How Our ESP Technology Made a Difference

Since the beginning, we have focused our efforts on remote areas operations, such as the Arctic and offshore, where changing a traditional ESP takes a long time due to rig availability. Our ESP technology offers significantly lower intervention costs, reduces lost production and provides full-bore access to the reservoir by eliminating the need for a workover rig. Furthermore, the live well intervention saves costs and avoids reservoir damage, as no kill fluid is required.

Alaska – Pump Only Replacement

OBJECTIVE: The operator wanted to replace only the pump (not the motor) in a well.

CHALLENGE: Harsh conditions and seasonal operations posed challenges. The wells in Alaska are also exposed to excessive sand production, causing pump wear and subsequent reduced production and short run lives.

SOLUTION: Following an early detection of production decline, the operator mobilized slickline equipment and performed a pump-only swap in the well. The operator used the Access375 wireline retrievable ESP system, 3.75” run in 4.5” tubing.

RESULT: This proactive slickline intervention took place in two days, minimizing the production impact and brought the well back on full production with the new pump. It was completed February 2014 and is still operating after more than 1,300 days. Cost savings = $6.7M

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Well operations:

  • February 2014: Initial rig installation Access375 system..
  • October 2015: Pump worn, swapped prior to failure, resized to better match changed production characteristics
  • December 2016: Pump worn, swapped prior to failure, resized to better match production. Motor and wet connect not pulled, pump only operation (one slickline run)
  • October 2017: (Swap pump only) This is the third pump swap on this well in four years, as per system design and customer programs. Pump only operation (one slickline run)
  • April 2018: Pump worn, swapped prior to failure, motor and wet connect not pulled, pump only operation (one slickline run)

Middle East Field Case: SPE-188175 (Saudi Aramco)

OBJECTIVE: We set out to do a trial test proving the use of slickline rigless deployed ESP technology.

CHALLENGE: Harsh conditions, high sand production and seasonal operations created challenges. A conventional ESP replacement requires an average of 10 days rig intervention. When coupled with the subsequent deferred production, a conventional ESP intervention can lead to exceedingly high operating costs.

SOLUTION: We installed the retrievable assembly and permanent completion (dock) at the well location according to the workover program. Then we pulled the ESP and rerun using a slickline unit.

RESULT: Completed in August 2016, the test included six months operating and three slickline system swaps. The permanent completion (dock) has over 400 operating days, and the retrievable systems has over 250 days without failure. Read more about the results in the SPE paper presented at ADIPEC 2017 in a session on well intervention advances.

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Well operations:

  • August 2016:
    • Install permanent completion (dock), AccessESP docking system.
    • Install AccessESP PMM and service company pump.
    • Swap pump and motor using slickline
  • September 2016: Swap pump and motor using slickline
  • February 2017: Swap pump and motor using slickline

West Africa Offshore Installation

OBJECTIVE: The goal was to install an alternatively deployed ESP to reduce future ESP replacement costs by using a retrievable ESP system.

CHALLENGE: The reservoir capacity of the well was unknown; therefore, the operator needed a cost-effective method to replace the ESP, if required. Technical challenges included high work-over costs and rig availability.

SOLUTION: The productivity of the well was found to be much higher than expected, and the 190hp retrievable ESP system was replaced with a 250hp system using slickline. The process was completed the process in days rather than months as with a conventional ESP.

RESULT: The new retrievable ESP technology achieved the required drawdown and target production rate. Completed April 2017, this was a major offshore asset in production for almost 20 years with complex production and secondary recovery issues. With over 200 operating days, it continues production.

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Well operations:

  • April 2017:
    • Install permanent completion (dock), AccessESP docking system
    • Install AccessESP PMM and service company pump

West Africa System Component Changeout

OBJECTIVE: The well was diagnosed with developing recirculation downhole. The objective was to test and confirm recirculation implementing repair.

CHALLENGE: The well had a horizontally placed ESP and a small offshore platform with limited footprint. We needed a tractor as well as compact mast and slickline unit.

SOLUTION: We tested the well with a plug on packoff (string did not include check valve) to confirm recirculation, pulled tubing packoff and tubing stop with slickline, replaced tubing packoff and installed with check valve, all using slickline and a tractor.

RESULT: We successfully put the well back in full production and demonstrated our ESP technology’s flexibility without need for an intervention rig.

High Deviated – Extreme Sand Production

OBJECTIVE: We needed to clean out a well with reduced flow rate caused by sand.

CHALLENGE: Sand accumulated to 2,000 feet above the pump. The retrievable system needed to be removed, the well cleaned and the retrievable system replaced, all without killing the well.

SOLUTION: Due to high deviation, we used coiled tubing and slickline to remove the sand and the retrievable system and to install the isolation sleeve across wet-connect, enabling clean-up to the producing zone. We retrieved the isolation sleeve and reinstalled the retrievable system.

RESULT: We successfully performed a clean-out in a live well and restored production to the previous level. We minimized disruption to oil production and health, safety and environment risks.

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