A Selection of Past Completions and Slickline Installs

Since our introduction, 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 and associated loss of production. The AccessESP system 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: To replace only the pump (not the motor) in a well. Operating Environment: Alaska North Slope

CHALLENGE: Harsh conditions, high sand production, seasonal operations. The wells in Alaska are 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. System used: 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. Success: Completed February 2014, 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: To do a trial test proving the use of Slickline Rigless Deployed ESP technology.

CHALLENGE: Harsh conditions, high sand production, seasonal operations. High workover costs to repace defective ESPs. A conventional ESP replacement requires an average of 10 days rig intervention. When coupled with a subsequent defferred production, both due to dependence on available workover rig in the field, the conventional ESP intervention can lead to exceedingly high operating costs.

SOLUTION: Install the retrievable assembly and permanent completion (dock) at the well location according to the workover program. Pull the ESP and rerun using slick-line unit.

RESULT: Completed 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: Install an alternatively deployed ESP to reduce future ESP replacement costs by using a retrievable ESP system. Operating Environment: Offshore West Africa

CHALLENGE: Unknown reservoir capacity of the well, therefore needed cost-effective method to replace the ESP, if required. Technical Challenges: Work-over costs, 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, in days rather than months for a conventional ESP.

RESULT: The new retrievable ESP system 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: Well was diagnosed with developing recirculation downhole. Objective was to test & confirm recirculation implementing repair.

CHALLENGE: Horizontally placed ESP, small offshore platform with limited footprint, needed tractor as well as compact mast and slickline unit.

SOLUTION: Test well with plug on packoff (string did not include check valve) to confirm recirculation, pull tubing packoff and tubing stop with slickline, replace tubing packoff, now install with check valve, all using slickline and tractor.

RESULT: Well was successfully put back in full production, demonstrated the system flexibility and system changeout without a need for an intervention rig.

High Deviated - Extreme Sand Production

OBJECTIVE: To clean out a well with reduced flow rate caused by sand.

CHALLENGE: Sand accumulated to 2000 ft above the Pump. The retrievable system must be removed, the well cleaned and the retrievable system replaced, all without killing the well.

SOLUTION: Due to high deviation, coiled tubing and slickline was used to remove the sand and the Retrievable System, install Isolation Sleeve across wet-connect enabling clean-up to the producing zone. Retrieve the Isolation Sleeve and reinstalled the Retrievable System.

RESULT: The well-clean was successfully performed in a live well and production restored to previous level. Minimized disruption to oil production and HSE risks.

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