Horizontal Wells Pressure Build Up Analysis in Orinoco Heavy Oil Belt

Briceno, Maria Gabriela; Summers, L.E.; Quijada, O.J.

doi:10.2118/78969-ms

Cited by 4 publications

(2 citation statements)

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“…Considering the narrow width of the streak and the huge contrast of permeability in the range of three orders of magnitude, this model is unlikely to match geological reality. Briceño et al (2002), it was reported that a bilinear flow regime is observed in well tests for horizontal wells that are overlying or underlying formations with a shale barrier. This was attributed to the transient double porosity behavior as explained by Du and Stewart (1992) above.…”

Section: Dual Layer Formation With Higher-permeability Layer Overlyinmentioning

confidence: 99%

“…It was explained that the bilinear flow is a result of linear flow in the high-permeability sub-vertical zone and linear flow in the surrounding low-permeability zone feeding into the high-permeability zone. Briceño et al (2002) attributed the presence of a ¼ slope straight line in the pressure derivative of a well in the Zuata field to transient dual-porosity behavior caused by the single well overlying or underlying shale barriers which possess different permeabilities and porosities. Jelmert andVik (1995, 2000) theorized that flow in the regions beyond the tips of the horizontal well may contribute to production during intermediate-times despite the conventional assumption of only linear flow perpendicular to well.…”

Section: Introductionmentioning

confidence: 99%

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Bilinear Flow in Horizontal Wells in a Homogeneous Reservoir: Huntington Case Study

Feng

2015

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In the Huntington field, bilinear flow with a clear one-quarter unit slope in the pressure derivative has been observed during intermediate-times in horizontal well tests, instead of the usual linear flow with a half unit slope expected in a homogeneous reservoir. This paper investigates various analytical methods with numerical methods to explain this behaviour.A number of plausible explanations of this pressure behavior were investigated in this study: rate history or production-time effects; transition between early and late time derivative radial flow stabilizations which could yield a quarter slope straight line on the derivative for specific combinations of horizontal and vertical permeabilities, well length and reservoir thickness; and geological conditions such as high-permeability streaks, the presence of shale barriers, and layering with varying permeability.It was concluded from numerical simulations and geological evidence that the most likely explanation, which yields the best match with well test data, was uniform horizontal permeability and non-uniform vertical permeability increasing from the bottom to the top of the reservoir. This is consistent with the geology of the Huntington field, where the depositional sequence is dominated by high-density turbidity currents.At each sedimentation pulse, heavier pebble/gravel lags were deposited first at the base of channels followed by finer particles which may have formed thin shale drapes. In addition, diagenesis might have led to cementation of pebble/gravel lags. The non-uniform and non-laterally extensive occurrence of the cemented pebble/gravel lags and thin shale drapes act as local baffles to vertical flow but not to horizontal flow resulting in bilinear flow behaviour in the reservoir. This paper offers a unique insight into an integrated effort at combining analytical, numerical well test models and geological evidence to explain the reservoir behavior observed in the Huntington field.

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Section: Dual Layer Formation With Higher-permeability Layer Overlyinmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Bilinear Flow in Horizontal Wells in a Homogeneous Reservoir: Huntington Case Study

Feng

2015

All Days

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Adaptability of Productivity Model for Cold Production by Horizontal Wells in Extra-Heavy Oil Reservoirs

Yang

Liu

et al. 2023

Springer Series in Geomechanics and Geoengineering

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Rate-Time Flow Behavior of Heavy Oil From Horizontal and Multilateral Wells

et al. 2006

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This paper examines the behavior of heavy oil reservoirs developed with horizontal and multilateral wells. Advanced decline curve analyses were used to characterize flow regimes and estimate the time to pseudosteady-state. Reservoir and well parameters such as the OOIP, Arps "b" exponent, decline rate, reserves, permeability and well productivity indices were also determined. Example analyses are presented for single, dual and triple lateral wells from heavy oil fields located in Venezuela and Canada. All wells exhibit a characteristic extended transient linear flow regime followed by an exponential decline. Similar results were obtained whether the analyses were performed on single, dual or triple lateral wells. Interference between laterals was not observed. Introduction The application of horizontal and multilateral wells is gaining momentum worldwide due to their ability to drain reservoirs more effectively. This advantage is even more pronounced in tight gas or heavy oil reservoirs where low mobility is responsible for long transient flow periods. The relatively new application of these exotic well geometries to such reservoirs provides a challenge in the area of production forecasting because traditional methods and equations were developed based on flow to a vertical well. This paper demonstrates the use of rate-time performance analyses on heavy oil reservoirs developed with horizontal and multilateral wells. Well productivity indices (PI) were calculated from the transient production period by matching the rate-time data to type curves. Permeability-thickness or the equivalent skin factor was calculated based on this PI. Hydrocarbon volume connected to the well, the Arps "b" exponent and the decline rate were calculated from the pseudosteady-state producing period. The decline curve results were also verified using a reservoir simulation flow model. Decline curve analysis was performed on the rate versus time values generated by the flow model to confirm that the model had similar transient and depletion behavior as the actual performance data. Decline Curve Analysis Concepts When a well is first opened to flow, it produces under transient flow conditions. It will remain under this condition until the production from the well affects the entire drainage area. This flow condition is referred to as pseudosteady-state or boundary dominated flow. Transient rate and pressure data are used to calculate permeability-thickness and skin, whereas pseudosteady-state data are used to determine connected OOIP. Constant well pressure solutions used to predict declining production rates as a function of time were first published in 1933 by Moore, Schilthius, and Hurst.[1] Results were presented for infinite, slightly compressible, single phase plane radial systems. The results were presented in graphical form in terms of dimensionless flow rate and dimensionless time as shown in Figure 1.

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Horizontal Wells Pressure Build Up Analysis in Orinoco Heavy Oil Belt

Abstract: TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe innovative application of

Cited by 4 publications

References 10 publications

Bilinear Flow in Horizontal Wells in a Homogeneous Reservoir: Huntington Case Study

Bilinear Flow in Horizontal Wells in a Homogeneous Reservoir: Huntington Case Study

Adaptability of Productivity Model for Cold Production by Horizontal Wells in Extra-Heavy Oil Reservoirs

Rate-Time Flow Behavior of Heavy Oil From Horizontal and Multilateral Wells

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