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Results
Successful Deepwater MPD Application in Drilling and Cementing Through Depleted Formation with Wellbore Instability and Loss Circulation Challenge Offshore of Sabah
Benny, B. (Managed Pressure Drilling, Weatherford Asia Pacific, Kuala Lumpur, Malaysia) | Tan, J. (Managed Pressure Drilling, Weatherford Asia Pacific, Kuala Lumpur, Malaysia) | See, J. (Managed Pressure Drilling, Weatherford Asia Pacific, Kuala Lumpur, Malaysia) | Foo, J. (Managed Pressure Drilling, Weatherford Asia Pacific, Kuala Lumpur, Malaysia) | Othman, F. (Sarawak Shell Berhad, Sarawak, Malaysia) | Mathew, M. (Sarawak Shell Berhad, Sarawak, Malaysia)
Abstract Managed Pressure Drilling (MPD) has become the essential drilling technique to drill problematic zones in these past decades due to its ability to precisely manipulate downhole equivalent mud weight (EMW). This ability empowers the operator to save time and cost when drilling through loss zone with lower drilling fluid and at the same time, able to retain EMW above the wellbore instability or, if required, pore pressure gradient. This paper describes the crucial role of MPD in a drilling operation on a horizontal deep water oil producer well in Sabah region, offshore of East Malaysia, to help the Operator recover from Wellbore Instability and Loss Circulation issues and successfully drill and cement the problematic section. The main challenge of the well is the tight drilling window between depleted sand formation and the interlayered shale formation. Therefore, the MPD Integrated Riser Joint (IRJ) was deployed along with the riser string prior drilling 12.25 in hole section. Initially, the section was drilled conventionally with wellbore strengthening techniques, only to encounter unmanageable static losses. After multiple unsuccessful attempts to cure losses, the section was cement plugged to sidetrack the well. Considering the substantial challenges encountered, the well was sidetracked with lighter drilling fluid and applied surface back pressure (SBP) to maintain its bottom hole pressure above the wellbore instability gradient and below the fracture gradient. After the well had reached target depth, the drilling assembly was pulled out of hole in MPD mode without having to displace the well to heavier tripping mud and, once it was above the Subsea Blowout Preventor (SSBOP), the well was then isolated with blind shear rams (BSR). To continue maintaining SBP below the BSR, the MPD system was lined up on a surface loop circulation in such a way that the SBP was applied to the well via kill line. With the casing string delivered to the bottom, Managed Pressure Cementing (MPC) was utilized to cement the casing by having a schedule of SBP against pumped strokes that was formulated by software simulation to give a minimum pressure surge when the cement slurry entered the open hole. In addition, the paper also describes the equipment setup required onboard a drillship for drilling with MPD in a deep-water setting. The MPD setup enables the application of advanced flow detection system and riser gas handling which are critical in drilling deep water wells. With all these features, MPD Deepwater application has successfully delivered the well to target depth which once was undrillable.
- Asia > Malaysia (0.34)
- North America > United States (0.28)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.54)
- Geology > Geological Subdiscipline > Geomechanics (0.54)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- (2 more...)
A Case History - The First Successful Managed Pressure Cementing Operation in Over-Pressure and Narrow Drilling Window Environment Using Swamp Barge Drilling Rig, Indonesia
Yasmin, Kharisma Asri (Weatherford) | Zein, Joydi Mirza (Weatherford) | Lubis, Defry Erwinsyah Umra (Weatherford) | Prasthio, Andry (Weatherford) | Faradilah, Ariyati (Weatherford)
Abstract The case presented in this paper is an HPHT exploratory well in East Borneo. This well was designed to drill a potential gas reservoir using MPD system to encounter the narrow operational window formation. An unexpected high pore pressure increase was detected while drilling the 8.5-inch hole section, resulting in a tighter window. The pore pressure below 9-5/8-inch casing shoe was measured to be 2.18 SG, up from 2.09 SG preliminary expectation. Because of this condition, it was decided to call in TD earlier and cement the open hole section using managed pressure cementing. Conventional cement operation wasn't viable due to the required mud weight increment and the resulting equivalent circulating density with 7-inch liner at the bottom, which limited the likelihood of success. Cement slurry and spacer must be designed to stay within the pressure window during static and dynamic conditions. Initially, the use of high-strength, low-density slurry weighted was also contemplated. However, because to the additional time and specialized needs for this cement-slurry combination, the idea was canceled. The decision was subsequently made to use MPC to maximize the likelihood of successfully installing a barrier through the 7-inch liner shoe. Managed pressure cementing occasionally implemented in specific drilling conditions. Nowadays, this technique has been more frequently applied in most MPD operations. Despite its unconventional condition, exerting SBP while cementing operation guarantees cementing improvement behind each casing. During the engineering and planning phase, the target ECD for cementing was established by discussions and reviews with all service companies involved. The anchor point used was defined at 9-5/8-inch shoe depth which was suitable to avoid undesired wellbore-fluid influxes and losses. The anchor point is a set depth in an open hole where ECD values are maintained constant using the MPD choke to produce overbalanced circumstances without exceeding the fracture gradient. Before executing cement operation, a dynamic formation integrity test (DFIT) needs to be conducted in order to identify and confirm the strength of the shoe at any open hole depth. DFIT is essential to confirm the anticipated pressure that can be applied to the formation. During implementation, the final surface backpressure schedule was fine-tuned after DFIT and using the MPD software which is completed with its delicate control system, as the primary operational reference. Because of the narrow operational window, the 7-inch liner was run in managed pressure mode, controlling the stripping speed and adjusting SBP increment using the MPD system choke control to maintain the ECD. This paper describes the detailed engineering and MPD application from conceptual, preparation, and execution, along with its results and lessons learned. This manuscript elaborates the first successful MPC operation deployed with Swamp Barge Rig, which enabled liner cementing at narrow pressure windows efficiently and time-saving for the the operator.
- North America > United States (0.69)
- Asia > Indonesia (0.51)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Casing and Cementing (1.00)
Abstract While wellbore strengthening techniques have been proven successful in strengthening weak permeable zones to achieve higher fracture gradients, the extent of their effectiveness is variable. This paper discusses an integrated approach where Managed Pressure Drilling (MPD) is incorporated and designed in conjunction with wellbore strengthening strategies to drill wells with formation strength below borehole stability requirements, thus allowing fail-safe outcomes from depleted drilling and completion operations, ultimately reducing the consequence of failure, and simplifying recovery efforts. There are two main benefits of incorporating MPD. First, MPD enables a reduction in the required drilling margin, and this in turn prevents an over-reliance on the effectiveness of wellbore strengthening strategies. Second, MPD provides the ability to reduce downhole pressure, reducing the consequences of unexpected loss circulation events. Mud weight selection was carefully engineered with several factors taken into consideration, including shale inhibition, impact on completion operations, and consequence of MPD system failure. Eight hole sections across four deep-water subsea wells were initially designed to be drilled with wellbore strengthening strategies alone, however, a loss circulation event led to challenging remediation and recovery efforts. Upon incorporating this MPD design, while seven other hole sections were drilled successfully without any loss circulation events, one hole section encountered loss circulation, and this design allowed an instant reduction in surface back pressure to stop the losses, effectively "failing safely". Four lower completion operations were also successfully executed with this design incorporated.
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- (3 more...)
Reservoir Characterization in Transient Wellbore Conditions Resulting from Unintended Hydraulic Fracture Communications Utilizing MPD
Kvalo P. E., M. (Stasis Drilling Solutions, Houston, Texas, United States of America) | Duarte, M. (Stasis Drilling Solutions, Houston, Texas, United States of America) | Vargas, N. (Stasis Drilling Solutions, Houston, Texas, United States of America) | Laird, E. (Stasis Drilling Solutions, Houston, Texas, United States of America) | Sullins, T. (Comstock Resources, Frisco, Texas, United States of America) | Boddy, T. (Comstock Resources, Frisco, Texas, United States of America) | Janes, C. (Comstock Resources, Frisco, Texas, United States of America)
Abstract MPD for reservoir characterization in green field applications is often seen as vital for providing operators with valuable information about the reservoir's physical properties while drilling. This aspect of Managed Pressure Drilling (MPD) in mature fields is not often a driver for implementation as these characteristics are typically well-defined. However, external factors such as unintentional communication between drilling and fracking operations can significantly alter known reservoir characteristics. The proppant exponentially enhances the permeability of both the child and parent well. While the fracturing fluid initially increases the pore pressure and stress environment in the near wellbore region, followed by its subsequent reduction, the rate of which is dependent on the dominant regime: flow back on the parent well, pressure equalization of the reservoir, and/or diffusion of fluid into the drilling mud. The challenges and interactions associated with unintended frac communication and how primary reservoir characteristics are fundamentally altered as a result will be discussed. Additionally, the results of each reservoir characterization test can be interpreted to adjust the plan forward and utilized to navigate these transient wellbore conditions. Thus, providing clear insight into the wellbore's evolving drilling window, enabling the safe drilling and completion of the "fracked into" well.
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > South Dakota > Williston Basin (0.99)
- North America > United States > North Dakota > Williston Basin (0.99)
- (3 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- (6 more...)
Abstract Narrow pore/stability pressure and fracture pressure margins (narrow operating window) can create severe complications during drilling operations. A slight change in the bottom hole pressure conditions can lead to significant Non-Productive Time (NPT) events like stuck pipe, fluid influx or lost circulation. In many cases, long wells with a narrow gap between pore/stability pressure and fracture pressure are impossible to drill with conventional practices because the annular friction pressure losses (difference between the dynamic and static pressure) are larger than the pore/fracture margin (Arnone & Vieira, 2009). Managed Pressure Drilling (MPD) enables operators to carefully balance between the pore and fracture pressure gradient by counteracting the lack of annular pressure losses (APL) when not circulating with the application of surface back pressure (SBP). MPD has the capability of providing a nearly constant bottomhole pressure with the proper compensation of pressure changes at surface. An accurate and real time determination of change in bottom hole pressure from dynamic effects is necessary to apply the correct SBP. This work investigates the accuracy of a novel approach in real-time MPD hydraulics modelling, which provides an alternative solution to the Pressure-While-Drilling (PWD) tool that measures the downhole annular pressure while drilling. The real-time hydraulics modelling proved to be accurate and allow for adjustments to be continuously made towards optimizing drilling efficiency, reliability, and safety without additional downhole tools.
- North America > United States > Texas (1.00)
- North America > United States > New Mexico (0.72)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (28 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- (3 more...)
Multi-Stage Heavy Pill Displacement Using Managed Pressure Tripping Technique in High Pressure-High Temperature Well with Narrow Drilling Margin - A Case Study in Haynesville Shale
Aliyev, Fuad (OPLA Energy) | Yousefi Sadat, Ali (OPLA Energy) | Cody, Shawn (OPLA Energy) | Huggard, Brad (Aethon Energy) | Dametz, Sebastian (Aethon Energy)
Abstract The narrow drilling window of a High Pressure-High Temperature (HPHT) formation creates challenges in managing bottom hole pressure (BHP) during drilling and tripping operations. Managed Pressure Drilling (MPD) techniques have proven effective in accurately controlling downhole pressure, especially in HPHT environments. This study evaluates the capability of automated Managed Pressure Tripping (MPT) techniques in the Haynesville shale gas. The results show that this approach effectively controls the BHP while tripping, resulting in significantly improved operational efficiency, cost, and safety. MPD hydraulics are developed primarily based on the well profile, mud properties, and drill string dimensions. It uses analytical formulation to compute annular pressure losses along the wellbore every second. Subsequently, the required mud volume, pumping schedule, and applicable surface back pressures (SBP) for the displacement of the heavy pill are simulated to accurately follow the narrow drilling margin. This technique is provided to the field as guidance, and the heavy pill is displaced in multiple stages while maintaining constant bottom-hole pressure through MPD. This method is fully automated, given accurate drilling parameters, and can be controlled remotely from a remote operations center (ROC). Drilling the deepest HPHT Haynesville wells with a narrow drilling window was successful by using MPD techniques with a mud weight of 16.0 ppg. The pore pressure / stability limit of 17.0 ppg was less than 2% of the formation integrity test (FIT) limit of 17.3 ppg. The MPD hydraulics simulator enables real-time BHP calculations, coupled with a pre-engineered mud schedule, which improves overall tripping efficiency. The heavy pill was displaced in multiple stages during casing and drilling BHA runs based on FIT results. This method resulted in smooth tripping procedures with no reported wellbore stability issues or fluid loss concerns. In comparison to conventional tripping, managing adequate SBP along with a mud pumping schedule allows tripping execution within such a narrow margin. There were no reported observations of wellbore stability issues nor any significant fluid loss concerns. In this case study, the well was drilled to a total depth of 24,100ft MD, and the production casing was successfully run to the planned depth using a multi-stage displacement technique.
- North America > United States > Texas (1.00)
- North America > United States > Louisiana (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Gas Play (0.63)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.63)
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Formation (0.99)
- (47 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- (3 more...)
- Information Technology > Communications > Collaboration (0.55)
- Information Technology > Architecture > Real Time Systems (0.36)
Abstract While drilling the 12" section, a water bearing formation is encountered prior to reaching the target gas reservoir formation. This formation is sporadically-charged across the field requiring a KMW up to 21 ppg. This poses major well integrity challenges as it becomes critical to avoid losses in the resulting narrow mud window and ensuring proper cement placement. Inability to predict the mud window makes it impossible to define the drilling strategy to implement. To understand the drilling challenges, in-depth offset wells analysis was performed. Based on mud weights required to drill across the reference formation, the heat-map for historical KMW was created based on confirmed well control events. It was difficult to predict formation-flow potential. Field geomechanics studies were then carried out to correlate the mapping done earlier. Once possibility of encountering abnormally pressured formation is flagged, in order prevent drilling risks such as loss circulation and poor cementing placement, proactive measures such as: Improved influx monitoring, drilling/cementing fluids optimization, liner-and-tieback system implementation, Managed Pressure Drilling/Cementing, optimized casing design were put in place. The integrated approach led to quick influx detection, proper definition of mud window, i.e. Pore Pressure and Fracture Gradient together, helped to prevent the losses, design of fit-for-purpose bridging strategy to ensure full drilling fluid column at all time while avoiding the cost associated with fluid losses. Drilling the section with Managed Pressure Drilling system (MPD) and low mud weight led to achievement of high ROP leading to substantial time saving. The Liner string was run and Managed Pressure Cementing (MPC) was implemented to manage the equivalent circulating density (ECD), avoid losses and ensure good zonal isolation. Overall non-productive time was reduced by 40% as compared to the offset wells in the area. Integrated drilling approach delivers great gains when there is good understanding of the well integrity challenges and solutions are tailored to solve identified problems.
- North America > United States (0.95)
- Europe > Norway > Norwegian Sea (0.66)
- North America > Canada > Alberta > Woodlands County (0.40)
- Asia > Middle East > Saudi Arabia > Eastern Province (0.28)
- Asia > Middle East > Bahrain > Awali Field (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Tengiz Formation (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Korolev Formation (0.99)
- Asia > Middle East > Israel > Southern District > Southern Levant Basin > Efe Field (0.97)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- (3 more...)
An Evaluation of Pressure Control Methods During Riser Gas Handling with MPD Equipment Based on Transient Multiphase Flow Modeling and Distributed Fiber Optic Sensing
Wei, Chen (Louisiana State University) | Chen, Yuanhang (Louisiana State University) | Santos, Otto (Louisiana State University) | Kunju, Mahendra (Louisiana State University) | Mahmud, Shahriar (Louisiana State University) | Almeida, Mauricio (Louisiana State University) | Sonnemann, Paul (SafeKick)
Abstract During the past decade, the increased use of Managed Pressure Drilling (MPD) equipment has significantly improved the safety and efficiency of gas influx management. However, it is still not clear to the industry what should be the safest and most effective pressure control method for removing gas influxes out of a riser. The objective of this study is to perform a systematic evaluation of different pressure control methods for riser gas handling, including the constant surface backpressure method, the constant riser bottom pressure method, and the fixed choke and constant outflow method. A transient multiphase flow simulator based on a Drift Flux Model was developed to simulate riser gas handling events in a Water Based Mud (WBM) system. Multiple sets of full-scale experimental data were used for the calibration and validation of the simulator. In the full-scale experiments, riser gas events were simulated by injecting gas into the bottom of an experimental well, followed by applying different pressure control methods. Besides conventional downhole and surface pressure and flow measurement instrumentations, a Distributed Fiber Optic Sensing (DFOS) system was used for the high-resolution monitoring of gas influxes in the annulus. The performance of different pressure control methods was evaluated based on the simulation results, including the behaviors of surface and riser bottom pressures, peak surface outflow rates, and the time required for riser gas handling. The numerical simulations carried out in this study can help better understand the different pressure control methods and improve the design of riser gas handling strategies.
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Reservoir Description and Dynamics (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Abstract The strategic location of the Haynesville unconventional dry-gas shale, near some of the world largest petrochemical complexes, export facilities, and in proximity with the Gulf of Mexico makes it one of the most revenue attractive plays in the USA. However, with wellhead pressures in excess of 9,000 psi and bottom hole temperatures reaching 380°F, this deep shale is classified as a challenging dry-gas high pressure-high temperature basin. The conservative and conventional approach of using extremely high mud density to deal with pressure uncertainties and possible dry gas entering the annulus while drilling, making connections, or tripping combined with the high temperature detrimental effect over the drilling fluid properties, have made the operators incur time consuming activities during the well construction process in this area. After 4 years and 2 million feet of long reach horizontal production hole sections successfully drilled with MPD in this HPHT Texas-Louisiana shared unconventional gas play, our experiences after strategically developing and utilizing a state of the art precise, fast, and reliable-low maintenance electric set point choke in combination with reduced equipment footprint and crew on a setup to comply with easy mobilization for the rig to fit on the cost-efficiencies improvement plans from operators and rig contractors in the area are described on this document.
- North America > United States > Texas (1.00)
- North America > United States > Louisiana (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.55)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- (5 more...)
Perforating Using MPD Techniques: Design and Execution
Fernandes, André Alonso (Petrobras) | Ferreira, Davi Valle (Petrobras) | Schnitzler, Eduardo (Petrobras) | de Castro, Fabiano Hamilton (Petrobras) | do Carmo, Isadora Luisa de Paiva Goncalves (Petrobras) | Santana, Pedro Menezes (Petrobras) | Roman, Roger Savoldi (Petrobras)
Abstract An appraisal well was drilled in Brazilian pre-salt area using overbalance drilling fluid, with conventional techniques. While drilling reservoir (in a 12 1/4" phase), total losses were found. Unsuccessful attempts with LCM and cement pills revealed that only MPD/PMCD techniques could deliver the well to TD. It was decided to anticipate the installation of the 9 5/8" casing, covering only the upper portion of the reservoir, and well was suspended. The remaining reservoir could be drilled later with a rig equipped with MPD system. This well was designed as a 2-zones intelligent completion in cased hole configuration. Due to the fluid losses a new design had to be considered. Due to reservoir uncertainties, definition on the separation between zones would only be taken after drilling the remaining reservoir section. To overcome this challenge without adding time and complexity to the overall design, the best solution was to perforate the cased hole section after drilling the remaining section, meaning doing it with reservoir communicated to the wellbore and in PMCD mode. Several options were evaluated to design the TCP operation in PMCD. Well control strategies, contingencies, thermal effects, and dynamic shocks were considered. The solution consisted in running the TCP with a closed string, without NRVs and having robust contingencies in case of washout or drillpipe failure after perforating. The well was drilled, and total fluid losses occurred again. It was then successfully perforated still in PMCD, then lower and upper completion were installed. Despite these challenges, this was the fastest intelligent completion in all Petrobras pre-salt fields so far.
- South America > Brazil (1.00)
- North America > United States > Louisiana (0.24)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- (2 more...)