HT Tool Overview
The latest generation of High Temperature tool was designed to conduct logging in harsh wellbore conditions with temperatures up to 305 degree C and with the presence of H2S. The tool includes gamma ray and casing collar locator (CCL) for depth correlation, temperature sensor, pressure sensors and conventional flowmeter (turbine spinner). The tool is available in real time mode.
- The surveys can be conducted in the steam injectors and geothermal wells in temperatures up to 305-degree C.
- The tool can provide wellbore steam injection profiles to understand which perforations are open intervals.
- The transient temperature survey in steam injectors can be conducted to obtain formation intake zones to understand unswept areas.
- The production profile for low temperature and dry steam geothermal wells can be recorded.
- The presence or absence of cement behind pipes will not affect the data quality.
The advantages listed above make this tool the most cost-effective steam injection and geothermal well profiling tool. The flow profile data can be used to determine the efficiency of injection and perforation performance.
PLT and Temperature Logging
The well is a vertical barefoot steam injector which was drilled in 2009. After drilling the well was completed with a 13 3/8” conductor, 9 5/8” surface casing and 7” intermediate casing. A 4.5” pre-drilled liner (PDL) was installed across the barefoot section. The steam was injected through vacuum insulated tubing (VIT).
A PLT was conducted in 2022 with the main objective to obtain the injected steam profile and distribution across the barefoot section. In addition, several relaxation temperature passes were recorded to understand the formation intake zones. The relaxation passes were recorded as follows: after 72 hours, 80 hours, 96 hours, 104 hours, 120 hours, 128 hours, 134 hours, and 144 hours of shut-in.
- The steam injection rate was calculated from the spinner data during the injection survey equaling 280 m3/d. The calculated injection steam rate is almost an exact match with the surface rate supplied from the steam generator at 300 m3/d.
- The two main intake zones in the PDL are 849-854 m and 862-865 m with an almost equal distribution between zones.
- The shape of the injection temperature curves indicated that the steam injection stops at 870 m.
- The relaxation temperature curves, recorded after 72-104 hours of shut-in were used for current formation steam distribution. These curves indicated the presence of two main intake formations at 855-861 m and 864-870 m where the upper zone is taking 45% of the total injected steam and the lower zone takes 55% of the injected steam.
- The relaxation temperature curves, recorded after 120-144 hours of shut-in, were used for historical steam distribution into the formation. The steam was accepted approximately within the same two intervals. However, the steam distribution is non-uniform: the majority of the steam goes into the upper part of the first interval and the lower part of the second interval.
- The relaxation temperature curves indicated that the steam heated the formation to 833 m. Above this depth the temperature curves showed a standard relaxation trend. It appeared that the shale layer at 831-833 m prevents the overlying formation from heating.
More case studies
PLT in Steam Injector
The well is a vertical barefoot steam injector which was drilled in 2009. After drilling the well was completed with a 13 3/8” conductor, 9 5/8” surface casing and 7” intermediate casing.
Combination of PLT and Acoustic Logging
A PLT is a common logging tool which provides flow profile inside the wellbore only. This type of tool cannot provide the formation flow profiles as well as crossflow above-between-below perforated intervals.
EMDs and MFC Combination 1
From previous case studies it is evident that in artificially lifted wells with either a bean pump (BP) or a progressive cavity pump (PCP) wear areas and associated corrosion are visible.
Temperature Monitoring in Steam Injectors
Integrity issues in steam injection wells can have unforeseen impact on adjacent production wells.
Crossflow Behind Pipes
Drilling a zone with losses can lead to poor cement quality or in severe cases a total absence of cement behind the casing resulting in free pipe.
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