A New Numerical Solution To Predict the Temperature Profile of Gas-Hydrate-Well Drilling

SPE Journal ◽  
2017 ◽  
Vol 22 (04) ◽  
pp. 1201-1212 ◽  
Author(s):  
Ben Li ◽  
Hui Li ◽  
Boyun Guo ◽  
Xiao Cai ◽  
Mas lwan Konggidinata
Keyword(s):  
Numerical Model ◽  
Temperature Profile ◽  
Gas Hydrates ◽  
Gas Hydrate ◽  
Drilling Fluid ◽  
Drilling Process ◽  
Thomson Effect ◽  
Drilling Mud ◽  
Pumping Rate ◽  
Well Drilling

Summary Gas-hydrate cuttings are conveyed upward by the drilling fluid through the outer drillpipe/wellbore annulus during the gas-hydrate-well-drilling process. The temperature profile along the wellbore during the drilling process has not been thoroughly investigated because the gas-hydrate cuttings could affect the temperature of the drilling fluid along the wellbore. As the mixture of drilling fluid and gas hydrates flows from the bottom to the surface, the methane and other hydrocarbons present in the gas hydrates would change from liquid to gas phase and further cause well-control issues. Furthermore, the bottomhole pressure would decrease and could not provide sufficient balance to the formation pressure, which could significantly increase the risk of well blowout. A numerical solution is presented in this paper to predict the temperature profile of the gas-hydrate well during the drilling process. The main considerations were the following: Hydrate cuttings entrained in the bottom of the hole would affect the temperature of the fluid in the annulus space. The entrained hydrate cuttings could affect the fluid thermal properties in the drillstring and in the annulus. Because of the Joule-Thomson cooling effect at the outlet of the nozzles, the fluid temperature at the bottom of the hole was lower than that above the drill-bit nozzles. Hence, the gas-hydrate-dissociation characteristics were considered and integrated in the proposed numerical model. The numerical model was validated by comparing the obtained data with the Shan et al. (2016) analytical model. In addition, the obtained data were also compared with the measured temperature data of a conventional well drilled in China and a gas-hydrate-well drilling record in India. Sensitivity analysis was used to evaluate the effects of the pumping rate, Joule-Thomson effect, and injection drilling-mud temperature on the annulus temperature-profile distribution. It was found that the injection drilling-mud temperature and pumping rate could affect the temperature profile in the annulus, whereas the Joule-Thomson effect could decrease the annulus temperature of the drilling mud near the bottom.

Investigation of Drilling Problems in Gas Hydrate Formations

2008 ◽  
Author(s):  
Catalin Teodoriu ◽  
Gioia Falcone ◽  
Amodu Afolabi
Keyword(s):  
Gas Hydrates ◽  
Gas Hydrate ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Hydrate Formation ◽  
Oil And Gas Industry ◽  
Lessons Learned ◽  
Drilling Fluids ◽  
Drilling Mud ◽  
Gas Hydrate Formation

Gas hydrates are ice-like crystalline systems made of water and methane that are stable under high pressure and low temperature conditions. Gas hydrates have been identified as strategic resources and may surpass all known oil and gas reserves combined. However, these resources will become reserves only if the gas contained therein can be produced economically. In the oil and gas industry, gas hydrates may be encountered while drilling sediments of the subsea continental slopes and in the subsurface of permafrost regions. They also represent a flow assurance issue, as they may form in the well and in the flowlines, causing blockages. Deepwater drilling programmes have experienced problems when encountering gas hydrate formations. A major issue is that of phase transition, where gas hydrate goes from a solid state to dissociated gas and water, as there are rapid changes in fluid volumes and pressure. This can cause drilling equipment failure, borehole instability and formation collapse. After dissociation of water and gas, hydrates may be prevented from forming in the well by using appropriate inhibitors in the drilling mud. There is a need to develop fluids specifically for drilling through gas hydrate formations, either to unlock the unconventional reserves trapped in the crystalline gas hydrate structures or to safely reach underlying conventional reserves. To drill wells in a gas hydrate formation, a conductor casing is needed to allow close loop circulation of the mud, if different from seawater. The search for the ideal mud for drilling through gas hydrate formations must start with a review of past experiences worldwide and of the lessons learned. This paper presents a review of the problems encountered while drilling through gas hydrate formations. It identifies the key requirements for drilling fluids, based on the interaction between the drill bit, the drilling fluid and the formation. An evaluation of the environmental risk associated with drilling through gas hydrate formations is also presented.

Pipe stick problems of deep well drilling

2021 ◽  
Vol 66 (05) ◽  
pp. 192-195
Author(s):  
Rövşən Azər oğlu İsmayılov ◽  
Keyword(s):  
Drilling Fluid ◽  
Drill Pipe ◽  
Drill String ◽  
Differential Pressure ◽  
Drilling Mud ◽  
Fluid Circulation ◽  
Well Drilling ◽  
Deep Well ◽  
Pressure Pipe ◽  
Bottomhole Pressure

The aricle is about the pipe stick problems of deep well drilling. Pipe stick problem is one of the drilling problems. There are two types of pipe stick problems exist. One of them is differential pressure pipe sticking. Another one of them is mechanical pipe sticking. There are a lot of reasons for pipe stick problems. Indigators of differential pressure sticking are increase in torque and drug forces, inability to reciprocate drill string and uninterrupted drilling fluid circulation. Key words: pipe stick, mecanical pipe stick,difference of pressure, drill pipe, drilling mud, bottomhole pressure, formation pressure

Enhancement lubricity properties of water-based mud with nanoparticles

2020 ◽  
pp. 70-74
Author(s):  
V.V. Guliyev ◽  
◽  
◽  
Keyword(s):  
Yield Point ◽  
Coefficient Of Friction ◽  
Drilling Fluid ◽  
Research Work ◽  
Shear Thinning ◽  
Rheological Parameters ◽  
Drilling Process ◽  
Drilling Mud ◽  
Pseudoplastic Fluid ◽  
Water Based

Currently, a great number of drilling fluids with different additives are used all over the world. Such additives are applied to control the properties of the drilling mud. The main purpose for controlling is to achieve more effective and safe drilling process. This research work aims to develop Water-Based Mud (WBM) with a Coefficient of Friction (CoF) as low as Oil-Based Mud (OBM) and better rheological properties. As it is known, produced CoF by WBM is higher than OBM, which means high friction between wellbore or casing and drill string. It was the reason for studying the effect of nanosilica on drilling fluid properties such as lubricity, rheological parameters and filtrate loss volume of drilling mud. The procedures were carried out following API RP 13B and API 13I standards. Five concentrations of nanosilica were selected to be tested. According to the results obtained, it was defined that adding nanosilica into the mud decreases CoF of basic WBM by 26 % and justifies nanosilica as a good lubricating agent for drilling fluid. The decreasing trend in coefficient of friction and plastic viscosity for nanosilica was obtained until the concentration of 0.1 %. This reduction is due to the shear thinning or pseudoplastic fluid behavior. After 0.1 %, an increase at PV value trend indicates that it does not follow shear thinning behavior and after reaching a certain amount of dissolved solids in the mud, it acts like normal drilling fluid. The yield point of the mud containing nanoparticles was higher than the basic one. Moreover, a growth in the concentration leads to an increase in yield point value. The improvement of this fluid system cleaning capacity via hydraulics modification and wellhole stability by filter cake endurance increase by adding nanosilica is shown as well. The average well construction data of “Neft Dashlary” field was used for the simulation studies conducted for the investigation of hydraulics parameters of reviewed fluids for all series of experiments. The test results were accepted reliable in case of at least 3 times repeatability.

scholarly journals Temperature Augmented Visual Method for Initial Screening of Hydrate Inhibitors

2018 ◽  
Vol 73 ◽  
pp. 1 ◽  
Author(s):  
Tinku Saikia ◽  
Vikas Mahto
Keyword(s):  
Gas Hydrates ◽  
Induction Time ◽  
Drilling Fluid ◽  
Academic Research ◽  
Petroleum Industry ◽  
Visual Methods ◽  
Drilling Mud ◽  
Initial Screening ◽  
Visual Method ◽  
Augmented Method

The formation of gas hydrates in oil & gas pipelines and drilling fluid flow lines is a major issue in the petroleum industry. Gas hydrate inhibitors are normally used to inhibit the formation of gas hydrates in the pipelines/flowlines. Initial screening of hydrate inhibitors and AntiAgglomerants (AA) requires a safe and economical experimental setup/method. Conventional visual method was used for initial screening of hydrate inhibitors in many researches. Some researchers also suggested modified visual methods, but all of them lacks accurate measurement of induction time and found to be inappropriate for experimental solutions like drilling mud, etc. In this work, a temperature augmented visual method was presented which can be used in academic research laboratories for study and initial screening of hydrate inhibitors. This method is capable of parallel screening of inhibitors and determines hydrate induction time precisely. Experiments were conducted to determine the hydrate induction time of different inhibitors using augmented method and compared with conventional visual method. The developed method found to be more precise in determining the induction time of hydrates in all types of experimental solutions.

scholarly journals Study on the stability of a shear-thinning suspension used in oil well drilling

2018 ◽  
Vol 73 ◽  
pp. 10 ◽  
Author(s):  
Flávia M. Fagundes ◽  
Nara B.C. Santos ◽  
João Jorge R. Damasceno ◽  
Fábio O. Arouca
Keyword(s):  
Gamma Ray ◽  
Drilling Fluid ◽  
Shear Thinning ◽  
Drilling Fluids ◽  
Oil Well ◽  
Drilling Process ◽  
Well Drilling ◽  
Constant Rate ◽  
The Stability ◽  
Solid Liquid

In order to avoid solid-liquid gravitational separation of particles in the drilling fluid and cuttings generated in this process, the oil industry has been developing drilling fluids with shear-thinning and thixotropic characteristics. In case of operational stops in the drilling process, the intense sedimentation of these particles can damage the equipment used and the well. In this context, this study simulated an operational stop to obtain information about stability of solids in a paraffin-based suspension with time-dependent shear-thinning behavior, which has already been used in current drilling processes. A long-term test using gamma-ray attenuation technique identified the separation dynamics of a set of micrometric particles belonging to and incorporated into the drilling fluid during operation. This test verified the typical regions of gravitational sedimentation and, through constant concentration curves, indicated that the sedimentation process did not occur at a constant rate. This study also proposed a constitutive equation for pressure on solids.

scholarly journals An Experimental Study on the Performance of Calcium Carbonate Extracted from Eggshells as Weighting Agent in Drilling Fluid

2019 ◽  
Vol 9 (1) ◽  
pp. 3859-3862 ◽  
Author(s):  
R. Iqbal ◽  
M. Zubair ◽  
F. Pirzada ◽  
F. N. Abro ◽  
M. Ali ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Drilling Mud ◽  
Gas Well ◽  
Well Drilling ◽  
Naturally Occurring ◽  
Drilling Operations ◽  
Drilling Cost ◽  
New Methodologies ◽  
The Cost

Drilling mud density is an important factor in drilling operations. The cost of the drilling mud used for oil and gas well drilling can be 10%-15% of the total drilling cost, and the deeper the well, the more the needed drilling mud. This research aims to prepare a mud that provides performance similar to the conventional mud and to lower down the dependency of primitive CaCO3 technology by exploring it from trash/polluted and naturally occurring materials. For that purpose, a mud was prepared by replacing primeval CaCO3 with the CaCO3 derived from eggshells, as eggshells contain CaCO3 in high amounts which range from 70% to 95%. The success of this project will provide an affordable solution and an alternative way to explore new methodologies for obtaining CaCO3. According to the 2017 Report of Pakistan Poultry Association (PPA) 18,000 Million table eggs are consumed per year in Pakistan. The obtained results of this research are quite satisfactory. CaCO3 obtained from eggshells is used in high amounts, 275–410g to achieve density ranges from 9.5 to 11.0 pounds per gallon whereas, pure the needed quantity of pure CaCO3 is 150g to obtain the density of 10.5 pounds per gallon. Apart from this, it is also observed that eggshell based CaCO3 samples are more efficient in rheological properties compared to the market samples of CaCO3 t. The pH of pure CaCO3 sample of 10.5 pounds per gallon density is almost the same with the sample of eggshell CaCO3 of 10.5 pounds per gallon density.

scholarly journals A temperature-pressure coupling model for predicting gas temperature profile in gas drilling

2020 ◽  
pp. 193-193
Author(s):  
Jinjiang Liu ◽  
Wenlin Wu ◽  
Peng Qian ◽  
Shuo Wang
Keyword(s):  
Temperature Profile ◽  
Drilling Fluid ◽  
Physical Parameters ◽  
Drilling Process ◽  
Gas Temperature ◽  
Gas Drilling ◽  
Bottom Hole ◽  
Pump Rate ◽  
Nozzle Size ◽  
Wellbore Temperature

In the gas drilling design, accurate prediction of wellbore temperature profile is very crucial. Different from liquid drilling fluid, physical and thermo-physical parameters of gases are sensitive to the change of pressure and temperature, at the same time, the change of these parameters will react against the wellbore temperature and pressure. Based on the energy conservation principle, a temperature-pressure coupling calculation model was established to predict the gas temperature profile during gas drilling process. The model is solved by cycle coupling iteration method. The calculation shows that annular temperature rises sharply near the wellhead, drops sharply at bottom hole and is a little higher than the formation temperature in other places. Without considering the influence of friction heat, calculated temperature is lower than the actual temperature. Temperature trends are the same under different pump rates and larger pump rate leads to larger temperature range at the wellhead and at bottom hole. Compared with the pump rate, bit nozzle size has more influence on the temperature drop range. Temperature reduction increases from 31.3?C to 57.2?C while bit nozzle size decreases from 539 mm2 to 339 mm2.

Application of Ultrafine Weighting Materials in High-Density Oil-Based Drilling Fluid Technology

2015 ◽  
Vol 814 ◽  
pp. 338-344 ◽  
Author(s):  
Yan Ye ◽  
Wen Hua An ◽  
Da Yin ◽  
Qing Wen Zhang ◽  
Lei Li ◽  
...  
Keyword(s):  
Drilling Fluid ◽  
Fine Powder ◽  
High Density ◽  
Suspension Stability ◽  
Drilling Fluids ◽  
Powder Particle Size ◽  
Drilling Process ◽  
Well Drilling ◽  
Base Oil ◽  
Lost Circulation

High-density oil-based drilling fluid already was considered as one of the most effective technologies during the HTHP Ultra-deep well drilling process. The weighting materials sag such as barite sag, however, always occurred because of the density contrast between the base oil and the weighting material, and hence sag can result in excessive torque, lost circulation and many other problems. This study applied three kinds of ultra-fine powder (particle size≤4μm), which are new weighting materials, to replace the common API barite (particle size10~70μm). The different kinds of high-density oil-based drilling fluids, which weighted with micronized barite, micronized ilmenite, manganese tetraoxide and API barite, were prepared and evaluated separately in lab. The performance data showed that compared with conventional weighting materials, the application of ultrafine powder technology could greatly optimize the rheology of high-density oil-based drilling fluids (ρ ≥ 2.3 g/cm3), reduce the amount of emulsifiers about 50% and dramatically enhance the dynamic suspension-stability of the system, Furthermore, OBM drilling fluids weighted with ultrafine weighting materials almost presented lower viscosity, shear force and sedimentation rate, which will meet more severe requirements of ultra-deep complex well drilling.

Evaluation of Ultrasonic Methods for In-Situ Real-Time Characterization of Drilling Mud

2005 ◽  
Author(s):  
Judith Ann Bamberger ◽  
Margaret S. Greenwood
Keyword(s):  
Physical Properties ◽  
Real Time ◽  
Speed Of Sound ◽  
Direct Contact ◽  
Drilling Fluid ◽  
Drilling Process ◽  
Drilling Mud ◽  
Well Control

A real time multi-functional ultrasonic sensor system is proposed to provide automated drilling fluid monitoring that can improve the capability and development of slimhole and microhole drilling. This type of reliable, accurate, and affordable drilling fluid monitoring will reduce the overall costs in exploration and production. It will also allow more effective drilling process automation while providing rig personnel a safer and more efficient work environment. Accurate and timely measurements of drilling fluid properties such as flow rate, density, viscosity, and solid loading are key components for characterizing rate of drill penetration, providing early warning of lost circulation, and for use in real-time well control. Continuous drilling fluid monitoring enhances drilling economics by reducing the risk of costly drilling downtime, increasing production performance, and improving well control. Investigations conducted to characterize physical properties of drilling mud indicate that ultrasound can be used to provide real-time, in-situ process monitoring and control. Three types of ultrasonic measurements were evaluated which include analysis of in wall, through wall and direct contact signals. In wall measurements provide acoustic impedance (the slurry density and speed of sound product). Through wall and direct contact measurements provide speed of sound and attenuation. This information is combined to determine physical properties such as slurry density, solids concentration and can be used to detect particle size changes and the presence of low levels of gas. The measurements showed that for the frequency range investigated in-wall measurements were obtained over the slurry density range from 1500 to 2200 kg/m3 (10 to 17 pounds solids per gallon of drilling fluid). Other measurements were obtained at densities in the 1500 to 1800 kg/m3 range. These promising measurement results show that ultrasound can be used for real-time in-situ characterization of the drilling process by monitoring drilling mud characteristics.

Hydrogen Bonds-Enhanced Organoclay-Free Oil Based Drilling Fluid System

2017 ◽  
Vol 890 ◽  
pp. 227-234
Author(s):  
Xian Bin Huang ◽  
Guan Cheng Jiang
Keyword(s):  
Hydrogen Bonding ◽  
Hydrogen Bonds ◽  
Drilling Fluid ◽  
Control Agent ◽  
Drilling Fluids ◽  
Oil Well ◽  
Drilling Process ◽  
Well Drilling ◽  
Filtration Loss ◽  
Organophilic Clay

Conventional oil based drilling fluids or muds (OBMs) using organophilic clay as viscosifier and rheological control agent cannot carry drill cuttings and suspend weighting materials effectively in oil well drilling process. It also causes excessive viscosity of drilling fluids, which lowers the rate of penetration. For the sake of solving these problems, in this study, hydrogen bonds-enhanced organoclay-free oil based drilling fluid was proposed. Firstly key additives (emulsifier, filter reducer) for OBMs with highly electronegative groups that might form hydrogen bonds were synthesized. In addition, a hydrogen bonding linker was synthesized and used to connect other additives to form a hydrogen bonding network in OBMs. The properties of drilling fluids were characterized by rheological measurements, static filtration experiments and plugging experiments. Experimental results show that, compared with the conventional OBM, the hydrogen bonds-enhanced organoclay-free OBMs substantially increased yield point (YP) and gel strengths, reduced filtration loss and exhibited a better plugging ability on high-permeability sand cores. Besides, a higher stability was also observed.

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