First Oman Implementation of Pressurized Mud-Cap Drilling Improves Drilling Efficiency and Sustainability

2021 ◽  
Author(s):  
Cesar Orta ◽  
Mohanad Al Faqih ◽  
Bader Al Gharibi ◽  
Mohammed Al Shabibi ◽  
Ali El Khouly ◽  
...  
Keyword(s):  
Control Device ◽  
Total Loss ◽  
Managed Pressure Drilling ◽  
Drilling Technique ◽  
Drilling Technology ◽  
First Time

Abstract Drilling with a gas cap over the Natih formation in Oman often results in excessive flat time. Using the current dynamic fill equipment to deal with kick and loss scenarios leads to extensive nonproductive time on the rig. Managed pressure drilling (MPD) is a well-established drilling technology, and diverse variants exist to suit different requirements. All those variants use the rotating control device (RCD) as a common piece of equipment, but their procedures are different. The pressurized mud-cap drilling (PMCD) technique in the Natih formation replaces the need for traditional dynamic filling technology. The PMCD application enhances the drilling and completion processes by reducing flat time when total downhole losses are experienced. This paper elaborates on PMCD as a proven drilling technique in total loss scenarios when drilling with it for the first time in the Natih formation in Oman. It describes the PMCD process, the associated equipment, and the results of the inaugural application in the Qalah field.

Conductor Sharing Drilling Technique

2021 ◽  
Author(s):  
Emad Alabbasy Alabbasy ◽  
Ahmed Khamis Ahmed ◽  
Khalid Alwahedi Khaled ◽  
Abdulmohsen Al Marzooqi Abdulmohsen ◽  
Majid Hammadi Majid
Keyword(s):  
The Other ◽  
Offshore Drilling ◽  
Large Hole ◽  
Horizontal Drain ◽  
Drilling Technique ◽  
Planning Technique ◽  
First Time

Abstract With the objective to drill two wells shared from one conductor with independent wellhead and completion, ADNOC Offshore drilling team pioneered for the first time in Umm Lulu field and ADNOC UAE the Conductor sharing drilling technique. Which is to drill two wells from one single conductor in wellhead tower. Well planning technique drilling 42" hole and run 36" conductor, then install lower male connector and run conductor Down Hole Guide (DHG) assembly to be a guide for both two wells. Land the DHG on the lower male connector. Install upper male connector, which is equipped with two well slots for drilling the two wells. Drilling 1st 16" hole and run 13 3/8" casing and cemented. Skid over second slot and drill second hole 16" and run and cement 13 3/8" casing and carry out top up cement job for both hole up to surface inside 36" conductor. Install casing head housing for each well. Then each well could be drilled as per normal procedures. Well executing process. Well challenges: Drilling large hole 42" hole with 42" bit and BHA. Run 36" conductor and conductor sharing DHG and keep aligned for accessibility of BHA and casing Nudge 16" hole for both two wells at centre-to-centre distance 8" safely without collision issue. Run two 13 3/8" casing strings in 36" conductor and cement same up to surface. Complete drilling well UL-056 from slot A, drilled 12 ¼" hole section to TH-I ABS, run 9 5/8" casing and perform cement job to surface, drilled 6" hole (linerless design) and land in TH II then continued drilling horizontal drain to TD, Run completion and deliver the well. Suspend the other well in slot B at 13 3/8" casing with securing the well with abandonment cap and as per ADNOC offshore policy.

First MPD Project in Myanmar Successfully Completed on Deepwater Exploration Well

2021 ◽  
Author(s):  
Harpreet Kaur Dalgit Singh ◽  
Bao Ta Quoc ◽  
Benny Benny ◽  
Ching Shearn Ho
Keyword(s):  
Pore Pressure ◽  
Control Device ◽  
Back Pressure ◽  
Deepwater Drilling ◽  
Hole Pressure ◽  
Bottom Hole Pressure ◽  
Bottom Hole ◽  
Managed Pressure Drilling ◽  
Pore Pressure Prediction ◽  
Exploration Well

Abstract With the many challenges associated with Deepwater Drilling, Managed Pressure Drilling has proven to be a very useful tool to mitigate many hurdles. Client approached Managed Pressure Drilling technology to drill Myanmar's first MPD well on a Deepwater exploration well. The well was drilled with a Below Tension Ring-Slim Rotating Control Device (BTR-S RCD) and Automated MPD Choke System installed on semi-submersible rig, Noble Clyde Boudreaux (NCB). The paper will detail MPD objectives, application and well challenges, in conjunction with pore pressure prediction to manage the bottom hole pressure to drill to well total depth safely and efficiently. This exploration well was drilled from a water depth of 590m from a Semisubmersible rig required MPD application for its exploratory drilling due to uncertainties of drilling window which contained a sharp pressure ramp, with a history of well bore ballooning there was high potential to encounter gas in the riser. The Deepwater MPD package integrated with the rig system, offered a safer approach to overcome the challenges by enhanced influx monitoring and applying surface back pressure (SBP) to adjust bottom hole pressures as required. Additionally, modified pore pressure hunting method was incorporated to the drilling operation to allow more accurate pore pressure prediction, which was then applied to determine the required SBP in order to maintain the desired minimum overbalance while drilling ahead. The closed loop MPD circulating system allowed to divert returns from the well, through MPD flow spool into MPD distribution manifold and MPD automated choke manifold system to the shakers and rig mud gas separator (MGS). The automated MPD system allows control and adjustments of surface back pressure to control bottom hole pressure. MPD technology was applied with minimal overbalance on drilling and connections while monitoring on background gases. A refined pore pressure hunting method was introduced with manipulation of applied surface back pressure to define this exploration well pore pressure and drilling window. The applied MPD Deepwater technique proved for cost efficiency and rig days to allow two deeper casing setting depths and eliminating requirement to run contingency liners. MPD system and equipment is proving to be a requirement for Deepwater drilling for optimizing drilling efficiency. This paper will also capture detailed lesson learned from the operations as part of continuous learning for improvement on Deepwater MPD drilling.

Double-section, non-retrievable casing drilling technique

2012 ◽  
Vol 52 (1) ◽  
pp. 261
Author(s):  
Keith Won ◽  
Ming Zo Tan ◽  
I Made Budi Utamain
Keyword(s):  
Planning Process ◽  
Cost Savings ◽  
Polycrystalline Diamond ◽  
Drilling Process ◽  
Drilling Performance ◽  
First Case ◽  
Drilling Technique ◽  
Drilling Technology ◽  
Improved Design ◽  
Casing Drilling

With the continuous surging in daily rental rates of oilfield exploration rigs, Casing while Drilling technology—which provides operators with an alternative drilling solution for a reduction in drilling flat-time and increased drilling operation efficiency—has appeared to be a standard part of drilling engineers’ toolkit in the well-planning process. Significant cost savings generated by Casing while Drilling have contributed to this technique being widely deployed on top-hole string installations on exploration and appraisal wells in the southeast Asia region. The double-section casing drilling technique has gained increasing popularity among operators in recent years; however, this technique development has been hamstrung by limited casing bit selections. An improved design casing bit has been highly anticipated in the industry to reduce this technique’s complexity of drilling process. Finding an equilibrium between durability and drill-out capability features for a casing bit has been a major challenge for bit designers. The increasing prospect and demand for a double-section casing drilling technique, however, has yielded the development of the casing bit design to a wider portfolio, inclusive of a more robust PDC (polycrystalline diamond compact) cutter-based drillable casing bit. The introduction of the new robust but drillable PDC cutter-based casing bit has broadened the Casing while Drilling application. The double-section casing drilling technique without the need for an additional conventional clean-out trip has become a strong contender to be part of drilling engineers’ next toolkit in delivering enhanced drilling performance and increasing operational efficiencies. This paper will introduce the first case history of the successful planning and implementation of the double-section casing drilling technique—particularly emphasising its optimised drilling performance and ease of drill-out without the need for a specialised drill-out bit.

Successful Implementation of Managed Pressure Drilling Technology Under the Conditions of Catastrophic Mud Losses in the Kuyumbinskoe Field (Russian)

2019 ◽  
Author(s):  
Aydar Galimkhanov ◽  
Denis Okhotnikov ◽  
Leyb Ginzburg ◽  
Andrey Bakhtin ◽  
Yuliy Sidorov ◽  
...  
Keyword(s):  
Successful Implementation ◽  
Managed Pressure Drilling ◽  
Drilling Technology

Conventionally Undrillable Open Fractured Reservoir, Drilled Using Managed Pressure Drilling Technology

2011 ◽  
Author(s):  
Ibrahim Hammoudi ◽  
Khelil Kartobi ◽  
Hani H. Qutob ◽  
Maurizio Antonio Arnone ◽  
Fabian Torres ◽  
...  
Keyword(s):  
Fractured Reservoir ◽  
Managed Pressure Drilling ◽  
Drilling Technology

Successful Implementation of Managed Pressure Drilling Technology Under the Conditions of Catastrophic Mud Losses in the Kuyumbinskoe Field

2019 ◽  
Author(s):  
Aydar Galimkhanov ◽  
Denis Okhotnikov ◽  
Leyb Ginzburg ◽  
Andrey Bakhtin ◽  
Yuliy Sidorov ◽  
...  
Keyword(s):  
Successful Implementation ◽  
Managed Pressure Drilling ◽  
Drilling Technology

Using Managed Pressure Drilling Equipment to Troubleshoot Well Control Issues with Total Lost Circulation and Ballooning on A Semisubmersible Rig

2021 ◽  
Author(s):  
Harpreet Kaur Dalgit Singh ◽  
Ho Ching Shearn ◽  
Bao Ta Quoc ◽  
Dien Nguyen Van
Keyword(s):  
Control Device ◽  
Lost Circulation ◽  
Flow Monitoring ◽  
Operational Window ◽  
Managed Pressure Drilling ◽  
Coriolis Flowmeter ◽  
Open Hole ◽  
Bottom Hole Assembly ◽  
Bearing Assembly ◽  
Operating Window

Abstract When drilling from a deepwater semisubmersible rig, the operator encountered wells problems, including lost circulation, influxes, and ballooning, in the 14 3/4-in. hole section. Managed Pressure Drilling (MPD) equipment that helped to mitigate these issues specifically, when stripping in the hole with the bottom hole assembly through the Rotating Control Device (RCD) bearing assembly while managing surge and swab pressures, monitoring the well while displacing heavy mud into the open hole, conditioning the contaminated mud, removing gas from the well, and fingerprinting the flow back to verify ballooning against influxes, and finally stripping out of the hole. The operator experienced a total loss of circulation at the 16-in. liner shoe at 1,633m while drilling the 14 3/4-in. hole section. Several lost-circulation material (LCM) pills of different weights were pumped to cure the losses without success. Then the well was flow-checked, the gain was noted, and the well shut-in. Having the MPD chokes and the Coriolis flowmeter in place made it possible to adjust the surface back pressure (SBP) accordingly within a small operating window. As a result, the operator could achieve the key objectives of stripping the drillstring in the hole, stripping out of the hole, and rolling over to spot 1.88SG heavy mud on the bottom using the pump and pull method. After LCM was pumped and a hesitation squeeze performed, well operations were stabilized, and the casing was run to a 2,111m measured depth. Advanced flow monitoring enabled the MPD to determine the required SBP for balancing the well. MPD applied 60psi of SBP and noted a gain of 8.3bbl/hr from the flowmeter. Next, MPD applied 65psi SBP and the well was static. Then, MPD applied 70psi SBP, and the well took losses at a rate of 19bbl/hr. MPD allowed to successfully strip the BHA in the hole through the RCD bearing assembly to the shoe. Correct string displacement observed via the MPD Virtual Trip Tank, achieved by adjusting the SBP from 62psi to 125psi. The closed-loop circulating system enabled safely circulating and conditioning contaminated gas-cut mud in the hole back to homogeneous mud. MPD reduced SBP incrementally and fingerprinted flow back at every step to give assurance that well ballooning, and not influxes, caused the flow back. Dynamically adjusting SBP, coupled with advanced monitoring of the returns flow using the Coriolis flowmeter, enabled balancing the well despite the challenges of a mixed mud gradient in the annulus and a narrow operational window. The MPD riser consisted of an RCD below-tension-ring (BTR)-s, flow spool, and top and bottom crossovers. Rig modifications involved fabricating the fixed piping to allow integrating MPD equipment with the rig system.

Sign in / Sign up

Export Citation Format

Share Document