-time data and physical availability status throughout project duration starting from the receipt, storage, issuance and further installation at site till start-up. RFID-GPS enabled system ensures faster delivery of material information as compared to the manual processes and aids material coordinator with reliable information that can help to take decisions for optimization of the project vitals. Real-time information about material receipt upon entry into project premises without time lag helps to acknowledge missing items and generate short supply materials instantly, thereby averting schedule disruption. Any missing or un-traceable material is notified well in advance for timely action. Dynamic material database keeps all stakeholders in unison on the inventory status and can reduce incidents or loss of material from site. The system has definite advantage of reducing the Construction man-days lost due to re-works arising out of material identification, searching, segregation based on material composition. RFID systems have the potential to improve work productivity and enhancing better project schedule adherence, overcoming human error in manual material control at project sites.