Application of Hydraulic Fracturing Candidate Selection Leading to Oil Production Boost from Multi-Layered, Low-Permeability Reservoirs: A Successful Case Study in Thailand

2021 ◽  
Author(s):  
Marut Wantawin ◽  
Thum Sirirattanachatchawan ◽  
Theerapat Suppachokinirun ◽  
Kittithuch Hnuruang ◽  
Sorawee Rongdechprateep ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Success Rate ◽  
Oil Production ◽  
Candidate Selection ◽  
Production Performance ◽  
High Rate ◽  
Hydraulic Fractures ◽  
Low Permeability ◽  
Selection Methodology ◽  
Low Permeability Reservoirs

Abstract Hydraulic fracturing activities implemented in Sirikit onshore oilfield of Thailand over a decade. Before 2018, the variation in post-fracturing production performance resulted in about 50% stimulation success rate. This outcome posted a big challenge to maintain project momentum. Hence, the candidate selection methodology was developed in-house which recommends "suitable" reservoirs. Using selection criteria, the multi-layered, low permeability reservoirs were selected for the 2018-19 Hydraulic Fracturing Campaign. Production analysis was conducted using the information gathered from past hydraulic fracturing campaigns. Reservoir Index (RI) was invented to distinguish the subsurface quality by formation permeability, thickness, pressure, and fluid properties. Together with the Fold of Increase (FOI) owing to hydraulic fracturing, a performance-based relationship was created which can categorize suitable reservoirs based on their RI ranges. This method has been applied to newly drilled wells during 2018. In the end, there were 13 wells selected to perform 28 hydraulic fracturing stages. The 2018-2019 Hydraulic Fracturing Campaign at Sirikit Oilfield was planned and executed. Post-fracturing production tests showing significant improvement. Some wells resulted in excellent oil production rate naturally, while some maintained high rate by artificial lift. According to post-campaign analysis, hydraulic fractures were proved to connect multiple layers of satisfactory flow capacity. In addition, well angle and stress direction accommodated the placement and orientation of multiple hydraulic fractures. As a result, the number of hydraulic fracturing stages that achieved economic production tests improved to 75% success rate. Hydraulic fracturing results from the past were fully utilized in order to achieve sustainable production improvement, thus driving continuous stimulation activities in the future. The candidate selection methodology has shaped up a candidate selection workflow that pointed out success criteria and avoided those that may lead to failure, which proved to be successful in one of the most complex fields in Thailand.

scholarly journals The efficiency of gas injection into low-permeability multilayer hydrocarbon reservoirs

2021 ◽  
Vol 3 (10) ◽  
pp. 100-108
Author(s):  
Sudad H AL-Obaidi ◽  
Miel Hofmann ◽  
Falah H. Khalaf ◽  
Hiba H. Alwan
Keyword(s):  
Hydraulic Fracturing ◽  
Oil Recovery ◽  
Gas Injection ◽  
Oil Production ◽  
Recovery Factor ◽  
Low Permeability ◽  
Compositional Model ◽  
Multistage Hydraulic Fracturing ◽  
Low Permeability Reservoirs ◽  
Working Agent

The efficiency of gas injection for developing terrigenous deposits within a multilayer producing object is investigated in this article. According to the results of measurements of the 3D hydrodynamic compositional model, an assessment of the oil recovery factor was made. In the studied conditions, re-injection of the associated gas was found to be the most technologically efficient working agent. The factors contributing to the inefficacy of traditional methods of stimulating oil production such as multistage hydraulic fracturing when used to develop low-permeability reservoirs have been analyzed. The factors contributing to the inefficiency of traditional oil-production stimulation methods, such as multistage hydraulic fracturing, have been analysed when they are applied to low-permeability reservoirs. The use of a gas of various compositions is found to be more effective as a working agent for reservoirs with permeability less than 0.005 µm2. Ultimately, the selection of an agent for injection into the reservoir should be driven by the criteria that allow assessing the applicability of the method under specific geological and physical conditions. In multilayer production objects, gas injection efficiency is influenced by a number of factors, in addition to displacement, including the ratio of gas volumes, the degree to which pressure is maintained in each reservoir, as well as how the well is operated. With the increase in production rate from 60 to 90 m3 / day during the re-injection of produced hydrocarbon gas, this study found that the oil recovery factor increased from 0.190 to 0.229. The further increase in flow rate to 150 m3 / day, however, led to a faster gas breakthrough, a decrease in the amount of oil produced, and a decrease in the oil recovery factor to 0.19 Based on the results of the research, methods for stimulating the formation of low-permeability reservoirs were ranked based on their efficacy.

scholarly journals The efficiency of gas injection into low-permeability multilayer hydrocarbon reservoirs

2021 ◽  
Author(s):  
Sudad H Al-Obaidi ◽  
Hofmann M ◽  
Khalaf FH ◽  
Hiba H Alwan
Keyword(s):  
Hydraulic Fracturing ◽  
Oil Recovery ◽  
Gas Injection ◽  
Oil Production ◽  
Recovery Factor ◽  
Low Permeability ◽  
Compositional Model ◽  
Multistage Hydraulic Fracturing ◽  
Low Permeability Reservoirs ◽  
Working Agent

The efficiency of gas injection for developing terrigenous deposits within a multilayer producing object is investigated in this article. According to the results of measurements of the 3D hydrodynamic compositional model, an assessment of the oil recovery factor was made. In the studied conditions, re-injection of the associated gas was found to be the most technologically efficient working agent. The factors contributing to the inefficacy of traditional methods of stimulating oil production such as multistage hydraulic fracturing when used to develop low-permeability reservoirs have been analysed. The factors contributing to the inefficiency of traditional oil-production stimulation methods, such as multistage hydraulic fracturing, have been analysed when they are applied to low-permeability reservoirs. The use of a gas of various compositions is found to be more effective as a working agent for reservoirs with permeability less than 0.005 μm2. Ultimately, the selection of an agent for injection into the reservoir should be driven by the criteria that allow assessing the applicability of the method under specific geological and physical conditions. In multilayer production objects, gas injection efficiency is influenced by a number of factors, in addition to displacement, including the ratio of gas volumes, the degree to which pressure is maintained in each reservoir, as well as how the well is operated. With the increase in production rate from 60 to 90 m3 / day during the re-injection of produced hydrocarbon gas, this study found that the oil recovery factor increased from 0.190 to 0.229. The further increase in flow rate to 150 m3 / day, however, led to a faster gas breakthrough, a decrease in the amount of oil produced, and a decrease in the oil recovery factor to 0.19. Based on the results of the research, methods for stimulating the formation of low-permeability reservoirs were ranked based on their efficacy.

Experience in Optimizing the Location and Parameters of Multistage Hydraulic Fractures for a Multilateral Well Based on Reservoir Simulation

2021 ◽  
Author(s):  
Vil Syrtlanov ◽  
Yury Golovatskiy ◽  
Konstantin Chistikov ◽  
Dmitriy Bormashov
Keyword(s):  
Hydraulic Fracturing ◽  
Reservoir Simulation ◽  
Optimal Placement ◽  
Hydraulic Fractures ◽  
Low Permeability ◽  
Advantages And Disadvantages ◽  
Modeling Methods ◽  
Multistage Hydraulic Fracturing ◽  
Determination Of Parameters

Abstract This work presents the approaches used for the optimal placement and determination of parameters of hydraulic fractures in horizontal and multilateral wells in a low-permeability reservoir using various methods, including 3D modeling. The results of the production rate of a multilateral dualwellbore well are analyzed after the actual hydraulic fracturing performed on the basis of calculations. The advantages and disadvantages of modeling methods are evaluated, recommendations are given to improve the reliability of calculations for models with hydraulic fracturing (HF)/ multistage hydraulic fracturing (MHF).

Geologic Controls on Gas Production and Hydraulic-Fracturing Flowback in Tight Gas Sandstones of the Late Jurassic Monteith Formation, Deep Basin, Alberta, Canada

2016 ◽  
Vol 19 (01) ◽  
pp. 024-040 ◽  
Author(s):  
Liliana Zambrano ◽  
Per K. Pedersen ◽  
Roberto Aguilera
Keyword(s):  
Hydraulic Fracturing ◽  
Gas Production ◽  
Production Performance ◽  
Rock Properties ◽  
Hydraulic Fractures ◽  
Tight Gas ◽  
Deep Basin ◽  
Rock Types ◽  
Sandstone Reservoirs ◽  
Geologic Controls

Summary A comparison of rock properties integrated with production performance and hydraulic-fracturing flowback (FB) of the uppermost lithostratigraphic “Monteith A” and the lowermost portion “Monteith C” of the Monteith Formation in the Western Canada Sedimentary Basin (WCSB) in Alberta is carried out with the use of existing producing gas wells. The analyses are targeted to understand the major geologic controls that differentiate the two tight gas sandstone reservoirs. This study consists of basic analytical tools available for geological characterization of tight gas reservoirs that is based on the identification and comparison of different rock types such as depositional, petrographic, and hydraulic for each lithostratigraphic unit of the Monteith Formation. As these low-matrix-permeability sandstone reservoirs were subjected to intense post-depositional diagenesis, a comparison of the various rock types allows the generation of more-accurate reservoir description, and a better understanding of the key geologic characteristics that control gas-production potential and possible impact on hydraulic-fracturing FB. Well performance and FB were the focus of many previous simulation and geochemical studies. In contrast, we find that an adequate understanding of the rocks hosting hydraulic fractures is a necessary complement to those studies for estimating FB times. This understanding was lacking in some previous studies. As a result, a new method is proposed on the basis of a crossplot of cumulative gas production vs. square root of time for estimating FB time. It is concluded that the “Monteith A” unit has better rock quality than the “Monteith C” unit because of less-heterogeneous reservoir geometry, less-complex mineralogical composition, and larger pore-throat apertures.

Low-Damage Hydraulic Fracturing Design Technique to Exploration Wells of Erlian Basin in China

2013 ◽  
Vol 753-755 ◽  
pp. 48-52
Author(s):  
Bo Cai ◽  
Yun Hong Ding ◽  
Yuan Peng Shi ◽  
Yong Jun Lu
Keyword(s):  
Hydraulic Fracturing ◽  
Field Application ◽  
Oil Fields ◽  
Low Permeability ◽  
Consumer Market ◽  
Damage Degree ◽  
Potential Part ◽  
Fracture Damage ◽  
Low Permeability Reservoirs ◽  
Erlian Basin

In China,more and more low permeability reservoirs have become the mainly oil production potential part for the soaring consumer market. Hydraulic fracturing treatment has always been playing an important role in these low permeability reservoirs.however,some inappropricate fracturing designs and treatments may decrease the productions as a result of high damage within both formations and artifical fractures.In order to minimize reduce formation and fracture damage, we take the wells in Erlian Basin as an example to explain the low-damage hydraulic fracturing technique which had been used in many of oil fields .Through eight years step by step study and field application, a comprehensive industrialize design technology was put forward. By the application of this technique, the low-damage degree is highlighted compared to the past.As a result the performance of post-fracturing wells have remarkably improved.

Fracturing in low-permeability soils for remediation of contaminated ground

2001 ◽  
Vol 38 (2) ◽  
pp. 316-327 ◽  
Author(s):  
Ron CK Wong ◽  
Marolo C Alfaro
Keyword(s):  
Electrical Resistivity ◽  
Hydraulic Fracturing ◽  
Electrical Resistivity Tomography ◽  
Soil Formation ◽  
Test Facility ◽  
Hydraulic Fractures ◽  
Low Permeability ◽  
Resistivity Tomography ◽  
Vertical Well ◽  
Actual Fracture

This paper presents a field study on hydraulic fracturing for in situ remediation of contaminated ground. Sand-propped hydraulic fractures were placed from vertical and horizontal wells at a test facility. Field excavations were conducted to expose the fractures and inspect their distribution and geometry. Fractures that were mapped by field excavation were found to be near horizontal, implying that the soil formation is overconsolidated. It was also observed that the sand "proppant" was thicker at locations where the soil layers were relatively weak or contained weak fissures. Electrical resistivity tomography (ERT) was also conducted in an attempt to map the fractures. There was no indication that fractures were being mapped by this geophysical technique. Fracture mapping based on tiltmeter data analyses conformed closely with the actual fracture placement in the vertical well but did not properly predict the actual fracture placement in the horizontal well.Key words: hydraulic fracturing, field test, low-permeability soil, electrical resistivity tomography, tiltmeters, horizontal well, vertical well.

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