Drilling Fluid Impact Studies Show that Worker Health and the Environment Can Be Protected While Improving Drilling Performance

2018 ◽  
Author(s):  
Serena Lim ◽  
Delina Lyon ◽  
Graham Whale ◽  
Burnell Lee ◽  
Peter Boogaard ◽  
...  
Keyword(s):  
Drilling Fluid ◽  
Impact Studies ◽  
Drilling Performance ◽  
Worker Health

Experimentally-Tuned Mathematical Model for Drillstring Vibrations

2007 ◽  
Author(s):  
Y. A. Khulief ◽  
F. A. Al-Sulaiman
Keyword(s):  
Dynamic Models ◽  
Drilling Fluid ◽  
Experimental Studies ◽  
Published Data ◽  
Test Rig ◽  
Stick Slip ◽  
Multibody Model ◽  
Drilling Performance ◽  
Weight On Bit ◽  
Functional Operation

Field experience manifests that drillstring vibration is one of the major causes for a deteriorated drilling performance. It is crucial to understand the complex vibrational mechanisms experienced by a drilling system in order to better control its functional operation and improve its performance. Experimental studies of drillstring dynamics are essential to complement the theoretical studies, and to alleviate the complexity of such dynamic models. This paper presents an experimental investigation using a specially designed drilling test rig. The test rig can simulate the drillstring vibrational response due to various excitation mechanisms, which include stick-slip, well-borehole contact, and drilling fluid interaction. The test rig is driven by a variable speed motor which allows for testing different drilling speeds, while a magnetic tension brake is used to simulated stick-slip. In addition, a shaker is employed to excite the drillstring axially in order to simulate the weight-on-bit (WOB). The drillstring is instrumented for vibration measurements. The experimentally identified parameters are used to refine the finite element multibody model of the drillstring, which was derived earlier by the investigators [1]. Comparisons with published data demonstrate the reliability of the developed scheme for prediction of drillstring vibrations.

High Performance Fresh Water Flocculating Drilling Fluid helps to increase drilling performance and reduce costs on Uvat oilfield

2008 ◽  
Author(s):  
Alexey Samarskiy ◽  
Robert Munger ◽  
Alexander Gennadievich Terentiev ◽  
Sergey Albertovich Gasparov ◽  
Boris Pavlovich Zalogin ◽  
...  
Keyword(s):  
Fresh Water ◽  
High Performance ◽  
Drilling Fluid ◽  
Drilling Performance

scholarly journals Experimental Investigation of Inhibitive Drilling Fluids Performance: Case Studies from United States Shale Basins

Energies ◽  
2020 ◽  
Vol 13 (19) ◽  
pp. 5142
Author(s):  
Nabe Konate ◽  
Saeed Salehi
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Gas Production ◽  
Drilling Fluids ◽  
Eagle Ford Shale ◽  
Oil And Gas Production ◽  
Shale Formations ◽  
Drilling Performance ◽  
Marine Shale ◽  
Fluid Systems

Shale formations are attractive prospects due to their potential in oil and gas production. Some of the largest shale formations in the mainland US, such as the Tuscaloosa Marine Shale (TMS), have reserves estimated to be around 7 billion barrels. Despite their huge potential, shale formations present major concerns for drilling operators. These prospects have unique challenges because of all their alteration and incompatibility issues with drilling and completion fluids. Most shale formations undergo numerous chemical and physical alterations, making their interaction with the drilling and completion fluid systems very complex to understand. In this study, a high-pressure, high-temperature (HPHT) drilling simulator was used to mimic real time drilling operations to investigate the performance of inhibitive drilling fluid systems in two major shale formations (Eagle Ford Shale and Tuscaloosa Marine Shale). A series of drilling experiments using the drilling simulator and clay swelling tests were conducted to evaluate the drilling performance of the KCl drilling fluid and cesium formate brine systems and their effectiveness in minimizing drilling concerns. Cylindrical cores were used to mimic vertical wellbores. It was found that the inhibitive muds systems (KCl and cesium formate) provided improved drilling performance compared to conventional fluid systems. Among the inhibitive systems, the cesium formate brine showed the best drilling performances due to its low swelling rate and improved drilling performance.

Wellbore Shielding Technique Increases Operative Window, Avoiding Formation Instability and Losses, Minimizing NPT, and Optimizing Drilling Operations in the Unconventional Plays

2021 ◽  
Author(s):  
Gaston Lopez ◽  
Gonzalo Vidal ◽  
Claus Hedegaard ◽  
Reinaldo Maldonado
Keyword(s):  
Drilling Fluid ◽  
Drilling Fluids ◽  
Wellbore Instability ◽  
Lost Circulation ◽  
Drilling Performance ◽  
Drilling Parameters ◽  
Vaca Muerta ◽  
Drilling Operations ◽  
Fracture Gradient ◽  
Vaca Muerta Formation

Abstract Losses, wellbore instability, and influxes during drillings operations in unconventional fields result from continuous reactivity to the drilling fluid causing instability in the microfractured limestone of the Quintuco Formation in Argentina. This volatile situation becomes more critical when drilling operations are navigating horizontally through the Vaca Muerta Formation, a bituminous marlstone with a higher density than the Quintuco Formation. Controlling drilling fluids invasion between the communicating microfractures and connecting pores helps to minimize seepage losses, total losses, wellbore fluid influxes, and instabilities, reducing the non-productive time (NPT) caused by these problems during drilling operations. The use of conventional sealants – like calcium carbonate, graphite, asphalt, and other bridging materials – does not guarantee problem-free drilling operations. Also, lost circulation material (LCM) is restricted because the MWD-LWD tools clearances are very narrow in these slim holes. The challenge is to generate a strong and resistant seal separating the drilling fluid and the formation. Using an ultra-low-invasion technology will increase the operative fracture gradient window, avoid fluid invasion to the formation, minimize losses, and stop the cycle of fluid invasion and instability, allowing operations to maintain the designed drilling parameters and objectives safely. The ultra-low-invasion wellbore shielding technology has been applied in various fields, resulting in significantly improved drilling efficiencies compared to offset wells. The operator has benefited from the minimization of drilling fluids costs and optimization in drilling operations, including reducing the volume of oil-based drilling fluids used per well, fewer casing sections, and fewer requirements for cementing intervals to solve lost circulation problems. This paper will discuss the design of the ultra-low-invasion technology in an oil-based drilling fluid, the strategy for determining the technical limits for application, the evaluation of the operative window with an increase in the fracture gradient, the optimized drilling performance, and reduction in costs, including the elimination of NPT caused by wellbore instability.

Raman Spectra of Hydrocarbon in Returned Drilling Fluid Using Co-Focal Laser Raman Microscopy

2012 ◽  
Vol 616-618 ◽  
pp. 715-719
Author(s):  
Ming Ming Tang ◽  
Jin Liang Zhang
Keyword(s):  
Raman Spectra ◽  
Drilling Fluid ◽  
Potential Method ◽  
Raman Microscopy ◽  
Hydrocarbon Detection ◽  
Laser Raman ◽  
Drilling Performance ◽  
Water Based

Hydrocarbon detection while drilling (HDWD) is important for obtain proper drilling performance. In this report, Raman spectra for hydrocarbon in returned water based drilling fluid have been acquired using He-Ne laser (633nm) excitation. The relative intensities of several Raman bands are found to depend on the concentration of hydrocarbon in returned drilling fluid. Spectra are interpreted as indicating that Raman spectra could be used as potential method for HDWD.

Using a Low-Salinity High-Performance Water-Based Drilling Fluid for Improved Drilling Performance in Lake Maracaibo

2007 ◽  
Author(s):  
Julio Cesar Montilva ◽  
Eric Van Oort ◽  
Ricardo Brahim ◽  
Lirio Quintero ◽  
William Dye ◽  
...  
Keyword(s):  
High Performance ◽  
Drilling Fluid ◽  
Low Salinity ◽  
Drilling Performance ◽  
Lake Maracaibo ◽  
Water Based

DEVELOPMENT AND EVALUATION OF SOLID CONTROL SYSTEM TO OPTIMIZE DRILLING PERFORMANCE

2016 ◽  
Vol 78 (6-7) ◽  
Author(s):  
Imros Kinif ◽  
Sonny Irawan ◽  
Abhilash M. Bharadwaj
Keyword(s):  
Control System ◽  
Yield Point ◽  
Drilling Fluid ◽  
Plastic Viscosity ◽  
Dilution Method ◽  
Drilling Fluids ◽  
Drilling Mud ◽  
Low Gravity ◽  
Drilling Performance ◽  
The Impact

The nature of solid content mechanism in drilling fluids directly affects its properties and causes adverse impact on drilling performance. It has rapidly evolved and become a paramount issue over the years because of challenging drilling operations. To control the impact of the drilled solids on drilling fluid properties, solid control system unit must be capable of removing the drilled solids before the re-circulation. Failure to establish good solid control management may end the operation strategy with dilution method. A rigorous analysis of drilled solid effects and its correlation with poor performance of solid control system significantly reflects on the overall rig performance in optimizing drilling operation. This paper presents a study of two different solid control system configuration used in two drilling wells. The study shows that installation of distributor tank reduces mud overflow and brings in flow control stability. Mud rheologies – Plastic viscosity, Yield Point and Low Gravity Solid are considered for the two solid control systems. The results of the new solid control system design are better than the old one. Plastic viscosity, yield point and low gravity solid values improve by 14 %, 17 % and 25 % respectively. These results can be used to check the drilling performance and also in characterization of the solid control system to enhance the drilling mud capabilities. This research shows the need of engineering evaluation in the solid control system to reduce the chances of frequent drilling problems, rig components wear issue and other drilling fluid related hazards.

Mathematical Model of the Diamond-Bit Drilling Process and Its Practical Application

1982 ◽  
Vol 22 (06) ◽  
pp. 911-922 ◽  
Author(s):  
Malgorzata B. Ziaja ◽  
Stefan Miska
Keyword(s):  
Penetration Rate ◽  
Drilling Fluid ◽  
Active Surface ◽  
Rock Properties ◽  
Depth Of Cut ◽  
Drilling Process ◽  
Diamond Cutting ◽  
Rate Of Penetration ◽  
Drilling Performance ◽  
Diamond Bit

Abstract With several limiting assumptions, a mathematical model of the diamond-bit drilling, process has been developed. The model represented by an instantaneous rate-of-penetration equation takes into account the reduction in penetration rate during drilling resulting from bit wear. The model has been tested both under laboratory and under field conditions. The comparison of the theoretical and experimental results has shown reasonable agreement. A method for estimating rock properties also has been established. Using this method, we can find the so-called index of rock strength and the index of rock abrasiveness. Introduction Several published studies concerned with diamond-bit drilling report on rock properties and drillability. drilling fluid additives, diamond wear, and drilling performance theories. Among the factors, that affect diamond-bit drilling performance, the type of formation to be drilled is of utmost importance since it significantly affects the type of bit, the drilling practices. and subsequently the rate of penetration and the drilling cost. The nature of the formation is also one of the main factors in planning deep wells, fracture jobs, mud and cement technologies, etc. For rock properties evaluation as well as for selection of proper drilling practices, several descriptions of the diamond-bit drilling process have been developed. The relevant literature is extensive and is not reviewed in this paper. The objective of this paper is to describe the diamondbit drilling model for surface-set diamond core bits and its application to determining the index of formation strength and the index of formation abrasiveness. The main difference between our model and the models known in literature is that we consider the effect of friction between the diamond cutting surfaces and the rock. A decrease in penetration rate is observed if the drilling parameters, are constant and if the formation is macroscopohomogeneous. Drilling Model The drilling model for a surface-set diamond core bit is subjected to the following limiting assumptions.Rock behavior during cutting with a single diamond may be approximated by a rigid Coulomb plastic material.The active surface of the bit is flat, and diamonds are spherical with diameter. d.The cross-sectional area of the chip formed by a single diamond is equal to the diamond cutting surface and can be established by geometry.During drilling, the neighboring diamonds work together to make a uniform depth of cut (Fig. 1).A number of diamonds forming one equivalent blade have to provide it uniform depth of cut from the inner to the outer diameter of the diamond core bit. so the bit is modeled to be a combination of several equivalent blades (Fig. 2).The diamond distribution technique provides uniform radial coverage that results in equally loaded cutting diamonds.Individual cutting diamonds perform some work that results from the friction between the rock and the diamond.Bit wear is assumed to be gradual while drilling is in progress. Under the preceding assumptions we may state that the drilling rate of the surface-set diamond core bit is a function only of weight on bit (WOB), rotary speed, average density of the diamonds on the bit's active surface, diamond size, core-bit diameters, rock properties, and degree of diamond dullness. The effects of flow rate, differential pressure, hydraulic lift, drilling fluid properties. and drillstring dynamics are ignored. According to Peterson, the penetration rate of the diamond bit, after some modifications, can be described by the following simplified equation. (1) This equation does not include the effect of diamond wear and hence pertains to unworn bits or to when bit dullness is negligible. SPEJ P. 911^

Best Practice to Improve Slim Hole Maximum Reservoir Contact Well Drilling Performance

2021 ◽  
Author(s):  
Rodrigo Antillon Moreira ◽  
Ramanujan Jeughale ◽  
Toki Takahiro ◽  
Toma Motohiro ◽  
Kerron Andrews ◽  
...  
Keyword(s):  
Friction Factor ◽  
Best Practice ◽  
Drilling Fluid ◽  
Stock Selection ◽  
Well Drilling ◽  
Drilling Performance ◽  
Well Integrity ◽  
Drilling Parameters ◽  
Open Hole ◽  
Extended Reach Drilling

Abstract Reservoir sections in MRC (Maximum Reservoir Contact) & ERD (Extended Reach Drilling) wells are mainly designed to drill 8 ½" hole, because of drilling limitations with smaller hole size. However, slim hole sizes offer opportunities to revitalize existing wells using re-entry drilling techniques in association with MRC and ERD designs. This paper discusses the best practices to be implemented in order to mitigate risk, reduce complexity and ensure improved drilling performance. Re-Entry wells in the field have a risk of well integrity issues such as corroded 9 5/8" casing. In order to mitigate this risk, the corroded 9 5/8" casing should be covered by 7" liner & tied-back to surface before drilling reservoir section. In this situation up to 18,000 ft of 4" DP is used in the wells to drill 6" hole and run 4 ½" lower completion. Offset well analysis, whip stock selection criteria, BHA design, drilling fluid selection, drilling and tripping practices based on torque & drag and hydraulics calculations are most important to achieve the well objective. The Slim hole MRC well was completed without any issues and achieved good drilling performance. It was observed that the actual drilling parameters such as torque, drag and stand pipe pressure were less than simulated parameters. NAF was selected in the section to reduce the friction factor, while motorized RSS and a reamer stabilizer were used in the BHA to reduce torque, drag and ensure a smooth well profile. A back reaming practice was implemented in hole section to reduce dog leg severity and the open hole was eventually displaced to viscosified brine to minimize the friction factor for running the 4 ½' lower completion. 8500 ft of 6" hole section was drilled and TD was reached at +/- 19,000ft within 50 days including recovering the existing completion, drilling 8 ½" & 6" hole and running completion. This paper aims to contribute to the oilfield industry by sharing the successfully implemented engineering design and operation execution methodology to overcome the complexities present in Re Entry Wells MRC/ERD wells required to be drilled with slim hole conditions under an optimal cost, time effectiveness and low risk.

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