17 Years Development of Artificial Lift Technology in ASP Flooding in Daqing Oilfield

An Innovative Artificial Lift Technology for Severely Scaling Wells Applied Successfully in Asp Flooding in Daqing Oilfield

10.2118/192121-ms ◽

2018 ◽

Author(s):

Mingzhan Chen ◽

Jiecheng Cheng ◽

Wanfu Zhou ◽

Youquan Huang ◽

Xiaoming Sun ◽

...

Keyword(s):

Asp Flooding ◽

Artificial Lift

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Understanding of the Fluid Flow Mechanism in Porous Media of EOR by ASP Flooding from Physical Modeling

10.2523/11257-ms ◽

2007 ◽

Cited By ~ 2

Author(s):

Jialu Wang ◽

Shiyi Yuan ◽

Pingping Shen ◽

Taixian Zhong ◽

Xu Jia

Keyword(s):

Porous Media ◽

Fluid Flow ◽

Physical Modeling ◽

Flow Mechanism ◽

Asp Flooding

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Fully Retrievable ESP: A New Artificial Lift Concept

10.2523/17203-ms ◽

2013 ◽

Author(s):

S. Spagnolo ◽

S. Pilone ◽

L. Corti ◽

G. Liantonio ◽

G. Rizza ◽

...

Keyword(s):

Artificial Lift

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ESP Optimization Goes Further: Operating Frequency Beyond 60 Hz

Proc. Indon. Petrol. Assoc., Digital Technical Conference, 2020 ◽

10.29118/ipa20-e-379 ◽

2020 ◽

Author(s):

A. Muklas

Keyword(s):

Circuit Breaker ◽

Load Level ◽

Operating Frequency ◽

Well Test ◽

Acceptable Range ◽

Artificial Lift ◽

Harmonic Filter ◽

Electrical Submersible Pump ◽

Motor Load ◽

Frequency Changes

Optimization in brown field developments is always challenging in terms of cost. One of it is XY Field, Rimau Block, South Sumatera with more than 70% of artificial lift is Electrical Submersible Pump (ESP). At ESP wells that are already running at maximum operating frequency of 60 Hz, some are still having problems to optimize their potential. The option to replace the pump with a higher rate is less of an option due to high cost. This leaves an opportunity to gain oil production by increasing frequency above 60 Hz. Upon discussion with the ESP Principal on the risks and possibilities, a trial was then planned for 3-wells. Candidates are selected from the list of ESP wells with the following criteria such as already operated at 60 Hz, still have sufficient fluid submergence, and based on simulated motor load at 70 Hz is still at safe motor load level. Frequency was increased gradually while continuously monitoring ESP Parameters (motor load, voltage and harmonic). It is also necessary to monitor the cable temperature as it is directly affected by the frequency changes. For each frequency increment, a well test is also performed to monitor the production changes. The trial was done on 3-wells (XY-364, XY-370 and XY-378), with the following promising results. XY-364 and XY-378 successfully reached the targeted 70Hz, while XY-370 stopped at 65Hz due to a cable temperature issue. Oil gain from this optimization was 48 BOPD with 1,043 BLPD and similar BS&W profile. ESP operation still normal until present day with all parameters at acceptable range. There were, however, challenges found during the trial. Cable temperature of XY-364 increased at junction box and found cable scun loosen. The problem was solved by replacing the cables. For XY-370, found temperature increment at moulded case circuit breaker during trial at 65 Hz. It was decided to hold at existing frequency. Unbalanced motor load at XY-364 and broken capacitor at XY-370 occurred at Harmonic Filter. The problem was solved by replacing the capacitor. The trial proves that we can operate ESP higher than base frequency (60 Hz) and resulted in decent oil gain. This opens an opportunity in ESP optimization above 60 Hz at an even larger scale.

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Unlocking Oil Resources without Artificial Lift Using Testing Barge in Tambora Gas Field

Proc. Indon. Petrol. Assoc., Digital Technical Conference, 2020 ◽

10.29118/ipa20-e-313 ◽

2020 ◽

Author(s):

J., A. Anggoro

Keyword(s):

Oil Recovery ◽

Gas Field ◽

Artificial Lift ◽

Oil Resources ◽

Cumulative Production ◽

Inspection And Maintenance ◽

Routine Inspection ◽

Prime Condition ◽

Safety Operation ◽

Mahakam Delta

Tambora field is a mature gas field located in a swamp area of Mahakam delta without artificial lift. The main objective of this project is to unlock existing oil resources. Most oil wells could not flow because there is no artificial lift, moreover the network pressure is still at Medium Pressure (20 Barg). Given the significant stakes, the option to operate the testing barge continuously as lifting tool is reviewed. The idea is to set the separator pressure to 1-3 Barg, so that the wellhead flowing pressure could be reduced to more than 15 Barg which will create higher drawdown in front of the reservoir. The oil flows from the reservoir into the gauge tank, where it is then returned to the production line by transfer pumps. The trial was performed in well T-1 for a week in November 2017 and successfully produced continuous oil with a stable rate of 1000 bbls/d. What makes this project unique is the continuous operation for a long period of time. Therefore, it is important to ensure the capacity of the gauge tank and the transfer pump compatibility with the rate from the well, the system durability which required routine inspection and maintenance to ensure the testing barge unit is in prime condition and to maintain vigilance and responsiveness of personnel. This project started in 2018 for several wells and the cumulative production up to January 2020 has reached 158 k bbls and will be continued as there are still potential oil resources to be unlocked. Innovation does not need to be rocket science. Significant oil recovery can be achieved with a simple approach considering all safety operation, production and economic aspect.

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