Eliminating Water Cut with Water Shutoff Treatment | Schlumberger
Case Study
Location
United States, North America, Offshore
Details

Challenge: Effectively shut off water production in 7-in [177.8 mm] liner

Solution: Set 3-in [76.2 mm] CoilFLATE packer as a mechanical isolation device to effectively place OrganoSEAL F water shutoff treatment fluid in the water producing section of the well

Results: Eliminated water production and increased oil production

Products Used

Eliminating Water Cut with Water Shutoff Treatment

CoilFLATE permanent bridge plug and OrganoSEAL fluid boost oil production in the Gulf of Mexico

Water cut causes 54-month shut-in

A Gulf of Mexico well in the Calcarenitas formation was drilled as an oil producer and completed with a 7-in [177.8 mm] liner. The minimum restriction in the well was 3.675 in [93.345 mm]. The operator had to shut it in for 54 months because of high water cut. .

Operator implements water shutoff treatment

The operator chose a Schlumberger water shutoff treatment. The project included:

  • setting a CoilFLATE packer in a 65-ft [19.8-m] window (at 10,500 ft to 10,435 ft [3,200 m to 3,180.6 m])
  • injecting OrganoSEAL F fluid below the packer
  • leaving the packer in the well as a permanent bridge plug
  • placing a 30-ft [9-m] cement plug on top of the bridge plug
  • perforating a new zone above the packer
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The Schlumberger water shutoff treatment boosted oil production from 0 bbl/d to 1,490.

A dummy run was performed with the Jet Blaster* jetting scale removal service and ACTive* in-well live performance—an optical fiber pressure, temperature, and casing collar locator (CCL) tool—to cor-relate depth in real time, clean the ID of the casing at setting depth, and drift the casing. The setting depth had to be accurate to ensure that the top of the cement plug to be placed on the bridge plug was below the new interval to be perforated. The ACTive tool in the coiled tubing (CT) string provided accurate real-time transmission of casing collar infor-mation from the downhole CCL tool to the surface acquisition system for correlation.

The packer was run in hole and set at 10,480 ft [3,194 m] in the 6.184-in [157.074-mm]-ID liner. After the packer was set, 200 bbl of OrganoSEAL F organic crosslinked gel and 20 bbl of SqueezeCRETE* cement were injected through the packer to shut off water production from the zone below. The CT was disconnected from the packer, and a 30-ft [9-m] cement plug was placed on it to make the packer a perma-nent bridge plug.

Oil production increases by 100%

New perforations were made from 10,320 ft to 10,420 ft [3,145 m to 3,176 m], and10 days after the water shutoff treatment, oil production was at 100%—with zero water cut.

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The engineered slat design allowed higher differential pressures at varying inflation ratios.

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