Assessment of Using Copper Nitrate for Scavenging Hydrogen Sulfide While Drilling Sour Horizontal Wells

2019 ◽  
Vol 141 (12) ◽  
Author(s):  
Salaheldin Elkatatny ◽  
Salem Basfer ◽  
Reyad Shawabkeh ◽  
Mohamed Bahgat ◽  
Mohamed Mahmoud
Keyword(s):  
Hydrogen Sulfide ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
Copper Nitrate ◽  
Drilling Mud ◽  
Liquid Sulfur ◽  
Rate Behavior ◽  
Effect Of Copper ◽  
New Formulation ◽  
Very High

The solubility of hydrogen sulfide (H2S) is very high in different liquids such as water or liquid sulfur. The existence of H2S results in local corrosion and causes cracking to the steel even if the concentration of H2S is low. The objectives of this paper are to (1) evaluate copper nitrate as an H2S scavenger while drilling sour horizontal and multilateral wells and (2) investigate the effect of copper nitrate on the drilling fluid rheological properties and drill pipe corrosion. The obtained results showed that by adding the copper nitrate (1 lb/bbl) to the drilling mud there was no change in the shear stress–shear rate behavior, and the yield point (YP) plastic viscosity (PV) ratio was increased by 20% indicating good hole cleaning. In addition, the filtrate volume reduced by 26% and the filter cake thickness decreased by 50%. The new formulation of the drilling fluid with the copper nitrate is not corrosive (the corrosion rate was 0.00084 lb/ft2 after 24 h at 212 °F). Breakeven experiments showed that adding copper nitrate to the drilling fluid doubled the adsorption capacity when compared with triazine and tripled the capacity when compared with Scav1 when using I lb of the commercial H2S scavenger per bbl of the drilling fluid.

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

New Hybrid Hole Cleaning Model for Vertical and Deviated Wells

2019 ◽  
Vol 142 (3) ◽  
Author(s):  
Ahmed Abdulhamid Mahmoud ◽  
Mahmoud Elzenary ◽  
Salaheldin Elkatatny
Keyword(s):  
Drilling Fluid ◽  
Drill Pipe ◽  
Real Field ◽  
Oil Well ◽  
Hole Size ◽  
Drilling Mud ◽  
Rate Of Penetration ◽  
Hole Cleaning ◽  
Fluid Rheology ◽  
Pipe Size

Abstract Drilled cuttings transportation from the bottom hole to the surface to maintain efficient hole cleaning is a challenging issue while drilling vertical, deviated, high angle, and extended reach wells. This is attributed to the huge number of the parameters affecting the ability of the drilling fluid to leave the drilled solids. Drilling fluid rheology, density, and flowrate, hole size, drill pipe size, hole inclination, and rate of penetration are all confirmed experimentally to affect the effectiveness of the drilling mud to lift the fluid and keep a clean hole. Several parameters were developed earlier to account for the hole cleaning conditions, most of these parameters lake to including many of the parameters influencing the hole cleaning conditions. In this study, a new hole cleaning parameter was developed, which is called hole cleaning factor (HCF). The HCF parameter was developed based on the cutting carrying index (CCI) parameter, and it considered the effect of the drilling fluid rheology, density, and flowrate, the hole size, drill pipe size, hole inclination, and rate of penetration to identify the hole cleaning condition. The HCF model was applied in an oil well from North Africa to predict the hole cleaning condition at different 135 points where the depth ranges from 33 to 12,854 ft. The outcomes of the HCF were well correlated with the real-field scenarios, where the crew members faced by erratic torque with differentiation in drilling parameters resulting in worst stuck pipe conditions at the same depths as predicted by the HCF parameter. The developed HCF model will help the drilling engineers to avoid many issues while drilling such as cutting accumulation and drill pipe sticking. The predictability of the HCF model was compared with commercially available software, and the results indicated a good match between the predictability of the HCF model and the commercial software.

scholarly journals Corrosion Analysis On Internal Plastic Coating Drill Pipe 5 Inch 19.50 PPF Grade G-105

2021 ◽  
Vol 6 (1) ◽  
pp. 27-32
Author(s):  
Ario Oktora ◽  
◽  
Eka Sri Yusmartini ◽  
Muhammad Faizal
Keyword(s):  
Drilling Fluid ◽  
Drill Pipe ◽  
Drilling Mud ◽  
Drilling Depth ◽  
Operational Costs ◽  
Plastic Coating ◽  
Long Time ◽  
Drill Pipes ◽  
Geothermal Drilling ◽  
Oil Gas

In the oil, gas and geothermal drilling industry, the use of a drill pipe is vital for its use as an addition to the length of the drilling depth. Another function of the drill pipe is to channel high pressure drilling mud (drilling fluid / fluid) to the drill bit. During the drill pipe operation, several problems were encountered, such as broken, bent, and leaking or wash-out drill pipes. This is very detrimental to the company because the time to replace a new drill pipe will take a long time, and will disrupt the drilling program which will result in high drilling operational costs. This study analyzes the corrosion of the drill pipe which can cause damage to the drill pipe. The analysis on the drill pipe includes analysis of thickness, corrosion rate, remaining life, internal plastic coating damage, and SEM. The results show that the storage and use of drill pipes greatly affect the conductivity of the drill pipe.

scholarly journals The effect of drill–pipe rotation on improving hole cleaning using polypropylene beads in water-based mud at different hole angles

2019 ◽  
Vol 10 (3) ◽  
pp. 1253-1262 ◽  
Author(s):  
A. Katende ◽  
B. Segar ◽  
I. Ismail ◽  
F. Sagala ◽  
H. H. A. R. Saadiah ◽  
...  
Keyword(s):  
Buoyancy Force ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
Drilling Mud ◽  
Hole Cleaning ◽  
Drag Forces ◽  
Water Based ◽  
Drilling Operations ◽  
Cost Efficient ◽  
Pipe Rotation

AbstractHole cleaning is always a problem, particularly during drilling operations, and drilling fluid plays an important role in transporting drill cuttings through an annular section of wellbore to the surface. To transport the cuttings, a water-based mud with added polypropylene beads was selected since it is environmentally friendly and cost efficient. The polypropylene beads help to transport cuttings by providing an additional buoyancy force that lifts the cuttings to the surface via the influence of collision and drag forces. This experiment was performed using a 20 ft test section, 10 ppg drilling mud and 0.86 m/s annular velocity in a laboratory scale rig simulator, and the concentration of polypropylene beads was varied from 0 to 8 ppb. As the concentration of polypropylene increases, the cutting transport ratio also increases. It was observed that the fewest cuttings are lifted at a critical angle of 60°, followed by 45°, 30°, 90° and 0°. Additionally, cutting sizes had moderate effects on the cutting lifting efficiency, where smaller cutting sizes (0.5–1.0 mm) are easier to lift than larger cutting sizes (2.0–2.8 mm). Furthermore, a study of buoyancy force and impulsive force was conducted to investigate the cutting lifting efficiencies of various concentrations of polypropylene beads. This lifting capacity was also assisted by the presence of polyanionic cellulose (PAC), which increases the mud carrying capacity and is effective for smaller cuttings. The results show that in the presence of pipe rotation, the cutting lifting efficiency is slightly enhanced due to the orbital motion provided by the drill pipe for better hole cleaning. In conclusion, polypropylene beads combined with pipe rotation increase the cutting transport ratio in the wellbore.

Investigation of Tool-Joint Effect on Non-Newtonian Drilling Fluids Following the Herschel–Bulkley Model Flow Behavior in Oil Well Drilling

2021 ◽  
Author(s):  
Ardeshir Gholami ◽  
Zohreh Mansoori ◽  
Majid Saffar Aval ◽  
Goodarz Ahmadi
Keyword(s):  
Pressure Loss ◽  
Drilling Fluid ◽  
Flow Behavior ◽  
Drill Pipe ◽  
Fluid Flows ◽  
Joint Effect ◽  
Drilling Mud ◽  
Pressure Losses ◽  
Drilling Muds ◽  
Tool Joint

Abstract The prediction of frictional pressure loss in many oil wells drillings is of the utmost importance. Most studies in this area concerned fluid flow in pipes and annulus in order to predict friction losses. However, studies on the tool-joint effect in frictional pressure estimations were limited to only a few experimental and theoretical studies on water-based power-law drilling muds. (Tool-joint is the part in which two drill strings connect where the annulus has a gradual decrease and increase, respectively). The tool-joint plays an important role in extending the drill pipe, and its effect on pressure losses cannot be ignored. As of today, drilling muds must have certain qualities such as providing formation integrity, transporting the cuttings from bit to surface, drill pipe lubrication and heat transfer, and low-pressure loss to perform as a qualified and effective drilling fluid. Therefore, drilling muds have become more complex and expensive, and the process of choosing appropriate drilling muds is of great importance. For this reason, oil-based viscoplastic drilling muds are being used in more drilling operations, but for these drilling muds, almost no studies were conducted to predict the effect of the tool-joints on flow behavior and pressure loss. In this paper, the behavior of fluid flows and frictional pressure losses in weld-on tool-joints of different grades according to the IADC standard manual was studied using CFD simulations. The simulations were conducted using a drilling fluid with viscoplastic properties, following the Herschel–Bulkley model of Non-Newtonian fluids. And the characteristics of fluid flows in these tool-joints under different thermal boundary conditions were studied. The results show that tool-joints significantly affect the frictional pressure loss in the annulus. We also provided an accurate pressure loss prediction for the flow of oil-based viscoplastic muds passing through the tool-joint geometry. Furthermore, assuming the thixotropic behavior using the Moore-Cheng model for the drilling mud, the results showed that the flow behavior does not differ significantly from the Herschel-Bulkley drilling fluid in the range of study.

Residual phase lignin in haft cooking related to the conditions in the cook

1997 ◽  
Vol 12 (4) ◽  
pp. 225-229
Author(s):  
Cart-in A-S. Gustavsson ◽  
Chritofer T. Lindgren ◽  
Mikael E. Lindström
Keyword(s):  
Hydrogen Sulfide ◽  
Ionic Strength ◽  
Sodium Ion ◽  
Ion Concentration ◽  
Constant Composition ◽  
Hydroxide Ion ◽  
Sulfide Ion ◽  
Residual Phase ◽  
Kraft Cooking ◽  
Very High

Abstract The amount of lignin reacting according to the slow residual phase, i.e. the residual phase lignin, is in many perspectives an interesting issue. The purpose of the present investigation was to develop a mathematical model to show how the amount of residual phase lignin in the kraft cooking of spruce chips (Picm ahies) depends on the conditions in the earlier phases of the cook. The variables studied were hydroxide ion concentration, hydrogen sulfide ion concentration and ionic strength. The liquor-to-wood ratio during pulping was very high to maintain approximately constant chemical concentrations throughout each experiment (so called "constant composition" cooks). An increase in hydroxide ion concentration andtor hydrogen sulfide ion concentration leads to a decrease in the amount of residual phase lignin, while an increase in ionic strength, i.e. sodium ion concentration, leads to an increase. A signiticant result is that the hydrogen sulfide ion concentration has a pronounced influence on the amount of residual phase lignin during a cook at a low hydroxide ion concentration. The amount of residual phase lignin expressed as % lignin on wood, L,, can be described by the following equation developed for "constant composition" cooks (when cooking with a constant sodium ion concentration of 2 mol/L): LT=0,55-0.32*[HO-](-1,3)*ln[HS-] This equation is valid for a concentration of HO- in the range from 0.17 to 1.4, and a hydrogen sulfide ion concentration from 0.07 to 0.6 mol/L.

Scaling Formulae for the Wellbore Hydraulics Similitude with Drill Pipe Rotation and Eccentricity

2021 ◽  
Author(s):  
Thad Nosar ◽  
Pooya Khodaparast ◽  
Wei Zhang ◽  
Amin Mehrabian
Keyword(s):  
Power Law ◽  
Flow Rate ◽  
Annular Flow ◽  
Rotation Speed ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
Flow Loop ◽  
Annular Flows ◽  
Fluid Rheology ◽  
Pipe Rotation

Abstract Equivalent circulation density of the fluid circulation system in drilling rigs is determined by the frictional pressure losses in the wellbore annulus. Flow loop experiments are commonly used to simulate the annular wellbore hydraulics in the laboratory. However, proper scaling of the experiment design parameters including the drill pipe rotation and eccentricity has been a weak link in the literature. Our study uses the similarity laws and dimensional analysis to obtain a complete set of scaling formulae that would relate the pressure loss gradients of annular flows at the laboratory and wellbore scales while considering the effects of inner pipe rotation and eccentricity. Dimensional analysis is conducted for commonly encountered types of drilling fluid rheology, namely, Newtonian, power-law, and yield power-law. Appropriate dimensionless groups of the involved variables are developed to characterize fluid flow in an eccentric annulus with a rotating inner pipe. Characteristic shear strain rate at the pipe walls is obtained from the characteristic velocity and length scale of the considered annular flow. The relation between lab-scale and wellbore scale variables are obtained by imposing the geometric, kinematic, and dynamic similarities between the laboratory flow loop and wellbore annular flows. The outcomes of the considered scaling scheme is expressed in terms of closed-form formulae that would determine the flow rate and inner pipe rotation speed of the laboratory experiments in terms of the wellbore flow rate and drill pipe rotation speed, as well as other parameters of the problem, in such a way that the resulting Fanning friction factors of the laboratory and wellbore-scale annular flows become identical. Findings suggest that the appropriate value for lab flow rate and pipe rotation speed are linearly related to those of the field condition for all fluid types. The length ratio, density ratio, consistency index ratio, and power index determine the proportionality constant. Attaining complete similarity between the similitude and wellbore-scale annular flow may require the fluid rheology of the lab experiments to be different from the drilling fluid. The expressions of lab flow rate and rotational speed for the yield power-law fluid are identical to those of the power-law fluid case, provided that the yield stress of the lab fluid is constrained to a proper value.

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.

Comparative Analysis of the Rheological Behaviour of Irvingia Gabonensis Ogbono and Foreign Polymer for Bentonite Formulated Mud.

2021 ◽  
Author(s):  
Emmanuel Ayodele ◽  
David Ekuma ◽  
Ikechukwu Okafor ◽  
Innocent Nweze
Keyword(s):  
Rheological Properties ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Research Work ◽  
Rheological Behaviour ◽  
Oil And Gas Industry ◽  
Drilling Mud ◽  
Gas Industry ◽  
Local Product ◽  
Irvingia Gabonensis

Abstract Drilling fluid are complex fluids consisting of several additives. These additives are added to enhance and control the rheological properties (such as viscosity, gel strength and yield point) of the mud. These properties are controlled for effective drilling of a well. This research work is focused on determining the rheological behavior of drilling mud using industry-based polymer and Irvingia Gabonensis (ogbono) as viscosifiers. Water based muds were formulated from the aforementioned locally sourced viscosifier and that of the conventional used viscosifier (Carboxylmetyl cellulose, CMC). Laboratory tests were carried out on the different muds formulated and their rheological properties (such as yield stress, shear stress, plastic viscosity and shear rate) are evaluated. The concentration of the viscosifiers were varied. The expected outcome of the research work aims at lowering the total drilling cost by reducing the importation of foreign polymer which promotes the development of local content in the oil and gas industry. The research compares the rheology of mud samples and the effect of varying the concentration (2g, 4g, 6g, 8g, and 10g) of both CMC and Ogbono and determining the changes in their rheological properties. The total volume of each mud sample is equivalent to 350ml which represent one barrel (42gal) in the lab. From the result, at concentration of 2g, the ogbono mud has a better rheology than the CMC mud, but at a concentration above 2g, CMC mud shows a better rheology than ogbono mud, that is, as the concentration of CMC is increased, the rheological properties of the mud increased while as the concentration of ogbono is increased the rheological properties decreased. The viscosity of the drilling fluid produced from the ogbono were lower than that of CMC, it could be used together with another local product such as cassava starch, offor or to further improve the rheology and then be a substitute to the conventional viscosifiers.

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.

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