Technologies for the development of the Achimov deposits

Минич, А. А.; Timirgalin, Azamat; Butorina, M.G.; Oshmarin, Roman; Kondratiev, Artem; Mukminov, Iskander; Volkov, Georgy

doi:10.24887/0028-2448-2018-12-30-33

Cited by 2 publications

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“…Reservoirs with permeability less than 0.010 µm 2 have actual oil recovery factors in the range of 0.014 to 0.235, with an average value of 0.138. In general, with a water cut of about 80%, the withdrawal of initial recoverable reserve is not more than 35-40% of its calculated value [18][19][20][21]. With such ratios of water cut and oil recovery, it can be argued that with the existing development system based on water injection, the calculated values of oil recovery factors are overestimated and will not be achieved [22][23][24].…”

Section: Inefficiency Of Using Traditional Pressure Maintenance Methods In the Development Of Low Permeability Reservoirsmentioning

confidence: 99%

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

Al-Obaidi¹,

Hofmann²,

FH³

et al. 2021

Preprint

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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.

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Section: Inefficiency Of Using Traditional Pressure Maintenance Methods In the Development Of Low Permeability Reservoirsmentioning

confidence: 99%

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

Al-Obaidi¹,

Hofmann²,

FH³

et al. 2021

Preprint

View full text Add to dashboard Cite

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Comprehensive Studies of Formation Water for Achimov and Bazhenov Formations — Revitalizing Archived and Old Cores

Kazak

2021

All Days

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The sediments of Bazhenov (BF) and Achimov (ACh) formations have been studied for more than 50 years, and to date, a large amount of core material obtained during drilling at the stage of exploration is stored in the core stores of Russian industrial companies. The rise in the cost of the complex of geological exploration and the emergence of new research methods enabled studies of the old/dry core from previously drilled exploration wells. BF and ACh reservoir rocks have low permeability and initially low water saturation, and therefore, during storage, rock samples could partially retain pore water. To study its composition and quantitative content, we used the previously proposed integrated approach with proven effectiveness in fresh low-permeability BF rocks. The studied materials include BF rock samples from 3 different fields stored for 2 years after sampling in the laboratory, and ACh rock samples from 12 fields, cored more than 10 years ago at the geologic exploration stage. The complex technique includes determining free and bound water contents by the evaporation method with isotopic analysis (δ18O and δD) of the released water. The modified water extraction method provides a range of pore water salinity, while the modified alcohol ammonium chloride method measures the cation exchange capacity (CEC). Auxilary methods include Rock-Eval pyrolysis to determine organic matter content, X-ray diffraction analysis (XRD) to assess the mineral composition of sediments. The verification of the results for the BF rock samples was carried out according to the data obtained for the new/fresh core, while for the ACh rock samples — according to the results of the direct chemical composition analysis of the formation water. Despite the low permeability, we found that the BF and ACh rock samples during storage lost almost all (up to 90%) free water due to evaporation. At the same time, salts from formation water remained in the pore space, which made it possible to estimate the range of its NaCl salinity: 1.84–14.7 g/L for ACh rock samples and 4.49–20.19 g/L for BF rock samples. The obtained values set the lower limit of the possible pore water salinity of the studied ACh and BF rock samples. Moreover, the results match those from direct salinity measurements in the ACh depth intervals and the results of fresh BF core laboratory studies. We showed that the old/dry BF and ACh core could be effectively used to assess the bound water content with subsequent determination of its genesis from isotopic composition data and CEC measurements. This opportunity relies on the high clay content in the studied BF and ACh rock samples. The obtained results show the fundamental capability of informative laboratory studies of BF and ACh rock samples from public and private core storage facilities and give new life to archived and old/dry core.

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Technologies for the development of the Achimov deposits

Cited by 2 publications

References 0 publications

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

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

Comprehensive Studies of Formation Water for Achimov and Bazhenov Formations — Revitalizing Archived and Old Cores

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