Methodology of Effective Lateral Placement for Underbalanced Coiled Tubing Drilling Wells

2021 ◽  
Author(s):  
Azly Abdul Aziz ◽  
Ferney Moreno Sierra ◽  
Nawaf Aldossary
Keyword(s):  
Depositional Environments ◽  
Productivity Index ◽  
Well Testing ◽  
Multiple Sources ◽  
Gas Reservoirs ◽  
Past Performance ◽  
Placement Decisions ◽  
Coiled Tubing ◽  
In Series ◽  
Pressure Transient Test

Abstract This paper describes a methodology that has been developed to maximize lateral placement in productive reservoir intervals during underbalanced coiled tubing drilling (UBCTD) operations. UBCTD has emerged as an effective and economically viable development solution for exploiting reserves in mature gas reservoirs. In some cases, it can be a suitable solution to develop reserves in more geologically complex and heterogonous reservoirs over the conventional drilling and stimulation techniques. The methodology integrates big surface and subsurface data from multiple sources in multiple formats in real to near real-time that are normally acquired during UBCTD drilling operations. The multiple sources of data include subsurface geology, wellsite biosteering, reservoir influx, well testing and drilling, and can provide important information about the reservoirs encountered. With the aid of data analytics and an advanced visualization tool, the data is translated into in series of engineering plots that enable easier identification of productive intervals and more informed as well as efficient lateral placement decisions. This methodology has proven superior to the conventional instantaneous Productivity Index (PI) approach that is commonly used for UBCTD lateral placement. The methodology has been tested with good success in a number of recently drilled UBCTD wells in geologically complex depositional environments across carbonates and clastic reservoirs. Post flowback and pressure transient test analyses have shown significant improvement in the well deliver abilities and effective lateral lengths. Past performance from wells drilled using the PI method will be compared with wells drilled with this method.

Case History: Lessons learned From Retrieval of Coiled Tubing Stuck by Massive Hydrate Plug When Well Testing in an Ultra Deep Water Gas Well in Mexico

2011 ◽  
Author(s):  
Victor Gerardo Vallejo ◽  
Aciel Olivares ◽  
Pablo Crespo Hdez ◽  
Eduardo R. Roman ◽  
Claudio Rogerio Tigre Maia ◽  
...  
Keyword(s):  
Deep Water ◽  
Case History ◽  
Lessons Learned ◽  
Well Testing ◽  
Gas Well ◽  
Coiled Tubing ◽  
Hydrate Plug ◽  
Water Gas

Analysis of Plug Drilling and Stuck Pipe Performance Metrics

2021 ◽  
Author(s):  
Paul Brown ◽  
Brian Gunby
Keyword(s):  
Performance Metrics ◽  
Service Providers ◽  
Performance Indicator ◽  
Geographic Region ◽  
Relative Strength ◽  
Third Party ◽  
Multiple Sources ◽  
Coiled Tubing ◽  
Surface Measurements ◽  
Performance Statistics

Abstract A large collection of data recorded during coiled tubing (CT) operations has been analyzed using proprietary pattern recognition algorithms to identify downhole events with a high degree of confidence. These events include the drilling of plugs and stuck pipe incidents. Key performance indicator (KPI) metrics derived from this analysis provide insight into industry trends over time and by region, and can provide useful performance benchmarks for service providers and operator companies. Depth, weight and pressure data from multiple sources has been streamed and stored on a shared platform over a five year period, creating a record of over 39,000 data files. This data was processed to generate KPI-type statistics for over 500,000 detected plugs and 760 possible stuck pipe scenarios, based on analysis of depth and weight signatures. Using surface measurements to quantify downhole events has some limitations, but the method has proven sufficiently robust to allow useful trends to be observed and evaluated. While the analysis is confidential to the parties involved, a contributing company can compare their ‘performance’ statistics (as evaluated by the third party algorithms) against averages representative of the industry at large, arranged by year and geographic region, to identify areas of relative strength or weakness. An operator company can likewise compare metrics for different service providers (derived solely from jobs performed for their company) for those which elect to share data in this fashion. This paper presents statistics for plug drilling operations and stuck pipe incidents in North America between 2016-2020, a period of significant change in the CT industry. Examples show how average plug drilling times have generally decreased, with less frequent use of short trips and fewer pipe cycles. The data shows that, for some companies, faster operations have come at the expense of more frequent or severe stuck pipe incidents, whereas other companies have experienced fewer such problems. This comparative analysis illustrates how downhole outcomes can be deduced from surface measurements, and resulting performance metrics can vary widely between companies, fields and geographic regions.

Analytical Treatment of Pressure-Transient Solutions for Gas Wells With Wellbore Storage and Skin Effects by the Green's Functions Method

SPE Journal ◽  
2016 ◽  
Vol 21 (05) ◽  
pp. 1858-1869 ◽  
Author(s):  
Emilio P. Sousa ◽  
Abelardo B. Barreto ◽  
Alvaro M. Peres
Keyword(s):  
Green's Functions ◽  
Green’S Functions ◽  
Approximate Solutions ◽  
Test Problems ◽  
Well Testing ◽  
Well Test ◽  
Gas Reservoirs ◽  
Analytical Treatment ◽  
Wellbore Storage ◽  
Diffusivity Equation

Summary Even when written in terms of a pseudopressure function, the diffusivity equation for flow of gases through porous media is, rigorously speaking, nonlinear because the viscosity-compressibility product is pseudopressure-dependent. However, several techniques and analysis procedures neglect such nonlinearity. A new methodology for constructing solutions for gas reservoirs through the Green's functions (GF) technique was recently proposed in the literature. Such methodology handles the viscosity-compressibility product variation rigorously, and it was applied to solve several gas-well test problems successfully. However, wellbore storage and skin effects were not considered yet by this new approach. In this work, the GF technique is applied to obtain a new solution for an infinite, homogeneous, isotropic gas reservoir being produced through a single vertical well represented by a line-source with wellbore storage and skin. The solution, however, does not consider non-Darcy flow effects. Even though the wellbore storage introduces a new nonlinearity to an already nonlinear problem, this work presents two accurate approximate solutions compared with the results from a commercial numerical well-testing simulator. This work also shows that the wellbore pseudopressure dimensionless solution is a function of the correlating groups CDexp(2S) and tD/CD, exactly similar to the way that wellbore dimensionless liquid solutions are. Liquid and gas dimensionless solutions under these correlating groups are not equal, though.

Well Testing of Tight Gas Reservoirs

2006 ◽  
Author(s):  
Juan P. Garcia ◽  
Mehran Pooladi-Darvish ◽  
Frank Brunner ◽  
Marty Santo ◽  
Louis Mattar
Keyword(s):  
Well Testing ◽  
Tight Gas ◽  
Gas Reservoirs ◽  
Tight Gas Reservoirs

Coiled Tubing and Well Testing Experiences on Sichuan Horizontal Shale Gas Wells

2013 ◽  
Author(s):  
Chris Stolte ◽  
Chris Wu ◽  
Darryrl Carroll ◽  
Wang Shiqian
Keyword(s):  
Shale Gas ◽  
Well Testing ◽  
Gas Wells ◽  
Coiled Tubing

Impacts of Diverse Fluvial Depositional Environments on Hydraulic Fracture Growth in Tight Gas Reservoirs

2013 ◽  
Vol 28 (01) ◽  
pp. 8-25
Author(s):  
Patricia H. Cuba ◽  
Jennifer Miskimins ◽  
Donna S. Anderson ◽  
Mary M. Carr
Keyword(s):  
Hydraulic Fracture ◽  
Depositional Environments ◽  
Tight Gas ◽  
Gas Reservoirs ◽  
Tight Gas Reservoirs ◽  
Fracture Growth
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