Brazil

Decrease cost and reduce risk through a collaborative approach

As your cost of doing business and drilling challenges continue to increase, we’re making significant infrastructure investments that are enabling us to work closer with your teams. Presalt reservoir challenges. Our purpose is enabling you to work with reduced HS&E and economic risk.

In the Campos Basin’s deepwater horizontal wells - is reducing completion time while simultaneously improving production rates.

Presalt
Our approach can help you optimize drilling production and reduce intervention in these substantially challenging plays.

Post-Salt
Our collaborative approach with the operator resulted in successful navigation with full reservoir coverage.

Our Solutions:

• Flow Assurance mitigation and remediation more
• Geologic “Static” modeling 
• Project Management more

Heavy Oil

Current challenges:

• Heavy oil is defined as those with API < 20. Is has low energy, low GOR and high viscosities at reservoir conditions, thus these characteristics of heavy oil make it hard to flow and produce as well as creating flow assurance challenge
• Heavy oil contains high amount of asphaltenes which can complicate production process
• For reservoir performance, heavy oil reservoirs tend to have low reservoir pressure, temperature and low productivity due to high viscosity. Therefore, EOR and well stimulation’s techniques should be implemented
• For production, multiphase flow modeling can be challenging which leads to development and flow assurance issues

Our Solutions:

• EOR (steam injection, chemical injection, and water injection)
• Stimulation (multilateral wellbores, inflow control devices)
• Fluid modeling
• Flow Assurance (Steam placements along the wellbore)

Shale Oil

Shale oil production also comes with large amounts of associated natural gas. Associated gas often does not have a commercial market. Some of it is flared but environmental regulations dictate that only a small portion can be burned off at the wellhead. The issue of associated gas is already emerging as a problem for shale players, particularly in North Dakota’s Bakken. Shale operators in the Bakken have started to shut down rigs and scale back well completions to avoid violating the state’s 85% gas-capture target. In the Permian, an estimated $1 million of gas is burned off every day because there aren’t enough pipelines to get it to market.

South East Asia

Reducing costs in ultra-deepwater will require technology development. It is important to focus on those technology's that will provide the biggest bang for the buck. System and value engineering processes have identified high impact technologies. Not surprisingly, subsea and downhole technologies offer greatest opportunities for increasing recovery, operability, and extending tieback distances.

Current challenges:

• Rapid sedimentation in young basin causes overpressured reservoirs. Overpressured reservoirs create challenges for formation evaluation, drilling, and completion.
• High temperature/high pressure reservoirs in some regions requires special approaches in development planning and HPHT tools.
• Some reservoirs are tight sand that might require horizontal drilling and fracking.

Our Solutions:

• Geologic “Static” modeling 
• HP/HT asset development (formation evaluation, HP/HT tools and equipment)

Increase recovery at lower cost applying total asset solutions

We have superior reservoir capabilities that enable us to offer total asset solutions, including well construction support, an improved production system, a revised field development plan, field management project, or enhanced oil recovery project. You can work more efficiently to improve job execution, leading to better production.

Decreased rig time through optimized reservoir completions 

An Australia operator needed to produce a deepwater field from an unconsolidated reservoir with a thin fluid column containing heavy viscous oil. Wellbore construction required innovative completion technologies including sand control, inflow control, and multiple laterals per well with hydraulic isolation at the junction.

We supplied reservoir-optimized recommendations for the 13-well development project; this included nine bilateral producers, a single lateral producer, and water-and-gas injection wells.  Completion equipment included EQUALIZER™ reservoir drainage system, fluid loss control valve, FLEX-LOCK™ liner hanger with ZXP™ liner hanger packer. The GT™ suspension bridge plugs enabled the operator to batch drill and complete the wells, which reduced OPEX with less NPT.

The reservoir-optimized completion exceeded the operator’s expectations with 37% more production and a nearly 30% higher productivity index.

Total asset solution through integrated approach Offshore East India, in a maximum depth of 4,600 ft [1,400 m], an operator needed a flexible, life-of-well deepwater completion that would isolate multizone unconsolidated formations. The objective included converting to an injector well later.

Working with the operator, we decided on an integrated reservoir-optimized completion with RE Packer™  wellbore isolation system and EQUALIZER™ reservoir drainage system. This enabled the required isolation without complicated setting procedures. Our integrated approach allowed a uniform production/injection profile without a costly deepwater cementing job. 

Tight Gas

Associated gas often does not have a commercial market. Some of it is flared but environmental regulations dictate that only a small portion can be burned off at the wellhead. The issue of associated gas is already emerging as a problem for shale players, particularly in North Dakota’s Bakken. Shale operators in the Bakken have started to shut down rigs and scale back well completions to avoid violating the state’s 85% gas-capture target. In the Permian, an estimated $1 million of gas is burned off every day because there aren’t enough pipelines to get it to market.