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Collaborating Authors
Drilling Operations
Abstract This paper focuses on anti-collision best practices developed and implemented by Liberty Resources for horizontal drilling across pre-existing horizontal wellbores within the same horizon in the Williston Basin. These multidisciplinary collaborative workflows have allowed Liberty Resources to successfully drill multiple complex horizontal wellbores traversing as close as 10 feet wellbore-to-wellbore to existing laterals. As the horizontal infill development of unconventional reservoirs progresses, complex wellbore trajectories with heightened collision concerns will be required. To achieve this requires advancing the industry's anti-collision standard practices with new and more precise anti-collision methods, detailed planning, and near perfect execution. In the Williston Basin alone there are over 13,000 vertical wells, 15,000 horizontal wells, and over 1,000 re-entry and directional wells drilled to date, with the first horizontal wells introduced to the basin over 30 years ago. Historically, the horizontal wells were drilled using a vast array of well designs and orientations due to the limitations of technology, industry practices and standards, and the insufficient understanding of the reservoir. Advancements in drilling and completions technologies and a better understanding of the reservoir now allow leases to be reassessed for infill potential. This increased infill development has led to increasingly complex wellbore trajectories with collision concerns not only for existing vertical wellbores but now also for existing horizontal wellbores within the same or proximal horizons. The anti-collision best practices include directional and geologic planning considerations, operational tolerances and requirements including zonal determination, communication protocols, and risk management practices. Creating a broad framework that allows for flexibility to adjust for distinct operational constraints. These workflows and tolerances have been implemented in three horizontal wellbores traversing seven same-formation pre-existing horizontal wellbores. The anti-collision method was successfully applied in both the Middle Bakken and Three Forks formations, each with their own varied and unique geologic characteristics, demonstrating applicability for a wide range of reservoirs. The ability to execute complex wellbores opens new opportunities to access additional resources in previously considered "fully developed" acreage. The methods presented in this paper have allowed the routine drilling of horizontal laterals as close as 10 feet to existing laterals. This technology can be applied to a variety of reservoirs opening new opportunities to access additional resources previously considered unrecoverable due to existing wellbores.
- North America > United States > North Dakota (1.00)
- North America > Canada (1.00)
- North America > United States > South Dakota > Williston Basin (0.99)
- North America > United States > Montana > Williston Basin (0.99)
- North America > United States > North Dakota > Williston Basin > Three Forks Group Formation (0.94)
- North America > United States > North Dakota > Williston Basin > Bakken Shale Formation > Middle Bakken Shale Formation (0.94)
Application of an Innovative Spacer System Designed for Optimal Performance in HTHP Wells
Doan, Angela (Baker Hughes, a GE Company) | Holley, Andrew (Baker Hughes, a GE Company) | Kellum, Matthew (Baker Hughes, a GE Company) | Dighe, Shailesh (Baker Hughes, a GE Company) | Arceneaux, Cory (Baker Hughes, a GE Company) | Conrad, Ken (Baker Hughes, a GE Company)
Abstract Extreme well conditions, especially higher temperatures, are becoming more commonplace. This in turn requires improvements to our wellbore fluids. This study focuses on the development of a new spacer system designed especially for those wells exhibiting extremely high temperatures. A critical characteristic of this spacer is that the surface rheology must not be overly excessive as to maintain a pumpable fluid; however, the downhole rheology must not diminish due to thermal thinning or degradation of the gelling agent so the spacer remains stable. To ensure the spacer suitably meets these requirements, both ambient and elevated temperature rheologies are analyzed and reported. The stability of the spacer related to settling of solid particulates is examined by conducting dynamic settling tests at 300°F and above. In this study, spacer compositions and densities were adjusted to examine effects on rheology and stability of the solids within the system at elevated temperatures. Results show that conventional spacer systems are not adequate at elevated temperatures especially above 300°F. The newly developed spacer system shows much improved results from dynamic settling tests even up to 400°F. Also, the surface rheology of the new spacer system is not significantly different from that of the conventional system. The innovative spacer system within this paper was shown to add significant value to extreme cementing operations. In addition, by comparing the results between these two testing methods, the dynamic settling test should be considered as an alternate procedure for testing the stability of spacers under high temperature conditions.
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- Well Completion (1.00)
- (4 more...)
Abstract This paper serves to provide a technical overview of the Real-Time Drilling (RTD) analytics system currently developed and deployed. It also serves to share practices used in managing the RTD analytics project which have resulted in the efficient delivery of work products. By employing the novel and agile development approach on the RTD project, the design to production time has been faster and has cost much less compared to a more traditional multi-year effort and cost intensive RTD development project. Within three months, for proof of concept (PoC) purpose, an RTD analytics system with two analytics modules was built from scratch and placed online in production. This real-time decision-support tool has been fully accepted by the operations team and has become a powerful tool for daily well operations. After eleven months as this paper was drafted, this system has four analytic modules online for production and three analytic modules under development; it is expected that more new modules will be added to the system on a regular basis.
- Europe > United Kingdom > North Sea > Southern North Sea > Southern Gas Basin > Sole Pit Basin > Block 43/27 > Johnston Field (0.93)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5505/17 > Dan Field (0.93)
- Asia > Middle East > Syria > Deir ez-Zor Governorate > Tanek Field (0.93)
- Well Drilling > Drillstring Design > Torque and drag analysis (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Management (1.00)
- (2 more...)
Drilling Analysis Using Big Data has been Misused and Abused
Maidla, Eric (ProNova - TDE Petroleum Data Solutions, Inc.) | Maidla, William (ProNova - TDE Petroleum Data Solutions, Inc.) | Rigg, John (ProNova - TDE Petroleum Data Solutions, Inc.) | Crumrine, Michael (ProNova - TDE Petroleum Data Solutions, Inc.) | Wolf-Zoellner, Philipp (ProNova - TDE Petroleum Data Solutions, Inc.)
The authors have been contacted by many people in the industry lately that are incorrectly utilizing big data to produce correlations that attempt to identify operational "sweet spots". This paper will show examples and address the need to add several steps to big data before any meaningful correlation results can be obtained, mainly understanding (and this is not a comprehensive list): 1. The sensors involved and their limitations; 2. The errors in the placement of these sensors (e.g.
- Europe (0.46)
- North America > United States > Texas (0.15)
- Data Science & Engineering Analytics > Information Management and Systems > Data mining (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
Abstract Major performance challenges for deepwater applications from a drill bit standpoint were identified as (1) High surface torque in salt is one of the major ROP limiters. (2) Inability to control depth of cut in soft rocks including shale and salt and when drilling in interbedded formations results in torsional oscillations and stick-slip. (3) Improper combination of bit and reamer induces drillstring vibrations. This paper presents the development of new drill bit technologies combined with a new system matching analysis package to address those problems. Salt mechanical behavior was evaluated using triaxial testing under confining pressures up to 5,000 psi. Full scale pressurized testing was then conducted to evaluate salt drilling behavior versus rock characteristics. The following specific challenges were addressed: Non-planar PDC geometries were tested in salt, among other rocks, to identify a geometry which results in maximum increase in ROP at any given torque. New insert shapes were developed and tested for more effective and accurate depth of control. A full drillstring analysis model was developed with the ability to predict downhole and surface torque and WOB as well as drillstring dynamics, torque, and drag. The new shaped cutter full scale pressurized test resulted in an increase in ROP/torque ratio throughout the different rock and a 28% increase in salt. The cutter also increased ROP/WOB ratio by 42%. Furthermore, the new insert shapes proved to be more effective in controlling depth of cut, resulting in an extra 35% reduction in torque/WOB ratio compared to standard insert shapes. The project is now in field evaluation and the new drill string analysis tool has been applied to several field applications including some in the Middle East, North Sea, Gulf of Mexico, and the Caribbean for different purposes. Some of those purposes include buttonhole assempbly (BHA) selection for given bit and reamer, bit selection for a given BHA design and reamer, and drilling parameter optimization for a given BHA design, bit, and reamer. New insert shapes were run in multiple applications in North America, including in North Dakota and Oklahoma, with promising results proving that although the project was focused on deepwater drilling challenges, the novel solutions are applicable to a wide range of applications.
- North America > United States > Oklahoma (0.24)
- North America > United States > North Dakota (0.24)
- Europe > United Kingdom > North Sea (0.24)
- (3 more...)
- Geology > Geological Subdiscipline > Geomechanics (0.70)
- Geology > Mineral (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.36)
- Well Drilling > Drillstring Design > Torque and drag analysis (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Equipment (1.00)
- (2 more...)
Abstract Various generations of double-shouldered drill pipe connections have been developed in the past 30 to 40 years with performance as a primary driver. The objective was to bring improvements in torque and hydraulics to satisfy drillers' needs. The record extended reach drilling (ERD) wells could not have been delivered without these technological advancements. The driver for these developments was solely on improved performances, with limited focus on cost, as these technologies were so enabling that the associated costs were deemed acceptable. When these same connections started to be used on land rigs to deliver wells in a factory drilling fashion, where cost control is of higher importance, the cost of maintaining these premium connections started to become more apparent. It, therefore, became obvious that a different approach was needed to meet the combined need for performance, as well as a lower cost of ownership post acquisition. A comprehensive two-year research and development (R&D) program was carried out to evaluate various design options. After the research was conducted, a design was chosen that allows better control of stress inside the connection. This allows users to benefit from other design features besides the torque and hydraulics of a streamlined connection. The R&D program included numeric simulation and mechanical lab testing. More specific elements of the design allowed more tolerance related to field damage of the connection, less material loss on repairs, and more importantly, a ruggedness so that the connection can remain in the field longer rather than needing to be repaired so often. The final stage of qualification was a field trial at the manufacturer's test rig facility. A post field trial inspection confirmed the improved serviceability and ruggedness, qualifying the connection for commercial release. The 4 generation double-shouldered connection was first put to task in the Permian basin. A rental string was dispatched to a land rig and used to drill the longest and fastest lateral in the area. The tapered 5½ in. by 5 in. drill pipe string, which comes with tool joints of a similar size (this of 5 in. drill pipe), drilled the well and saved two days off the estimated drilling plan. Subsequently, more strings have been deployed, and more data shall be gathered in this paper to demonstrate the low repair rate. A new approach has been used to design a connection that performs at high torque levels but also demonstrates improved serviceability and a ruggedness approaching that of an API rotary shoulder connection.
- 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)
- (21 more...)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Drilling Equipment (1.00)
Optimizing the Deepwater Completion Process: Case History of the Tamar 8 Completion Design, Execution and Initial Performance - Offshore Israel
Healy, John (Noble Energy) | Waggoner, Steven M. (Noble Energy) | Magin, Ian (Noble Energy) | Beavers, Matt (Noble Energy) | Williams, Kevin (Noble Energy) | Hebert, Russell (Noble Energy)
Abstract A case history from Offshore Israel is presented that describes the successful delivery of one (1) ultra-high rate gas well (+250 MMscf/D) completed in a significant (11.5 TCF) gas field with 7 in. production tubing and an Open Hole Gravel Pack (OHGP). The well described, Tamar 8, was completed approximately 4 years after the start of initial production from the Tamar development. Several operational innovations and process improvements were implemented that resulted in a significant reduction in rig time. A novel multi-purpose integrated tool string design enabled the sequential drilling of the pilot hole, underreaming of the reservoir section, several fluid displacements and casing cleaning in a single trip. The completions were installed with minimal operational issues (completion Non-Productive Time, NPT = 2.6%). Production commenced in April 2017. The initial completion productivity of this new well exceeded the five wells completed in 2012. Peak production rate to date is 281 MMscf/D.
- Europe (1.00)
- North America > United States > Texas (0.69)
- Asia > Middle East > Israel > Mediterranean Sea (0.29)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.94)
- Geology > Mineral (0.68)
- North America > Trinidad and Tobago > Trinidad > North Atlantic Ocean > Columbus Basin > South East Galeota Block > Cannonball Field (0.99)
- Asia > Middle East > Israel > Mediterranean Sea > Southern Levant Basin > Mari-B Field > Yafo Formation (0.99)
- Asia > Middle East > Israel > Mediterranean Sea > Southern Levant Basin > Mari-B Field > Noa Formation (0.99)
- (5 more...)
- Well Drilling > Drilling Operations (1.00)
- Well Completion > Completion Installation and Operations (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- (6 more...)
Abstract Weight on bit (WOB) is the axial trust force applied to the bit during drilling. It is one of the most important controllable variables of the drilling process. Still, it is quite rare and very difficult to measure it directly, and we are often left with estimating it indirectly through measurements of the tension at the top of the string, or even at the dead line anchor. This indirect WOB measurement, commonly called surface WOB, is most often calculated as measured off-bottom hook loadminus the actual hookload. This method assumes that the reference string weight is constant and does not change during drilling. This paper challenges this assumption by discussing a variety of physical effects that can cause the reference hook load to change, during the drilling of a new stand and after a traditional WOB zeroing procedure is carried out. The paper discusses the following effects that can be used for correcting the reference hook load: 1)well bore friction, 2)added weight in air, 3)well inclination, 4)flow induced lift, 5) nozzle jet lift, 6)cuttings in suspension, and 7) back-pressure in managed pressure drilling operations.
- Well Drilling > Drilling Operations > Directional drilling (0.89)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (0.69)
Abstract Friction reduction devices in the form of vibrators are becoming more widely used in drilling operations because of their ability to create oscillation in the string, which can reduce the amount of friction force present. Ordinarily, the placement of vibrators is based on past field experience; an improper arrangement of vibrators, however, can reduce their efficiency and lead to possible tool damage. A proper model for estimating the working range for vibrators can enhance the efficiency and safety of the vibrator. This paper presents a new method for predicting the working range for vibrators based on the stress wave theory. The proposed method uses the stress wave theory to calculate the vibration velocity. Beginning at the vibrator, the stress wave travels a lengthy distance in the string. The friction on the string, however, diminishes the stress wave energy until the vibration velocity reaches zero. The vibrator working range is defined as the string section with a non-zero oscillation velocity. A set of equations to calculate the stress wave traveling distance is proposed in this paper. This model provides a theoretical prediction of the vibrator working range to effectively optimize vibrator use. The stress wave traveling distance predicted from this model is likely to be a linear relationship to the acceleration generated by the vibrator, which is similar to the results obtained in the field, and can be used to better determine the most effective placement for vibrators in horizontal wells.
- Well Drilling > Drilling Operations > Directional drilling (0.50)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (0.49)
Abstract The Barlow equation for tubular internal yield pressure is widely used in American Petroleum Institute (API) and International Organisation for Standardisation (ISO) standards, but its provenance and accuracy have never been established: indeed, until very recently, the original reference had been lost to the industry. This has led to doubt and confusion about its use. This paper presents the work done by ISO TC67 SC5 workgroup 2 to remedy this, and explains the background and technical basis for the upcoming revisions to ISO TR 10400. It is shown that Barlow's 1836 derivation violates the 3D constitutive law, and the result is therefore incorrect as originally purposed (a thick wall hoop stress). Moreover, hoop stress is a uniaxial (1D) check: the modern approach is 2D or 3D checking, based on a material failure condition such as the Von Mises yield criterion. However, the result also happens to represent the thin wall approximation to the VME failure pressure for plane stress (i.e., zero axial load), which gives an accurate measure of the yield pressure. Remarkably, this does not seem to have been recognised in previous work. The derivation is given, and the assumptions and limitations explained. Present design practice is over-conservative for thick wall pipe, and potentially unconservative for thin wall. This is not the fault of the Barlow equation per se: it is caused by the difference in physics between the design equation (VME yield) and the ultimate limit state (ULS) behaviour (ductile rupture). The industry should therefore consider revising OCTG burst ratings and accompanying design practice to achieve a more uniform safety level over the full D/t range of casing and tubing.