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Research Papers: Petroleum Engineering

The Experimental and Model Study on Variable Mass Flow for Horizontal Wells With Perforated Completion

[+] Author and Article Information
Wei Jianguang, Lin Xuesong, Ma Yuanyuan

School of Petroleum Engineering,
Northeast Petroleum University,
Daqing 163318, Heilongjiang, China

Liu Xuemei

School of Petroleum Engineering,
Northeast Petroleum University,
Daqing 163318, Heilongjiang, China
e-mail: lxmdqsy@163.com

Contributed by the Petroleum Division of ASME for publication in the JOURNAL OF ENERGY RESOURCES TECHNOLOGY. Manuscript received June 6, 2016; final manuscript received April 19, 2017; published online July 17, 2017. Assoc. Editor: Egidio Marotta.

J. Energy Resour. Technol 139(6), 062901 (Jul 17, 2017) (7 pages) Paper No: JERT-16-1235; doi: 10.1115/1.4037026 History: Received June 06, 2016; Revised April 19, 2017

The variable mass flow in perforated horizontal wells is very complex. One reason is that the perforation can increase the roughness of the pipe wall which will increase the frictional pressure drop. The other is the fluid boundary layer and velocity profile of axial flow will be changed due to the “mixing” of the inflow with the axial flow. The influences of the perforation parameters and flux rate on the pressure drawdown in horizontal wellbore are investigated. The perforation parameters include perforation phasing, perforation diameter, and perforation density. According to the experiment results, some modes such as friction factor calculation model (the accuracy of the model is 4%), “mixing” pressure drop calculation model (the accuracy of the model is 3%), and total pressure drop calculation model (the accuracy of the model is 2%) are developed.

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References

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Figures

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Fig. 4

(a) Frictional pressure drop gradient versus Re with different perforation density without inflow, (b) frictional pressure drop gradient versus Re with different perforation diameter without inflow, and (c) frictional pressure drop gradient versus Re with different perforation phasing without inflow

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Fig. 5

(a) Total pressure drop gradient versus flux ratio with different perforation density with inflow, (b) total pressure drop gradient versus flux ratio with different perforation diameter with Inflow, and (c) total pressure drop gradient versus flux ratio with different perforation phasing with inflow

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Fig. 6

(a) “Mixing” pressure drop gradient versus flux ratio with different perforation density with inflow, (b) “mixing” pressure drop gradient versus flux ratio with different perforation diameter with inflow, and (c) “mixing” pressure drop gradient versus flux ratio with different perforation phasing with inflow

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Fig. 7

(a) The pressure drop gradient versus flux ratio with Re = 5000 of axial flow and (b) the pressure drop gradient versus flux ratio with Re = 15,000 of axial flow

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Fig. 8

Precision verification of frictional pressure drop calculation model

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Fig. 9

(a) Precision verification of “mixing” pressure drop calculation model with Re = 5000 in axial flow and (b) precision verification of “mixing” pressure drop calculation model with Re = 15,000 of axial flow

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Fig. 10

(a) Precision verification of total pressure drop calculation model with Re = 5000 of axial flow and (b) precision verification of total pressure drop calculation model with Re = 15,000 of axial flow

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