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Offshore Norway

REGION
SPECIFIC CHALLENGE

Remotely located exploration well offshore Norway as their most critical well in

Challenge

  • Reduce casing run times to improve operational efficiency
  • Find cost-effective drilling fluid and lubricant additives
  • Avoid non-productive time (NPT) during the operation

Solution

Two-pronged technical approach considering hydraulic and chemical factors in achieving well construction success:

  • Baroid Drilling Fluids Graphics (DFG™) software – for hole cleaning optimization and sweep design
  • Custom lubricant package – incorporating proprietary products designed to be spotted in the lateral up to the curve

Results

  • Reduced time to run production casings by an average of 10 hours
  • Saved operator USD 25,000 per well
  • Enhanced asset value by combining engineered chemistry with hydraulic modeling

Overview

Extremely high temperatures, risk of severe downhole losses in a karstic formation, and presence of hydrogen sulfide (H2S) led the operator to classify this remotely located exploration well offshore Norway as their most critical well in 2021. Through extensive technical and logistical planning, the well was successfully drilled by using BaraECD® non- aqueous fluid (NAF), pre-treated with SOURSCAV™ H2S scavenger. Although H2S was proven to be present within the formation fluids, no H2S was ever recorded at surface throughout the drilling of an 8½-in. reservoir section. The execution of the well was a success, and “Good quality on the fluid throughout the whole project” was reported by the customer.

Challenge

This complex exploration well required a customized fluid solution to meet several objectives. First and foremost, it needed to ensure stable and safe execution when drilling into a karstic reservoir section with a potential for up to 35% H2S gas within formation fluids. At the same time, it would have to withstand bottomhole temperatures (BHT) up to 150°C, requiring sufficient stability while executing a wireline program that could last up to 7 days. In addition, the nearest supply base was 30 hours sailing time from the offshore rig site, which presented yet another obstacle with regards to quickly accessing a sufficient fluid reserve volume in case of severe downhole losses when drilling into the karstic formation.

To properly mitigate the worst-case scenario of 35% H2S, a non-aqueous drilling fluid would have to be formulated with an adequate concentration of H2S scavenger. Since the H2S scavenger SOURSCAV™ is water soluble in nature, solubilizing enough scavenger within the brine phase of the non-aqueous drilling fluid would require a significant change from the traditional fluid design. Finally, measuring any excess concentration of the active scavenger and ensuring that no free H2S was present within the drilling fluid were paramount to ensure a safe execution while drilling.

Solution

Halliburton Baroid’s customized fluid solution combined a 1.30sg BaraECD NAF system at 70/30 oil/water ratio (OWR) with a total of 8.5 kg/m3 of the H2S scavenger SOURSCAV. Ultra- fine grind (UFG) barite was also used, along with additional emulsifiers, to ensure enhanced stability during the prolonged wireline logging program at 150°C BHT. The low OWR and a low salinity of only 50,000 mg/L of CaCl2 allowed for the high concentration of 8.5 kg/m3 of water soluble SOURSCAV to be sufficiently solubilized into the brine phase. In addition to the H2S scavenger SOURSCAV, the fluid also included up to 20 kg/m3 of lime as a secondary barrier to help suppress H2S.

An extensive offshore testing program and procedure was developed, and two extra mud engineers were mobilized to the rig with the sole task of conducting hourly lab testing of SOURSCAV concentration and H2S content, which were monitored via a garret gas train (GGT). Mud engineers were brought onshore for training to ensure that all crew involved in lab testing were familiar with the specialized test protocol. In addition, all mud engineers underwent a pre-job presentation of the design of service (DoS) and execution plan before going offshore.

A total of 1,800m3 of 1.30sg BaraECD NAF containing 8.5 kg/m3 (3.0 lb/bbl) of SOURSCAV was mixed and made available at the rig site, using additional storage boats for convenient access to extra supply as needed.

Results

The well was delivered safely and according to plan, thanks to the innovative fluid formulation. The BaraECD NAF remained stable for a total of 5 days of wireline logging and stayed within the agreed upon specification. Samples taken from the reservoir showed that >2,000 ppm H2S was present in the reservoir fluids but no H2S was ever recorded at surface, demonstrating that SOURSCAV was effectively scavenging any H2S before it could reach surface. The frequent lab testing of SOURSCAV and H2S levels were successfully executed and results reported along with daily mud reports. No significant drop in SOURSCAV concentration or the presence of any H2S was detected throughout the whole well.

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