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Search Results for Produced water formation volume factor
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Produced water formation volume factor
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE Reservoir Characterisation and Simulation Conference and Exhibition, January 24–26, 2023
Paper Number: SPE-212619-MS
... and 2D visible microscopic test, and long-tube physical simulation of huff-n-puff process, confirmed that gas-condensate could dissolve into oil, resulting in foamy oil with formation volume factor of 1.23 and viscosity reduction of 50% of initial value. In-situ huff and puff process. Single tubing...
Paper presented at the SPE Annual Technical Conference and Exhibition, September 30–October 2, 2019
Paper Number: SPE-196122-MS
... formation volume factor B w – produced water formation volume factor B oi – initial oil formation volume factor B gi – initial produced gas formation volume factor B wi – initial produced water formation volume factor B ginj – injected gas formation volume factor (15...
Publisher: American Rock Mechanics Association
Paper presented at the 48th U.S. Rock Mechanics/Geomechanics Symposium, June 1–4, 2014
Paper Number: ARMA-2014-7758
... Upstream Oil & Gas flow rate skin factor hydraulic fracture hydraulic fracturing drillstem/well testing Formation Permeability injection time fracture water disposal injection well water injection rate dependent skin equation injection permeability 1 1. INTRODUCTION Produced water...
Publisher: Offshore Technology Conference
Paper presented at the Offshore Technology Conference Asia, March 22–25, 2022
Paper Number: OTC-31624-MS
... statistical information from produced masses of two distinctively partitioning tracers, which follows a rigorous mathematical derivation and setup a volume factor equation relating to produced masses of two partitioning tracers. The partitioning coefficient is also modified by a dynamic factor to better...
Paper presented at the SPE International Conference and Exhibition on Health, Safety, Environment, and Sustainability, July 27–30, 2020
Paper Number: SPE-199498-MS
... of the magnitude of the produced water volumes generated in each case. Produced Water Constituents The composition of produced water varies considerably depending on a number of factors, such as the geographic location of the oil and gas field, the geologic formation producing the water, and the process...
Paper presented at the Production and Operations Symposium, March 31–April 3, 2007
Paper Number: SPE-106233-MS
... water production rate is only the volume ration of produced water to injected steam, how much formation water (bottom/edge water) is produced can not be known from this parameter. Through studying production data of thermal recovery in Liaohe oilfield, we discovered that the produced part of injected...
Alexey Viktorovich Kornilov, Ivan Vasilievich Tkachev, Artem Vacheevich Fomkin, Andrey Mikhailovich Petrakov, Denis Radikovich Batrshin, Grigory Aleksandrovich Fursov, Denis Mikhailovich Ponomarenko, Gennadiy Dmitrievich Fedorchenko, Geroge Vladimirovih Sansiev
Paper presented at the SPE Russian Petroleum Technology Conference, October 12–15, 2021
Paper Number: SPE-206433-MS
...), mixed or hydrophobic wettability, risks of quick channeling of injected water from injectors to producers as well as salinity of formation water and formation temperature. Also enhanced oil recovery methods can be used as an additional method to optimize the reservoir coverage and decrease the water cut...
Paper presented at the SPE International Conference on Oilfield Chemistry, December 6–7, 2021
Paper Number: SPE-204368-MS
...-fouling performance of the surfactants and surfactant/chelating agent formulations in the lab testing. The efficiency factor is defined as the ratio of the total filtrate volume of the treated produced water divided by the total filtrate volume of the untreated produced water. This efficiency factor...
Paper presented at the SPE Europec featured at 79th EAGE Conference and Exhibition, June 12–15, 2017
Paper Number: SPE-185818-MS
... observed that the water injection is balanced, tending to be slightly higher than the total fluid rate produced in the last 5 years. The recovery factor is 7.5% with a pore volume injected of 0.34. This shows a slow injection rate, with a low recovery factor. At the pattern level, many of them...
Paper presented at the SPE Eastern Regional Meeting, October 4–6, 2017
Paper Number: SPE-187522-MS
... Abstract Management of produced water from conventional plays and shale and tight oil and gas plays is driving subtle yet potentially consequential changes in certain regions and Underground Injection Control (UIC) formations. UIC operation topics of interest include induced seismicity (from...
Paper presented at the SPE Eastern Regional Meeting, August 17–19, 2011
Paper Number: SPE-148717-MS
..., gas specific gravity, water specific gravity, oil formation volume factor, gas formation volume factor, and solution gas oil ratio are assigned with values often found in real oil fields. Table 1 illustrates the parameters used in the simulation model. Data in Table 1 are also used as the input...
Paper presented at the SPE Nigeria Annual International Conference and Exhibition, August 2–4, 2021
Paper Number: SPE-207110-MS
..., but the challenge is that the parameters that contribute to HIIP estimations change with time and become difficult to readily quantify. Parameters such as water saturation, formation volume factor, area, thickness, and reservoir fluid contacts may change significantly. Water saturation is most difficult to quantify...
Paper presented at the SPE Russian Petroleum Technology Conference, October 12–15, 2021
Paper Number: SPE-206645-MS
... of a well, m kz/kx anisotropy coefficient, dim. WCT water cut, dim μ w water viscosity, Pa×sec μ o oil viscosity, Pa×sec B o formation volume factor for oil, m 3 /m 3 B w formation volume factor for water, m 3 /m 3 K cover fraction...
Paper presented at the SPE Annual Technical Conference and Exhibition, November 11–14, 2007
Paper Number: SPE-109965-MS
... ) = C t where B o is the oil formation volume factor. Because the formation volume factor for water is essentially unity, the produced water volume is assumed to be equal to the reservoir water volume. Water records obtained from the WOGCC for the Czapanskiy A-4 well within the Moran...
Paper presented at the SPE International Oilfield Scale Conference and Exhibition, June 24–25, 2020
Paper Number: SPE-200701-MS
... is controlled by the factors outlined above and time is not one of these factors. While time (number of days/months) is a typical operation requirement for a squeeze treatment to be effective over it is cumulative produced water volume over that time period that is the value that a squeeze is designed to meet...
Paper presented at the SPE International Oilfield Scale Conference and Exhibition, May 25–26, 2022
Paper Number: SPE-209487-MS
... to a currently producing platform facility and the wells were to be completed via dual ESP due to constraints on the volume of gas lift gas available. The field produced formation water only and the platform wells had been producing for a number of years with no significant calcium carbonate issues experienced...
Paper presented at the International Petroleum Technology Conference, March 26–28, 2019
Paper Number: IPTC-19102-MS
... of reservoir liquid: oil and water viscosity, density, volume factor, compressibility. 4 IPTC-19102-MS Dynamic producing history: oil and water producing rate, water injecting rate, cumulative oil and water production, cumulative water injection, production decline. Fracturing process: injecting volume...
Paper presented at the SPE/AAPG/SEG Unconventional Resources Technology Conference, July 26–28, 2021
Paper Number: URTEC-2021-5993-MS
... urtec 5993 frac water basin formation water turner powder river basin composition unconventional resource technology conference Abstract Objectives/Scope: Increasing focus has been directed towards value that can be derived from the analysis of produced water from unconventional wells...
Paper presented at the SPE Nigeria Annual International Conference and Exhibition, August 2–4, 2016
Paper Number: SPE-184239-MS
... Abstract One major factor that triggers fines migration in formations during hydrocarbon production especially in the presence of water is high flow rates. Low flow rates have been recommended to prevent fines mobilization but this solution is not always practical because there is a critical...
Paper presented at the SPE Enhanced Oil Recovery Conference, July 19–20, 2011
Paper Number: SPE-144908-MS
... rate allocation factor injection enhanced recovery injector formation pressure spe 144908 waterflooding bubble point pressure recovery factor streamline simulation horizontal injector producer production rate water injection reservoir vertical well Introduction Block B...
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