A Model for Gas Coning and Rate-Dependent Gas/Oil Ratio in an Oil-Rim Resevoir

The development of gas-oil reservoir with condensate gas is more difficult than pure gas reservoir or oil reservoir. This article gives the example of G oil reservoir the development of gas cap and oil rim. According to the characteristic of the oil developing and the results of numerical simulation, the rules for oil and gas developing and developing time have been defined, by which the recoveries of gas, oil, and condensate oil will reach a significantly high level.

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Autonomous Inflow Control Valve Multiphase Flow Performance for Light Oil

10.4043/31239-ms ◽

2021 ◽

Author(s):

Soheila Taghavi ◽

Einar Gisholt ◽

Haavard Aakre ◽

Stian Håland ◽

Kåre Langaas

Keyword(s):

Multiphase Flow ◽

Single Phase ◽

Control Valve ◽

Oil Reservoirs ◽

Test Results ◽

Gas Oil ◽

Flow Loop ◽

Light Oil ◽

Water Cut ◽

Oil Rim

Abstract Early water and/or gas breakthrough is one of the main challenges in oil production which results in inefficient oil recovery. Existing mature wells must stop the production and shut down due to high gas oil ratio (GOR) and/or water cut (WC) although considerable amounts of oil still present along the reservoir. It is important to develop technologies that can increase oil production and recovery for marginal, mature, and challenging oil reservoirs. In most fields the drainage mechanism is pressure support from gas and/or water and the multiphase flow performance is particularly important. Autonomous Inflow Control Valve (AICV) can delay the onset of breakthrough by balancing the inflow along the horizontal section and control or shut off completely the unwanted fluid production when the breakthrough occurs. The AICV was tested in a world-leading full-scale multiphase flow loop located in Porsgrunn, Norway. Tests were performed with realistic reservoir conditions, i.e. reservoir pressure and temperature, crude oil, formation water and hydrocarbon gas at various gas oil ratio and water cut in addition to single phase performances. A summary of the flow loop, test conditions, the operating procedures, and test results are presented. In addition, how to represent the well with AICVs in a standard reservoir simulation model are discussed. The AICV flow performance curves for both single phase and multiphase flow are presented, discussed, and compared to conventional Inflow Control Device (ICD) performance. The test results demonstrate that the AICV flow performance is significantly better than conventional ICD. The AICV impact on a simplified model of a thin oil rim reservoir is shown and modelling limitations are discussed. The simulation results along with the experimental results demonstrated considerable benefit of deploying AICV in this thin oil rim reservoir. Furthermore, this paper describes a novel approach towards the application of testing the AICV for use within light oil completion designs and how the AICV flow performance results can be utilized in marginal, mature, and other challenging oil reservoirs.

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Improved near-well approximation for prediction of the gas/oil production ratio from oil-rim reservoirs

Computational Geosciences ◽

10.1007/s10596-011-9250-6 ◽

2011 ◽

Vol 16 (2) ◽

pp. 231-246 ◽

Cited By ~ 3

Author(s):

Svenn Anton Halvorsen ◽

Are Mjaavatten ◽

Robert Aasheim

Keyword(s):

Oil Production ◽

Gas Oil ◽

Production Ratio ◽

Oil Rim

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RESERVOIR SIMULATION IN THE MEREENIE FIELD

The APPEA Journal ◽

10.1071/aj85037 ◽

1986 ◽

Vol 26 (1) ◽

pp. 428

Author(s):

B.F. Towler

Keyword(s):

Oil Recovery ◽

Reservoir Simulation ◽

Water Injection ◽

Gas Oil ◽

The North ◽

Stock Tank ◽

Bottom Hole Flowing Pressure ◽

Steep Decline ◽

Oil Rim ◽

Reservoir Simulator

The Mereenie Field in the Amadeus Basin was discovered in 1964 and contains an estimated 240 million barrels of oil and 480 billion (USA) cubic feet of gas in three formations. The field commenced production at 1500 barrels of oil per day from seven wells in September 1984. The structure is large and elongated and the oil in the permeable sands appears as a rim round the structure. This paper describes a reservoir simulation study initiated to evaluate the recovery of oil from wells sited on the north and south flanks of the anticline where the steep dips cause the oil rim to become very narrow.Ten studies were made on a 21 × 15 cell pattern model using a three phase semi-implicit black oil reservoir simulator. The ten runs compared oil recovery and gas/oil ratio as a function of formation dip, bottom hole flowing pressure, gas injection and water injection. These showed that the flank wells could be expected to recover 300 000 stock tank barrels of oil from primary and secondary operations which represents about 25 per cent of the oil in place for wells sited on half mile spacings. However the wells will experience high gas/oil ratios and a steep decline in oil rate.

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Understanding and Modeling Gas Breakthrough in the Karachaganak Gas Condensate Field

10.2118/207072-ms ◽

2021 ◽

Author(s):

Abdulmalik Ibragimov ◽

Andrey Kan

Keyword(s):

Production Optimization ◽

Gas Oil ◽

Sector Model ◽

Gas Processing ◽

Rate Dependent ◽

Reducing Gas ◽

Field Level ◽

Estimate Rate ◽

Level Production ◽

Field Production

Abstract Field production constrained with surface facilities on gas handling have to deal with well rates optimization by reducing gas oil ratio of the field production. This means the best way of reducing gas oil ratio on field level is not by closing wells with the highest gas oil ratio but chocking back wells where gas breakthrough occurred and GOR of a well is rate dependent [1]. In this paper, authors modeled and analyzed wells with gas breakthrough in single porosity and dual porosity sector models. The analysis showed single porosity models underestimate severity of gas breakthrough and fail to predict rate dependent GOR of a well in the field. Also, based on the sector model using machine-learning technique an empirical equation was developed to estimate rate dependent GOR of a well which can be further used in field level production optimization exercise to reach maximum liquid production under gas processing constraints.

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Optimizing productivity in oil rims: simulation studies on horizontal well placement under simultaneous oil and gas production

Journal of Petroleum Exploration and Production Technology ◽

10.1007/s13202-020-01018-9 ◽

2020 ◽

Author(s):

Oluwasanmi Olabode ◽

Sunday Isehunwa ◽

Oyinkepreye Orodu ◽

Daniel Ake

Keyword(s):

Oil Recovery ◽

Oil And Gas ◽

Horizontal Wells ◽

Gas Production ◽

Gas Oil ◽

Reservoir Properties ◽

Well Placement ◽

Hydrocarbon Production ◽

Oil And Gas Production ◽

Oil Rim

AbstractThin oil rim reservoirs are predominantly those with pay thickness of less than 100 ft. Oil production challenges arise due to the nature of the gas cap and aquifer in such reservoirs and well placement with respect to the fluid contacts. Case studies of oil rim reservoir and operational properties from the Niger-Delta region are used to build classic synthetic oil rim models with different reservoir parameters using a design of experiment. The black oil simulation model of the ECLIPSE software is activated with additional reservoir properties and subsequently initialized to estimate initial oil and gas in place. To optimize hydrocarbon production, 2 horizontal wells are initiated, each to concurrently produce oil and gas. Well placements of (0.5 ft., 0.25 ft. and 0.75 ft.) are made with respect to the pay thickness and then to the fluid contacts. The results show that for oil rim with bigger aquifers, an oil recovery of 8.3% is expected when horizontal wells are placed at 0.75 ft. of the pay thickness away from the gas oil contact, 8.1% oil recovery in oil rims with larger gas caps with completions at 0.75 ft. of the pay zone from the gas oil contacts, 6% oil recovery with relatively small gas caps and aquifer and 9.3% from oil rims with large gas caps and aquifers, with completions at mid-stream of the pay zone.

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Creating the Integrated Model for Conceptual Engineering of Reservoir Management and Field Facilities Construction – Experience of Tazovskoe Oil and Gas-Condensate Field.

10.2118/206540-ms ◽

2021 ◽

Author(s):

Artem Igorevich Varavva ◽

Renat Timergaleevich Apasov ◽

Dmitry Alexeyevich Samolovov ◽

Artem Viktorovich Elesin ◽

Gaidar Timergaleevich Apasov ◽

...

Keyword(s):

Growth Rates ◽

Oil And Gas ◽

High Growth ◽

Integrated Model ◽

Gas Condensate ◽

Gas Oil ◽

Full Field ◽

Conceptual Engineering ◽

Construction Experience ◽

Oil Rim

Abstract The paper describes the experience of building a full-field integrated model (PK1 reservoir) of the Tazovskoye field, including a model of the reservoir, wells, and a gathering network, taking into account the external transportation system. In order to integrate the features of the field, such as the simultaneous development of a thin oil rim and a gas cap, high growth rates of the gas-oil ratio, oil wells - both ESP-operated and flowing, algorithms and tools have been developed, which are discussed in the paper. The results of the integrated model runs are given, main features of the solutions are highlighted.

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