Schlumberger

Case Study: Monitoring Accurate Fluid Contacts in Fractured Carbonate with Lower Opex and Less HSE Exposure

Distributed temperature sensing (DTS) using WellWatcher BriteBlue HT fiber is accurate to within 1 m of gradiomanometer surveys, Oman

Challenge: Monitor gas, oil, and water levels in the fracture system of a carbonate formation regularly and cost-effectively to optimize steam injection and liquid offtake rates during thermal recovery of heavy oil.

Solution: Deploy WellWatcher BriteBlue HT high-temperature multimode DTS fiber to record the differential thermal relaxation in gas, oil, and water following a temperature perturbation.

Result: Accurately determined fluid contacts—with lower operating costs and lower HSE exposure—to within 1 m of wireline gradiomanometer surveys run for comparison, leading to deployment of the fiber in 14 observation wells in preparation for startup of the full-field thermal recovery process.

Optimally manage fracture oil rim position and thickness in carbonate formation

An operator uses thermally assisted gas-oil gravity drainage (TA-GOGD) to produce heavy oil from a highly fractured carbonate reservoir in Oman. Steam is injected into the fractures, generating a gas gradient across the carbonate reservoir so that the oil drops down by gravity. The steam also heats the reservoir so that the reduced-viscosity oil drips out faster. Reservoir pressure is kept low by using aquifer pumpoff wells, which maintains high steam quality and creates a large density contrast between the light gas and heavy oil for efficient gravity drainage.

Gas, oil, and water levels in the fractures and in the matrix are different. Oil extracted from the carbonate accumulates in the fracture oil rim, from where it is produced by wells intersecting the fractures. Reservoir surveillance needs to provide regular measurement of the various fluid levels in the fracture system, so that the oil rim position and thickness can be managed by adjusting the offtake rates of oil and aquifer water. With 14 observation wells, steam injection surface facilities, and downhole temperatures of 247 degC, frequent wireline gradiomanometer interventions were costly, impractical, and presented HSE exposure.

Use distributed temperature surveys to monitor fluid levels

Schlumberger proposed a novel deployment of WellWatcher BriteBlue HT high-temperature fiber to measure distributed temperature. An observation well was completed with open hole across the reservoir. A 1/2-in U-tube was clamped to the outside of predrilled tubing run in the hole; fluid levels inside and outside the tubing were at equilibrium with the fluid levels in the fractures. Inside the U-tube, a 3/16-in control line was placed containing the doubleended optical fiber in nitrogen gas.

A DTS measurement cannot indicate fluid levels if the fluids are at thermal equilibrium; therefore, a temperature perturbation that did not change the fluid levels had to be introduced. Water 10 degC cooler than the expected reservoir temperature was pumped through the annulus between the U-tube and the control line. The pumping continued until the temperature in the U-tube at reservoir depth fell to about 6 degC below that of the surrounding wellbore fluids. Immersed in nitrogen, the fiber was protected from both water (hydrogen exposure) and the mechanical strain caused by friction with a moving fluid.

Achieve accurate results with lower surveillance opex and minimized HSE exposure

With the pump stopped, the rate at which the cooler water inside the U-tube reached thermal equilibrium with the warmer wellbore fluids was measured via rapidly repeated distributed temperature surveys. This temperature recovery is known as thermal relaxation. Gas, oil, and water have very different specific heat capacities and thermal conductivities, so each surrounding fluid took a different amount of time to heat the water inside the U-tube. The differences caused sharp discontinuities on the initial temperature logs of the warming water at the depths of the fluid contacts. Real-time visualization software enabled quality control of data and provided approximate fluid contact depths. Further analysis was used to refine the results, leading to injection and pumpoff profile changes to optimize reservoir drainage.

The fluid contacts identified with this technique were within 1 m of the levels measured using gradiomanometer logs and are sufficiently accurate to manage the oil rim. The field trials were done in a “cold well.” Once the reservoir is heated, pumping cool water will create a larger temperature change in the U-tube, leading to longer relaxation times and more accurate measurements. Fourteen observation wells have been completed with this system in preparation for the startup of the full-field TA-GOGD process.


Download: Monitoring Accurate Fluid Contacts in Fractured Carbonate with Lower Opex and Less HSE Exposure (1.30 MB PDF)

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Fluid Levels Monitored Using DTS Measurements

Distributed temperature sensing (DTS) using WellWatcher BriteBlue HT fiber is accurate to within 1 m of gradiomanometer surveys, Oman
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