Reconstruction of the Initial State of a Gas-Condensate System Based on a Limited Set of Field Data; A Case Study of One of the Fields in South Caspian Basin

2017 ◽  
Author(s):  
Olenchikov Dmitry ◽  
Semenov Alexander
Keyword(s):  
Field Data ◽  
Gas Condensate ◽  
Caspian Basin ◽  
South Caspian Basin ◽  
Initial State ◽  
Condensate System

scholarly journals Dynamics of hydrocarbon production in long-developed fields of the South Caspian basin with emphasis on reserves renewability

2021 ◽  
Vol 11 (3) ◽  
pp. 1081-1091
Author(s):  
A. A. Feyzullayev ◽  
I. Lerche ◽  
I. M. Mamedova ◽  
A. G. Gojayev
Keyword(s):  
Oil And Gas ◽  
Methodological Approach ◽  
Gas Production ◽  
Oil Field ◽  
Gas Condensate ◽  
Caspian Basin ◽  
The South ◽  
South Caspian Basin ◽  
Hydrocarbon Production ◽  
Field Development

AbstractThe scientific basis of the paper is the concept of renewability of oil and gas resources. In accordance with this concept, the purpose of this paper is to estimate the volumetric rate of natural replenishment of the reservoir with oil and gas using the example of long-developed Bibieybat oil and Garadag gas condensate fields in the South Caspian Basin (SCB). The methodological approach of this assessment is based on the authors' assumption that at the late stage of field development, the recoverable amount of hydrocarbon fluids is compensated by the amount of their natural inflow, as a result of which oil or gas production stabilizes. The analysis of the dynamics of hydrocarbon production for the Bibieybat oil field covered the period from 1935 to 2018, and for the Garadag gas condensate field from 1955 to 1979. The rate of natural oil replenishment calculated for 29 operating facilities of the Bibieybat field varies per well within 0.32–1.4 ton/day (averaging 0.76 ton/day) or about 277 ton/year. The rate of natural gas inflow at the Garadag gas condensate field is about 5.2 thousand m3/day per well.

scholarly journals Signs of Natural Renewal of Oil and Gas Reserves in Fields of the South Caspian Basin

2020 ◽  
Vol 3 (3) ◽  
Keyword(s):  
Oil And Gas ◽  
Dynamic Equilibrium ◽  
Gas Production ◽  
Oil Field ◽  
Gas Condensate ◽  
Caspian Basin ◽  
Geological Time ◽  
South Caspian Basin ◽  
Sharp Drop ◽  
Oil And Gas Production

Results are given of oil and gas production in the long-lived fields Bibieybat and Garadag of the Absheron Peninsula, South Caspian Basin (SCB). The analysis for the Bibieybat oil field covered the period from 1935 to 2018, and for the Garadag gas condensate field from 1955 to 1979. The development is the Productive Series (lower Pliocene) - main reservoir of the SCB. The intensive development of these fields leads to the disturbance of the natural dynamic equilibrium established in the reservoir over geological time. A sharp drop of formation pressure (significantly lower than hydrostatic) during field development contributes to the natural inflow of hydrocarbon fluids to the reservoir. The rate of natural oil replenishment calculated for 29 operating facilities of the Bibieybat field varies per well within 0.32-1.4 ton/day (averaging 0.76 ton/day) or about 277 ton/year. The rate of natural gas inflow at the Garadag gas condensate field is different for its various blocks, averaging 5.2 thousand m3/day per well. Stable oil and gas production and the equivalent rate of natural recharge are determined by the influence of a complex of factors, of which reservoir pressure, temperature and permeability of the reservoir rocks are dominant.

The Bahar oil and gas-condensate field in the South Caspian Basin

1998 ◽  
Vol 4 (3) ◽  
pp. 253-258 ◽  
Author(s):  
A. A. Narimanov ◽  
N. A. Akperov ◽  
T. I. Abdullaev
Keyword(s):  
Oil And Gas ◽  
Gas Condensate ◽  
Caspian Basin ◽  
The South ◽  
South Caspian Basin

Late Life Field Management with Instrumentation Failure. Modelling Predictions and Successful Validations of Late Life Subsea Gas Condensate System Using Historical Field Data

2021 ◽  
Author(s):  
Lawrence Khin Leong Lau ◽  
Kun An ◽  
Wu Jun Tong ◽  
Song Wang ◽  
Zhi Wei Yue ◽  
...  
Keyword(s):  
Field Data ◽  
Pressure Fluctuations ◽  
Flow Characteristics ◽  
Late Life ◽  
Flow Regimes ◽  
Gas Condensate ◽  
Well Production ◽  
Water Cut ◽  
Instrumentation Failure ◽  
Condensate System

Abstract Depleting reservoir pressure, increasing water cut and decreasing overall system production leading to increased liquid holdup are among the key challenges for typical late life gas condensate production system. This paper elucidates modelling details of a late life offshore subsea gas condensate system and how the findings are implemented and validated with actual field data for successful outcomes. There is only one subsea well remain in operation with relatively long subsea flowlines. Subsea pressure and temperature transducers are out of service as the asset approaches the end of design life. In this context, flow assurance team has taken the modelling approach in order to minimize cost and to maximize values. Detailed transient multiphase thermohydraulics models are developed and benchmarked against field data. Historical field data over the past two years are utilized in order to predict the trend for key parameters such as well production rates and water to gas ratio (WGR). Matrix of simulation including the predictions of slugging flow regimes are carried out for the entire flow path, from reservoir characteristics descriptions at bottom hole, through flow regimes analysis at topsides slug catcher. Three categories of operation characteristics, namely the low risk, medium risk, and high risk production periods are identified. It is predicted that the system would start to fall into slugging flow regimes from 2 months onwards with final production end date of after 10 months. This is shared with wider team such that operations and base management teams are informed with predicted multiphase flow characteristics for the remaining production life. As such, gas supply succession plan can be executed in time to ensure uninterrupted downstream commercial agreement. Feedbacks from operations team revealed accurate predictions of such analysis, including slugging flow phenomenon which was associated with flow and pressure fluctuations, was observed in field as predicted by the study. More importantly, the production cut-off date is accurately predicted 10 months ahead and within the accuracy of ± 1 week. This study demonstrated how historical field data, coupled with detailed transient multiphase thermohydraulics modelling, can be utilized for offshore gas condensate production predictions during late life. Without transducers and/or virtual metering data feed, production end date can be accurately predicted based on key parameters analysis. This is particularly valuable for supply succession planning and is deemed a successful case study with significant positive outcomes which can be used as reference for other gas condensate assets.

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