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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper URTeC 198192, “Production Performance Evaluation From Stimulation and Completion Parameters in the Permian Basin: Data-Mining Approach,” by Mustafa A. Al-Alwani, SPE, and Shari Dunn-Norman, SPE, Missouri University of Science and Technology, and Larry K. Britt, SPE, NSI Fracturing, et al., prepared for the 2019 SPE/AAPG/SEG Asia Pacific Unconventional Resources Technology Conference, 18–19 November, Brisbane, Australia. The paper has not been peer reviewed. The complete paper uses 3,782 unconventional horizontal wells to analyze the effect of proppant volume and the length of the perforated lateral on short- and long-term well productivity across the Permian Basin. Tying cumulative production to completion and stimulation practices showed that increasing pumped proppant per well from 5 million to less than 10 million lbm yielded a 34% increase in 5-year cumulative average barrels of oil equivalent (BOE). Raising the pumped proppant per well to 10 million-15 million lbm and 15 million-20 million lbm increased 5-year cumulative BOE from the previous proppant range group to 27% and 18.5%, respectively. Introduction For this study, stimulation chemical data from Permian (Midland) Basin wells were downloaded from FracFocus for all horizontal wells completed and stimulated between 2012 and 2018. The data were then subjected to rigorous cleaning and processing, a process detailed in the complete paper, and then combined with DrillingInfo completion and production parameters. Combining these data provided ample parameters for stimulation, completion, and production data. The objective of the study was to investigate the production performance of Permian Basin wells as a result of different ranges of stimulation and completion parameters. Fig. 1 shows a database representation of the major counties in the Permian Basin with the number of wells in each county. Results and Discussion To substitute for any quantities of produced gas, all production data have been converted to BOE by using the conversion factor of 1 BOE=6 Mcf. The amount of proppant being pumped and the length of the perforated lateral length have been selected to represent the stimulation size and the completion magnitude, respectively.
- North America > United States > Texas (1.00)
- North America > United States > New Mexico (1.00)
- North America > United States > Oklahoma > Major County (0.25)
- Oceania > Australia > Queensland > Brisbane (0.25)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
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- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Data mining (1.00)
Summary The Ivishak (sometimes referred to as the Sadlerochit) Reservoir is the largest producing horizon in the Prudhoe Bay Field. The field, located on the coastline of the Beaufort Sea, has been divided into eight zones with lower sections being deposited in low energy, marine and delta-front environments and the remaining zones consisting of sandstones and conglomeratic units deposited by braided streams. Subsequent burial, structuring and hydrocarbon emplacement resulted in a maximum accumulation 40 million years ago with a hydrocarbon column thickness of 2080 feet. Continuing burial resulted in flattening and hydrocarbon spillage resulting in the configuration at field discovery with a hydrocarbon column thickness of 1050 feet. Understanding the structural and hydrocarbon histories is key to understanding and calculating the gas, oil and water saturation distributions at the time of field discovery since some areas of the reservoir appear to have been in capillary equilibrium with the discovery oil-water contact while structurally high portions of the reservoir appear to be in equilibrium with conditions at the time of maximum hydrocarbon accumulation. Introduction and Geologic Setting Prudhoe Bay, the largest oil field in North America, is located on the North Slope of Alaska along the coastline of the Beaufort Sea (see Figure 1) halfway between the National Petroleum Reserve Alaska on the west and the Arctic National Wildlife Range on the east.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.50)
- Geology > Geological Subdiscipline > Stratigraphy (0.49)
Production Performance Evaluation from Stimulation and Completion Parameters in the Permian Basin: Data Mining Approach
Al-Alwani, Mustafa A. (Missouri University of Science and Technology) | Dunn-Norman, Shari (Missouri University of Science and Technology) | Britt, Larry K. (NSI Fracturing) | Alkinani, Husam H. (Missouri University of Science and Technology) | Al-Hameedi, Abo Taleb T. (Missouri University of Science and Technology) | Al-Attar, Atheer M. (Enterprise Products) | Trevino, Hector A. (Missouri University of Science and Technology) | Al-Bazzaz, Waleed H. (Kuwait Institute for Scientific Research)
Over the last decade, there have been numerous advancements in horizontal drilling applications and in combination with hydraulic fracturing there has been a plethora of growth in producing unconventional resources. Literature in unconventional well performance shows a close correlation between the oil and gas prices and the operators’ willingness to pump more or less proppant in their wells. Despite this general trend, operators are constantly assessing the optimization of completions design to find the optimum stimulation and completion applications. This paper utilizes 3782 unconventional horizontal wells to analyze the impact of proppant volume and the length of the perforated lateral on short and long-term well productivity across the Permian (Midland) Basin. The raw stimulation data were collected from FracFocus website. Rigorous data management techniques were utilized to build a comprehensive dataset with all the volumes of proppant, water, perforated lateral length, and all other stimulation chemicals. Quality control and data validations were applied to the dataset and all outliers were removed. In this study, the amount of the proppant pumped is compared to the cumulative production of equivalent barrel of oil (BOE) for the first year, 2 years, and five years. The effect of normalized proppant per perforated foot on the cumulative production is also investigated. Tying cumulative production to completion and stimulation practices, showed that increasing the pumped proppant per well from 5 million pounds to less than 10 million pounds, yielded a 34% increase in the five years cumulative average BOE. Stepping up the pumped proppant per well to 10-15 million pounds and 15-20 million pounds increased the 5 years BOE cumulative from the previous proppant range group to 27% and 18.5%, respectively. The cumulative production per foot versus the amount of pumped proppant, lateral length versus production, cumulative production per foot versus lateral length ranges, and finally the proppant per foot versus cumulative production per foot are all discussed in this study. This study represents a descriptive analysis approach to investigate the impact of different stimulation and completion designs on short and long-term cumulative production.
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
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- Information Technology > Data Science > Data Mining (0.50)
- Information Technology > Data Science > Data Quality (0.48)
Abstract Since 1995, the global LNG industry has mounted a recovery of vitality and energy few in the 1980s thought likely. Improvements in technology that lowered its incremental production, transportation, and regasification costs combined with resurgence in worldwide natural gas demand and price to force LNG into the energy limelight as never before. This paper presents an overview of global LNG capacities—production, shipping, and regasification—as of Jan. 1, 2008. It will also review world LNG markets, look at individual regions and projects, and conclude with a view of near and mid-term industry issues. 1. Introduction The nature of natural gas as a fuel restricted it to regional use throughout most of the last half of the 20th Century. Limited means of moving gas conspired with small and scattered world markets to keep the fuel cheap and often, where produced, flared as a nuisance. Even with advent of larger and longer regional, and sometimes interregional pipelines, natural gas use remained geographically constrained. Mostly in Asia and mainly due to steady growth of Japanese and Korean demand did LNG grow over the last 30 years of the 20th Century. By the end of the 20th Century, however, it had become clear to the global natural gas industry that the technical means for moving natural gas in its cryogenic state—liquefied, that is—held the potential for circumventing regional and global geographic barriers. Demand in the 1990s, pushed by public recognition of gas as a more environmentally benign fuel than oil or coal, helped force up the incremental value of natural gas (per million cubic feet/day, MMcfd; or million cubic meters). These two forces—demand and price—then combined to revive the LNG industry outside Asia from the stagnation it had largely fallen into in the late 1980s after a brief surge in the 1970s. By the late 1990s, moving supplies of natural gas as LNG from such formerly stranded areas as off Western Australia, Qatar, and West Africa to markets many miles distant over oceans and seas became not only possible but also economical. By the first decade of the 21st Century, nations with large reserves of natural gas were pushing to develop liquefaction projects, setting off waves of shipbuilding and of plans for regasification projects in market areas. This paper presents an overview of global LNG capacities—production, transportation, and regasification—as of Jan. 1, 2008. It will also review world LNG markets, look at individual regions and projects, and conclude with a view of industry issues. 2. Markets The promise of global LNG is the promise of minimal or no market-specific or geographic barriers to trade, a vision that is unlikely ever to be realized. From the beginning, long-term contracts of generally 20 years dominated and continue to characterize most commercial arrangements. But pricing references differ for Asia-Pacific, Europe, and North America. Each of these regional markets has its own pricing mechanism that reflects and reinforces geographic barriers among them. These commercial differences combined with regional concentrations of end users and with the nature of natural gas will likely prevent the kind of global fungibility found in crude oil and its products.
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- Energy > Oil & Gas > Midstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.69)
- Oceania > Australia > Western Australia > Burrup Peninsula > North West Shelf > Carnarvon Basin > PL WA-350-P > Pluto Field (0.99)
- Oceania > Australia > Western Australia > Burrup Peninsula > North West Shelf > Carnarvon Basin > PL WA 34-L > Pluto Field (0.99)
- North America > Canada > Saskatchewan > Western Canada Sedimentary Basin > Alberta Basin (0.99)
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ABSTRACT. India is among the lowest consumers of energy in the world. Moreover about 80 per cent of her needs are met by non-commercial sources. With the increase in population and tempo of social and industrial progress, the requirements will increase and the emphasis will shift from noncommercial to commercial sources of energy. Handicapped as the country is because of the heavy strain on her foreign exchange balance, the interplay of economic factors restricts the rapid development of coal, hydro and nuclear resources. India never consciously planned for oil. Now she is faced with the dual problem of finding more oil for potential demands in her various sectors of economy and bridging a widening imbalance between the production and consumption of major products like motor gasoline and middle distillates. The stress is, therefore, laid on continuous exploration effort, on increase in refining capacity, on developing through intensive research refining techniques to suit the resources and pattern of demand and lastly on more coordination in planning for energy. RESUME. L'Inde est l'un des pays dont la consommation d'énergie est la plus faible du monde. De plus, 80% environ de ses besoins sont assurés par des sources non-commerciales d'énergie. Etant donné l'accroissement de sa population, ainsi que ses progrès rapides dans le domaine social et industriel, ses besoins augmenteront et eile devra exploiter les sources commerciales d'énergie, plutôt que non-commerciales. Dans ce pays, handicapé comme il l'est par le manque de devises étrangères, divers facteurs économiques restreignent le développement rapide des ressources en charbon, en énergie hydroélectrique et atomique. L'Inde n'a jamais, d'une manière organisée, dressé des plans pour la prospection du pétrole. Or, à l'heure actuelle, elle doit faire face au double problème de trouver des réserves suffisantes pour satisfaire aux besoins éventuels de ses divers secteurs économiques, et en même temps remédier au déséquilibre croissant entre la production et la consommation des produits essentiels tels que l'essence et les distillats moyens. L'effort du pays porte donc zur la prospection continue du pétrole, sur un meilleur rendement des raffineries, sur le développement par la recherche de techniques poussées de raffinage s'adaptant aux ressources et à la demande, enfin sur une coordination plus grande dans l'étude des problèmes de l'énergie. PART I K. K. SAHNI 3Y Introduction The scope of this paper is to present a brief outline, firstly, to illustrate the existing pattern of energy consumption in India; secondly, to assess the energy requirements of the country in the foreseeable future so that for all fuels, long term planning and investment can be undertaken and the co
- Materials > Metals & Mining > Coal (1.00)
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- Energy > Power Industry > Utilities > Nuclear (0.46)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.46)
- Asia > India > West Bengal > West Bengal Basin (0.99)
- Asia > India > Assam > Upper Assam Basin > Digboi Field > Nahor Oil Sand (0.99)
- Asia > India > Assam > Upper Assam Basin > Digboi Field > Digboi Oil Sand Group (0.99)
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