Best Practices and Lessons Learned on the Application of Managed Pressure Drilling MPD Technology For High Pressure High Temperature HPHT Wells in Vietnam

Quoc, Bao Ta; Yong, Tan; Singh, Harpreet Kaur Dalgit; Nguyen, Vi Pham; Minh, Ho Chi

doi:10.2118/180637-ms

Day 3 Wed, August 24, 2016 2016

DOI: 10.2118/180637-ms

|View full text |Cite

Best Practices and Lessons Learned on the Application of Managed Pressure Drilling MPD Technology For High Pressure High Temperature HPHT Wells in Vietnam

Bao Ta Quoc

Tan Yong

Harpreet Kaur Dalgit Singh

et al.

Abstract: With the surmounting call of cost cutting measures within the oil and gas industry, it is of paramount importance to examine and evaluate the drilling activities during the course of the application of Managed Pressure Drilling (MPD) technique for High Pressure High Temperature (HPHT) wells globally. The cost reduction has also affected wells drilled in Vietnam. One common discussion amongst operators to decide on MPD system installation for a drilling campaign is the significant upfront cost as… Show more

Help me understand this report

Search citation statements

Order By: Relevance

Paper Sections

Select...

Citation Types

Supporting

Mentioning

Contrasting

Year Published

2017

2023

Publication Types

Select...

Other2

Relationship

Self Cite0

Independent2

Authors

Journals

Cited by 2 publications

References 2 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

Hydrostatically Underbalanced Managed Pressure Cementing Enables Zonal Isolation in Narrow-Margin HPHT Exploration Well

Lau

Prasetia

Long

et al. 2017

Day 2 Wed, October 18, 2017

View full text Add to dashboard Cite

As more and more HPHT & DW wells are drilled to explore or exploit reservoirs with narrow pore pressure (PP) / fracture gradient (FG) windows, the luxury of maintaining significant hydrostatic overbalance during the drilling and cementing operations or of being able to maintain hydrostatic overbalance at all, is being challenged. Managed Pressure Cementing (MPC) is relatively a new cementing technique using Managed Pressure Drilling (MPD) equipment and processes allows the wellbore to be displaced with a hydrostatically underbalanced mud after landing the liner string, then cement with a hydrostatically underbalanced spacer & cement slurry while applying dynamically controlled surface back pressure through MPD set up. MPC was the chosen approach to mitigate the risks when cementing the 9-7/8in liner in a hydrostatically underbalanced condition and applying surface backpressure (SBP) using an automated MPD system to bottom hole pressure between the highest pore pressure and the lowest fracture pressure of the well. To run the 9-7/8in liner, it was determined by simulation that three (3) step mud circulations were required at 1650m, 2280m and 2909m to change the MW from 17.0ppg to 15.2ppg despite the Pore Pressure is 16.68ppg at 2909m. A SBP as high as (850 psi) is applied to maintain the ECD within the operating window for liner circulation with roll over mud and subsequent cementing operation. When cementing the 9-7/8in liner the density of all the fluids were designed at 15.2 ppg to minimize the ECD downhole. Hence, the variation in ECD is solely attributed to the frictional pressures, which inevitably makes the rheology hierarchy play a greater role for an efficient mud removal. Application of comprehensively engineered cementing and MPD techniques resulted in flawless cementation result. No losses or any gain were observed, zero gas migration, and liner top isolation packer was successfully pressure tested and inflow tested. The successful use of MPC in a HPHT exploration well located in offshore Malaysia and drilled by a jack up rig, has delivered significant value to the project and Malaysian cementing experience in general, providing confidence for further applications of this technique and technology. MPC has become the primary technology enabler for efficaciously delivering such challenging well to its planned total depth without compromising the well design and integrity. The progressive method presents to be a safe and technically viable process, enabling the well to be drilled, cased and cemented which would otherwise not be feasible by conventional methods. This has secured the future development prospect of the field by demonstrating the capability to perform drilling to deeper reservoir targets and cementing within a narrow operating windows. The triumph of MPC is dictated by strenuous pre-operation design process, detailed risk assessment with multiparty mitigation plan and communication resulting in an accurate modeling, operational execution thus ultimately, a successful cement barrier. The key aspect is adherence to conventional HPHT cement job design best practices with specific focus on achieving good rheology hierarchy between the fluids pumped downhole to ensure good mud removal hinged around comprehensive and vital computer modeling of ECD envelope with the correct inputs.

show abstract

Hydrostatically Underbalanced Managed Pressure Cementing Enables Zonal Isolation in Narrow-Margin HPHT Exploration Well

Lau

Prasetia

Long

et al. 2017

Day 2 Wed, October 18, 2017

View full text Add to dashboard Cite

show abstract

The Integration of Geomechanics and Reservoir Modeling for Hydraulic Fracturing and Well Spacing Optimization in the Third Bone Spring Sand of the Delaware Basin

Bui,

Nguyen,

Nguyen

et al. 2023

Day 2 Wed, October 04, 2023

View full text Add to dashboard Cite

This paper aims to apply a numerical reservoir simulation incorporating geomechanical properties to determine the optimal well spacing, the number of hydraulic fracture stages per well, and the best timeframe to fracture the infill or child well in the Third Bone Spring Sand of the Delaware Basin. The field data of a multistage fractured horizontal parent well was examined to simulate the fracture propagations, then well spacing analysis between the parent and child well was performed. The optimal number of fracture stages for each well and the ideal timing for fracturing the chill well were also specified to achieve the highest estimated ultimate recovery. The proposed workflow coupled the rock properties with a dual permeability reservoir simulation to construct a hydraulic fracture model capable of simulating 3D fracture propagations. The 1D mechanical earth model was initially developed to deliver geomechanical parameters of the studied formation. The quality of the parent well’s fracture simulation was validated using the production history matching technique. The matched model was analyzed for optimizing well spacing, fracture stages density, and the child well hydraulic fracture timing. The results showed a normal faulting regime in the formation with the minimum, maximum, and overburden stress gradients of 0.79, 0.90, and 1.10 psi/ft, respectively. The coupled model successfully simulated fracture propagations of the parent well using the fracture treatment data. The fracture outputs were verified by satisfactorily matching the production data. The estimated fracture geometry of the parent well varies from 200 to 1050 ft fracture length and 150 to 250 ft height for each stage. The findings demonstrate that the fracture geometry complies with variations in stress conditions during fracture fluid injection. Parent well production also alters the stress orientations and magnitudes, affecting the fracture propagations of the child well. Well-spacing analysis between parent and child wells was conducted from 650 to 1300 ft with a 50 ft increment. The results specified an optimal spacing to avoid well communications and maximize total production. For hydraulic fracturing optimization, the number of fracture stages analysis was performed and converted to the optimal density of stages per well. Furthermore, the parent well’s production period is the most sensitive factor affecting the child well’s fracturing. Therefore, the ideal timeframe for child well hydraulic fracturing was provided to optimize the entire process. The novelties of this research are in the ability to effectively estimate the optimal well spacing, fracture stages density, and timing of fracturing child well in the Third Bone Spring Sand formation using a 3D coupled model. Following the proposed workflow, one can optimize the hydraulic fracturing process in any other formations.

show abstract

scite is a Brooklyn-based organization that helps researchers better discover and understand research articles through Smart Citations–citations that display the context of the citation and describe whether the article provides supporting or contrasting evidence. scite is used by students and researchers from around the world and is funded in part by the National Science Foundation and the National Institute on Drug Abuse of the National Institutes of Health.

Contact Info

hi@scite.ai

10624 S. Eastern Ave., Ste. A-614

Henderson, NV 89052, USA

Blog Terms and Conditions API Terms Privacy Policy Contact Cookie Preferences Do Not Sell or Share My Personal Information

Made with 💙 for researchers

Part of the Research Solutions Family.

Best Practices and Lessons Learned on the Application of Managed Pressure Drilling MPD Technology For High Pressure High Temperature HPHT Wells in Vietnam

Cited by 2 publications

References 2 publications

Hydrostatically Underbalanced Managed Pressure Cementing Enables Zonal Isolation in Narrow-Margin HPHT Exploration Well

Hydrostatically Underbalanced Managed Pressure Cementing Enables Zonal Isolation in Narrow-Margin HPHT Exploration Well

The Integration of Geomechanics and Reservoir Modeling for Hydraulic Fracturing and Well Spacing Optimization in the Third Bone Spring Sand of the Delaware Basin

Contact Info

Product

Resources

About