Comparison of Riser Gas Unloading in Water and SBM: Full-Scale Experiments

Kunju, Mahendra R; Almeida, Mauricio

doi:10.2118/213195-ms

Cited by 3 publications

References 26 publications

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Is Handling Gas in the Riser a Safe Alternative? Exploring the Limits and Opportunities for Safer Kick Handling During Deepwater Drilling

Gabaldon,

Humphreys,

Teixeira

et al. 2023

Day 2 Wed, October 04, 2023

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This work complements previous efforts exploring the opportunity for safer return to operations after an influx event in deepwater drilling operations when an MPD system is installed on the floating rig. Additionally, even kicks taken during conventional drilling, with rigs equipped with adequate RGH equipment, can benefit from an alternative way to address the event. An RGH Envelope is proposed, which can be incrementally adopted in a stepwise approach. For MPD operations, influxes greater than IME circulation limits, but within RGH Envelope limits, can be introduced into the riser and then removed using the Fixed Choke, Constant Output (FCCO) method. In non-MPD operations, all influxes need to be initially addressed by shutting the well on the BOP as soon as possible. Then, for influxes within the equivalent MPD IME limits, the surface RGH system can be engaged and routed to the rig choke, and the influx is completely circulated using Driller's method through the riser system. A potential expansion of this method, for influxes exceeding the original IME limits, but within RGH Envelope limits, can be circulated into the riser and then finalized by using FCCO method. For conventional drilling operations without a rotating control device (RCD) seal installed, consideration should be given to installing the seal assembly in the RCD prior to circulating hydrocarbons to surface with an open BOP. The authors explore the RGH Envelope limits and present guidelines for a comprehensive risk assessment on RGH process, limits, and how it impacts multiple aspects of the operations.

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Is Handling Gas in the Riser a Safe Alternative? Exploring the Limits and Opportunities for Safer Kick Handling During Deepwater Drilling

Gabaldon,

Humphreys,

Teixeira

et al. 2023

Day 2 Wed, October 04, 2023

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Fixed Choke Constant Outflow Circulation Method for Riser Gas Handling: Full-Scale Tests in Water- and Synthetic-Based Mud with Gauges and Distributed Fiber-Optic Sensors

et al. 2023

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Summary Conventional methods of managing gas-in-riser events are not optimal when the drilling riser is isolated from the formation by a closed subsea blowout preventer (BOP) on rigs equipped with mud gas separator (MGS), managed pressure drilling (MPD), or riser gas-handling equipment. The industry is concerned about exceeding the pressure limit of the riser and the flow capacity of the MGS and hence has not been able to reach a consensus on a circulation method for riser gas. This work is an analysis of the first-ever demonstration of the fixed-choke constant-outflow (FCCO) circulation method in synthetic-based mud (SBM) carried out in June 2022. The first-ever demonstration of the FCCO circulation method in water was performed in March 2021. The results from the water tests were discussed in IADC Gas-in-Riser/Riser Gas-Handling Subcommittee meetings, and the new fixed-choke method was named FCCO in November of 2021. The reason for using the acronym FCCO for the new method is that it allows the use of a fixed-choke opening percentage throughout the circulation period by managing the outflow and backpressure by varying only the pump rate. This work includes the comparison of the actual test results from the March 2021 FCCO tests in water with results estimated using a new model. This is followed by a discussion of the results from the June 2022 FCCO test in SBM. Nitrogen gas was injected into the bottom of an annulus 5,200-ft deep, vertical test well (9 5/8×2 7/8 in. casing/tubing) initially filled with water and instrumented with four downhole pressue and temperature gauges, and distributed fiber-optic sensors [distributed temperature sensing (DTS) and distributed acoustic sensing (DAS)] for water tests, and later filled with SBM. We started direct circulation to produce flow out of the annulus through a choke kept at a fixed open position (%) required for a preplanned applied surface backpressure (ASBP). We reduced pump rate if/as necessary to maintain this ASBP to ensure outflow rate within MGS flow capacity. We performed tests at different fixed-choke positions, different average ASBPs, and initial pump rates. We tested constant bottomhole pressure (CBHP) circulation and fixed pump rate methods also for comparison with the FCCO circulation method. The results from the FCCO tests demonstrated better control of outflow compared with the other methods. There is no need to use high ASBP. The use of a high ASBP suppressed the value of peak pressure. Installation of more than one gauge inside the riser enhances safety by allowing real-time influx detection capability, estimation of gas position, gas velocity, and gas void fraction. The FCCO method can be preplanned and easily substituted as the preferred circulation method for staying within the handling capacity of the existing MGS on the rig during gas-in-riser situations.

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Comparison of Gas Signature and Void Fraction in Water- and Oil-Based Muds Using Fiber-Optic Distributed Acoustic Sensor, Distributed Temperature Sensor, and Distributed Strain Sensor

Adeyemi,

Wei,

Sharma

et al. 2024

SPE Journal

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Summary Accurate estimation and prediction of gas rise velocity, length of the gas influx region, and void fraction are important for optimal gas kick removal, riser gas management, and well control planning. These parameters are also essential in monitoring and characterization of multiphase flow. However, gas dynamics in non-Newtonian fluids, such as drilling mud, which is essential for gas influx control, are poorly understood due to the inability to create full-scale annular flow conditions that approximate the conditions observed in the field. This results in a lack of understanding and poor prediction of gas kick behavior in the field. To bridge this gap, we use distributed fiber-optic sensors (DFOS) for real-time estimation of gas rise velocity, void fraction, and influx length in water and oil-based mud (OBM) at the well scale. DFOS can overcome a major limitation of downhole gauges and logging tools by enabling the in-situ monitoring of dynamic events simultaneously across the entire wellbore. This study is the first well-scale deployment of distributed acoustic sensor (DAS), distributed temperature sensor (DTS), and distributed strain sensor (DSS) for investigation of gas behavior in water and OBM. Gas void fraction, migration velocities, and gas influx lengths were analyzed across a 5,163-ft-deep wellbore for multiphase experiments conducted with nitrogen in water and nitrogen in synthetic-based mud, at similar operating conditions. An improved transient drift flux–based numerical model was developed to simulate the experimental processes and understand the gas dynamics in different wellbore fluid environments. The gas velocities, void fractions, and gas influx lengths estimated independently using DAS, DTS, and DSS showed good agreement with the simulation results, as well as the downhole gauge analysis.

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Comparison of Riser Gas Unloading in Water and SBM: Full-Scale Experiments

Cited by 3 publications

References 26 publications

Is Handling Gas in the Riser a Safe Alternative? Exploring the Limits and Opportunities for Safer Kick Handling During Deepwater Drilling

Is Handling Gas in the Riser a Safe Alternative? Exploring the Limits and Opportunities for Safer Kick Handling During Deepwater Drilling

Fixed Choke Constant Outflow Circulation Method for Riser Gas Handling: Full-Scale Tests in Water- and Synthetic-Based Mud with Gauges and Distributed Fiber-Optic Sensors

Comparison of Gas Signature and Void Fraction in Water- and Oil-Based Muds Using Fiber-Optic Distributed Acoustic Sensor, Distributed Temperature Sensor, and Distributed Strain Sensor

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