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Results
Avoiding Surface Collision and Drilling a Smooth Well Using Gyro-While-Drilling in Offshore Abu Dhabi/UAE
Day, Tim (Schlumberger) | Hormozy, Behzad (Schlumberger) | Khaled Al-Awadhi, Farhaad (ADNOC/CNPC) | Al-Husseiny Afifi, Hassan (ADMA-OPCO) | Abdul Karim, Hassan (ADMA-OPCO) | Abu Hasira, Mohamed (ADMA-OPCO) | Al-Ameri, Fahad (ADNOC)
Abstract Drilling wells from offshore platforms is always a challenge because of the need to eliminate potential collision issues caused by the relatively close spacing of wellheads. On a platform offshore Abu Dhabi, the spacing of the wells is 7.4 ft center-to-center and less than 5 ft wall-to-wall. There are nine slots on the tower, with five slots already used. Based on the required kickoff azimuth, the most logical slot for a high- profile deep and high temperature well was slot 9 (on the corner of the template) to reduce the risk of a well-to-well collision. However, using slot 9 would make it very challenging and risky to use slot 3 in the future. A detailed risk assessment was conducted, and the following risks were identified: 1. the motor producing an unknown amount of reactive torque while kicking off, could lead to a departure of the well from the plan and a collision with other wells or to block the empty slots. 2. Excessive dogleg at a shallow depth would incur high torque and drag in deeper sections, thus increasing the risk of string washout or twistoff and excessive casing wear. Also putting a higher loading on the top drive to drill the deeper sections. 3. Rig time would be taken for running the single-shot gyro. 4. As the circulation would have to be stopped to take the gyro single shot, there would be risk of hole packoff and stuck pipe. 5. There would be a long distance from the bit to the survey point if the single-shot gyro were run above Measurement-While-Drilling (MWD) tools, causing a "late reaction" to any deviation changes. After discussion, and a detailed cost / benefit analysis and risk assessment, it was decided to use a Gyro-While-Drilling (GWD) service as this would remove or significantly reduce the identified risks. This was the first usage of this service in the UAE for ADNOC companies (ADMA, ZADCO, ADCO), and the results were excellent. The well was kicked off in the correct direction from the start. There were no violations of the anti-collision rules to offset wells or empty slots. The well was steered away from slot 9, leaving it to be used for future wells. There was no reduction in the drilling parameters used to drill this 26″ hole section. There were no hole packoffs or stuck-pipe incidents, and the service saved at least 8 hours of rig time. Tight communication ensured all personnel involved had timely access to required information, which increased the confidence in decisions to drill ahead.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > UAE Government (0.36)
- Well Drilling > Well Planning > Trajectory design (1.00)
- Well Drilling > Drilling Operations (1.00)
Monitoring and Confirming Full Activation of Hole-Enlargement-While-Drilling (HEWD) Tool using MWD Real-Time Data. A process developed by the Operation Support Center.
Al-Saadi, Murad (Schlumberger D&M) | Khambete, Shreepad (Schlumberger D&M) | El-Masri, Hassan (Schlumberger D&M) | Day, Tim (Schlumberger D&M) | Al-Awadhi, Farhaad Khaled (ADNOC) | Al-Hussieny, H.. (ADMA) | Karim, Hassan Abdul (ADMA)
Abstract An operator in the Middle East planned to drill and perform a hole-enlargement-while-drilling (HEWD) operation in hard carbonate formations with an unconfined compressive strength (UCS) between 20,000 and 35,000 psi [138 to 241 MPa]. The main concern from the operator was ensuring that the hydraulic reamer was fully activated while drilling ahead. Downhole logging-while-drilling (LWD) tools that provide real-time caliper data cannot be run above the reamer because of the operational requirements of both the reamer and the LWD caliper tools. The reamer requires a small plastic ball to be dropped through the inside of the drillpipe to activate the reamer and, consequently, placing a real-time caliper tool above the reamer would prevent the ball from reaching the reamer. Additionally, such a configuration would prevent electrical signal communication between the LWD tool and the real-time data transmission available at the measurements-while-drilling (MWD) tool. Hence, it was not possible to use real-time LWD data to confirm the reamer activation, and an alternate method had to be developed. A new process was developed to monitor and confirm the full pad activation of the reamer. When the reamer is not activated, then 100% of the flow passes through the reamer, MWD tool, and drill bit. However, when the reamer is activated, then 20% to 30% of the flow is diverted through the HEWD tool to open the pads and cool and lubricate the cutters. The process ensures activation of the underreamer using the relation between MWD turbine RPM and flow. Alarms built into the monitoring software are triggered under certain conditions to alert the system operator to the expanded or retracted state of the underreamer. The operator can quickly check flow conditions and make adjustments to change the state of the underreamer. The process was used to perform a successful HEWD run with a BHA that included a rotary steerable system (RSS), MWD tool, an underreamer, and a 14.5-in. drill bit. The BHA delivered a high-quality in-gauge borehole and met all directional objectives, holding tangent at 19° inclination and 94° azimuth.
- Information Technology > Communications (1.00)
- Information Technology > Architecture > Real Time Systems (1.00)