The Study and Application of Massive Hydraulic Fracturing Technique in Y104-6 Well Glutenite Formation

2013 ◽  
Vol 734-737 ◽  
pp. 1498-1502
Author(s):  
Cong Lu ◽  
Jian Chun Guo ◽  
Ren Jiang Xue ◽  
Jian Wang
Keyword(s):  
Hydraulic Fracturing ◽  
Economic Benefit ◽  
Material Selection ◽  
Oil Production ◽  
Thick Section ◽  
Geological Characteristics ◽  
Recoverable Reserves ◽  
Reservoir Development

Aiming at the southern areas of Bohai glutenite reservoir natural capacity is low, without obvious interlayer, filter lost badly, cause conventional hydraulic facturing in short of effect on increasing production, the paper conducted the research and application of technology on Y104-6 well. According to the reservoir geological characteristics and well conditions, the paper studied on fracturing scale determination, the perforating section, and the optimization of fracturing material selection, and application. Completed the injection into well fluid amount 1491.9 m3, proppant 188 m3, displacement of pump 7.5 m3/min. After treatment, average fluid flowing production achieved 18.6 t/d, average daily oil production 6.8 t, stimulate effect and the economic benefit is remarkable. This well fracturing technology, make the successful application of the southern areas of Bohai glutenite reservoir a significant breakthrough, recoverable reserves get promoted for big thick section glutenite reservoir development and vertical fracturing of the organization and implementation has provided valuable experience.

scholarly journals Derivation of water flooding characteristic curve for offshore low-amplitude structural reservoir with strong bottom water

2021 ◽  
Author(s):  
Ying-xian Liu ◽  
Jie Tan ◽  
Hui Cai ◽  
Yan-lai Li ◽  
Chun-yan Liu
Keyword(s):  
Bottom Water ◽  
Characteristic Curve ◽  
Calculated Data ◽  
Oil Production ◽  
Water Flooding ◽  
Characteristic Curves ◽  
Recoverable Reserves ◽  
Curve Method ◽  
Water Cut ◽  
Low Amplitude

AbstractThe water flooding characteristic curve method is one of the essential techniques to predict recoverable reserves. However, the recoverable reserves indicated by the existing water flooding characteristic curves of low-amplitude reservoirs with strong bottom water increase gradually, and the current local recovery degree of some areas has exceeded the predicted recovery rate. The applicability of the existing water flooding characteristic curves in low-amplitude reservoirs with strong bottom water is lacking, which affects the accurate prediction of development performance. By analyzing the derivation process of the conventional water flooding characteristic curve method, this manuscript finds out the reasons for the poor applicability of the existing water flooding characteristic curve in low-amplitude reservoir with strong bottom water and corrects the existing water flooding characteristic curve according to the actual situation of the oilfield and obtains the improvement method of water flooding characteristic curve in low-amplitude reservoir with strong bottom water. After correction, the correlation coefficient between $$\frac{{k_{ro} }}{{k_{rw} }}$$ k ro k rw and $$S_{w}$$ S w is 95.92%. According to the comparison between the actual data and the calculated data, in 2021/3, the actual water cut is 97.29%, the water cut predicted by the formula is 97.27%, the actual cumulative oil production is 31.19 × 104t, and the predicted cumulative oil production is 31.31 × 104t. The predicted value is consistent with the actual value. It provides a more reliable method for predicting low-amplitude reservoirs' recoverable ability with strong bottom water and guides the oilfield's subsequent decision-making.

Increasing the Productivity of Horizontal Wells Through Multistage Hydraulic Fracturing Using a Working Fluid Based on a New Biopolymer System

2021 ◽  
Author(s):  
Nikolay Mikhaylovich Migunov ◽  
Aleksey Dmitrievich Alekseev ◽  
Dinar Farvarovich Bukharov ◽  
Vadim Alexeevich Kuznetsov ◽  
Aleksandr Yuryevich Milkov ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Russian Federation ◽  
Oil Production ◽  
Horizontal Wells ◽  
Working Fluid ◽  
High Tech ◽  
Executive Order ◽  
Bazhenov Formation ◽  
Multistage Hydraulic Fracturing ◽  
The Russian Federation

Abstract According to the US Energy Agency (EIA), Russia is the world leader in terms of the volume of technically recoverable "tight oil" resources (U.S. Department of Energy, 2013). To convert them into commercial production, it is necessary to create cost-effective development technologies. For this purpose, a strategy has been adopted, which is implemented at the state level and one of the key elements of which is the development of the high-tech service market. In 2017, the Minister of Energy of the Russian Federation, in accordance with a government executive order (Government Executive Order of the Russian Federation, 2014), awarded the Gazprom Neft project on the creation of a complex of domestic technologies and high-tech equipment for developing the Bazhenov formation with the national status. It is implemented in several directions and covers a wide range of technologies required for the horizontal wells drilling and stimulating flows from them using multi-stage hydraulic fracturing (MS HF) methods. Within the framework of the technological experiment implemented at the Palyanovskaya area at the Krasnoleninskoye field by the Industrial Integration Center "Gazpromneft - Technological Partnerships" (a subsidiary of Gazprom Neft), from 2015 to 2020, 29 high-tech wells with different lengths of horizontal wellbore were constructed, and multistage hydraulic fracturing operations were performed with various designs. Upon results of 2020, it became possible to increase annual oil production from the Bazhenov formation by 78 % in comparison with up to 100,000 tons in 2019. The advancing of development technologies allowed the enterprise to decrease for more than twice the cost of the Bazhenov oil production from 30 thousand rubles per ton (69$/bbl) at the start of the project in 2015 to 13 thousand rubles (24$/bbl) in 2020. A significant contribution to the increase in production in 2020 was made by horizontal wells, where MS HF operations were carried out using an experimental process fluid, which is based on the modified Si Bioxan biopolymer. This article is devoted to the background of this experiment and the analysis of its results.

Experimental Investigation on Enhanced-Oil-Recovery Mechanisms of Using Supercritical Carbon Dioxide as Prefracturing Energized Fluid in Tight Oil Reservoir

SPE Journal ◽  
2021 ◽  
pp. 1-16
Author(s):  
Lei Li ◽  
Zheng Chen ◽  
Yu-Liang Su ◽  
Li-Yao Fan ◽  
Mei-Rong Tang ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Water Resources ◽  
Supercritical Carbon Dioxide ◽  
Hydraulic Fracturing ◽  
Clay Minerals ◽  
Oil Production ◽  
Tight Oil ◽  
Injection Mode ◽  
Oil Development ◽  
Live Oil

Summary Fracturing is the necessary means of tight oil development, and the most common fracturing fluid is slickwater. However, the Loess Plateau of the Ordos Basin in China is seriously short of water resources. Therefore, the tight oil development in this area by hydraulic fracturing is extremely costly and environmentally unfriendly. In this paper, a new method using supercritical carbon dioxide (CO2) (ScCO2) as the prefracturing energized fluid is applied in hydraulic fracturing. This method can give full play to the dual advantages of ScCO2 characteristics and mixed-water fracturing technology while saving water resources at the same time. On the other hand, this method can reduce reservoir damage, change rock microstructure, and significantly increase oil production, which is a development method with broad application potential. In this work, the main mechanism, the system-energy enhancement, and flowback efficiency of ScCO2 as the prefracturing energized fluid were investigated. First, the microscopic mechanism of ScCO2 was studied, and the effects of ScCO2 on pores and rock minerals were analyzed by nuclear-magnetic-resonance (NMR) test, X-ray-diffraction (XRD) analysis, and scanning-electron-microscope (SEM) experiments. Second, the high-pressurechamber-reaction experiment was conducted to study the interaction mechanism between ScCO2 and live oil under formation conditions, and quantitively describe the change of high-pressure physical properties of live oil after ScCO2 injection. Then, the numerical-simulation method was applied to analyze the distribution and existence state of ScCO2, as well as the changes of live-oil density, viscosity, and composition in different stages during the full-cycle fracturing process. Finally, four injection modes of ScCO2-injection core-laboratory experiments were designed to compare the performance of ScCO2 and slickwater in terms of energy enhancement and flowback efficiency, then optimize the optimal CO2-injection mode and the optimal injection amount of CO2slug. The results show that ScCO2 can dissolve calcite and clay minerals (illite and chlorite) to generate pores with sizes in the range of 0.1 to 10 µm, which is the main reason for the porosity and permeability increases. Besides, the generated secondary clay minerals and dispersion of previously cemented rock particles will block the pores. ScCO2 injection increases the saturation pressure, expansion coefficient, volume coefficient, density, and compressibility of crude oil, which are the main mechanisms of energy increase and oil-production enhancement. After analyzing the four different injection-mode tests, the optimal one is to first inject CO2 and then inject slickwater. The CO2 slug has the optimal value, which is 0.5 pore volume (PV) in this paper. In this paper, the main mechanisms of using ScCO2 as the prefracturing energized fluid are illuminated. Experimental studies have proved the pressure increase, production enhancement, and flowback potential of CO2 prefracturing. The application of this method is of great significance to the protection of water resources and the improvement of the fracturing effect.

scholarly journals Potential Use of Water Associated with Conventional Oil Production and Sea Water as Base Fluids for Hydraulic Fracturing Operations: Effect of Water Chemistry on Crosslinking and Breaking Behaviors of Guar Gum-Based Fracturing Fluid Formulations

2016 ◽  
Vol 6 (1) ◽  
pp. 31 ◽  
Author(s):  
Dayanand Saini ◽  
Timea Mezei
Keyword(s):  
Los Angeles ◽  
Hydraulic Fracturing ◽  
Water Chemistry ◽  
Fresh Water ◽  
Oil And Gas ◽  
Guar Gum ◽  
Sea Water ◽  
Oil Production ◽  
Fracturing Fluid ◽  
Conventional Oil

 Even though water consumption per hydraulic fracturing (or fracturing) job is relatively low; nearly all of the fresh water used for fracturing in California is in the regions of high water stress such as San Jouquin and Los Angeles Basins. However, water availability should not be a concern as huge volumes of water are being produced along with oil and gas from conventional formations (i.e. associated water) in the Kern County of California, a region where most of the fracturing activities take place. This associated water can potentially be used for preparing fracturing fluids in stimulating the unconventional formations. The present study reports on the relevant investigation done in this area of interest.The results suggest that associated water chemistry has limited effect on the viscosity of cross-linked formulations. However, guar gum concentration was found to affect the breaking behaviors of cross-linked fracturing fluid formulations. The new type of commercially available biodegradable breaker was found to be effective in breaking the tested cross-linked formulations at elevated temperature which was as high as 85°C (185°F). Both crosslinking and breaking behaviors of fracturing fluid formulations evaluated in this study were found comparable to the behaviors of commonly used cross-linked formulation (guar gum + 2% potassium chloride). These results suggest that both the associated water (i.e. water resulting from regional conventional oil production activites) and sea water (offshore oil fields) could serve as alternative sources of base fluid for use in fracturing jobs without putting significant burden on precious regional fresh water resources.

scholarly journals Identifying chemicals of concern in hydraulic fracturing fluids used for oil production

2017 ◽  
Vol 220 ◽  
pp. 413-420 ◽  
Author(s):  
William T. Stringfellow ◽  
Mary Kay Camarillo ◽  
Jeremy K. Domen ◽  
Whitney L. Sandelin ◽  
Charuleka Varadharajan ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Oil Production ◽  
Fracturing Fluids

Optimized Hydraulic Fracturing Improves Oil Production in the N'Dola Field, Offshore Angola

1998 ◽  
Author(s):  
John M. Bagzis ◽  
C. Dean Wehunt ◽  
Edward B. Neubauer ◽  
Raymond P. Jansson ◽  
Richard Tjoonk ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Oil Production

Tailored Workflow for Optimizing the Hydraulic Fracturing in Tight Reservoir Development: A Case Study from Cambay Basin

2019 ◽  
Author(s):  
Vivek Pandey ◽  
Sunil Kumar Dimri ◽  
Dinesh Kumar Mathur ◽  
Raman Kumar Singh ◽  
Ankit Dutt ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Cambay Basin ◽  
Reservoir Development ◽  
Tight Reservoir

The South Brae Field, Block 16/7a, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 55-62 ◽  
Author(s):  
Martin J. Roberts
Keyword(s):  
North Sea ◽  
Oil Production ◽  
Upper Jurassic ◽  
The Other ◽  
Field Margins ◽  
The South ◽  
Western Margin ◽  
Recoverable Reserves ◽  
Clay Formation ◽  
Devonian Age

AbstractSouth Brae Oilfield lies at the western margin of the South Viking Graben, 161 miles northeast of Aberdeen. Oil production began in July 1983 from a single platform located in 368 ft of water. The field originally contained 312 MMBBL of recoverable reserves, and in May 1990, cumulative exports of oil and NGL reached 219 MMBBL. The reservoir lies at depths in excess of 11800 ft TVSS, has a maximum gross hydrocarbon column of 1670 ft, and covers an area of approximately 6000 acres.The reservoir is the Upper Jurassic Brae Formation which is downfaulted against tight sealing rocks of probable Devonian age at the western margin of the field. The other field margins are constrained by a combination of structural dip and stratigraphic pinchout.The reservoir is capped by the Kimmeridge Clay Formation, which is also the source of the oil.

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