A laboratory set up for the measurement of wellbore instability due to erosion of unconsolidated formations

2015 ◽  
Vol 55 (1) ◽  
pp. 329
Author(s):  
Ghazal Avijegon ◽  
Joel Sarout
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Ct Scanning ◽  
High Flow ◽  
Annular Space ◽  
Chemical Additives ◽  
Flow Loop ◽  
Coiled Tubing ◽  
Early Results ◽  
Set Up

Borehole instability is a recurring issue encountered during drilling operations in the oil and gas, and mining industries. In exploration drilling using coiled tubing technology, boreholes are slim and the annular space is usually tight. Similar situations are also encountered around the drill-collar section in standard drilling where the annular space can be tight; therefore, the drilling fluid has a high flow velocity and a turbulent flow regime is dominant. The flow conditions are the governing conditions for borehole erosion, which can lead to borehole instability. Erosion of the borehole introduces more cuttings into the annulus space, which is detrimental to the efficiency of cuttings transport and brings contamination to samples being retrieved at the surface for geochemistry and mineral analyses. In this peer-reviewed paper a new laboratory set-up aimed at estimating borehole erosion in pre-drilled rock samples is reported. A flow loop unit is used, which allows the injection of high flow-rates of any type of fluid composed of chemical additives and simulated cuttings. Early results of an exploratory study are reported in terms of changes in the internal borehole diameter (ID) of the sample before and after the erosion experiment. These were recorded using X-ray CT scanning. This change in ID acts as a measure of the formation’s erodibility, from which shear stress is estimated.

Maximum Drag Reduction Asymptote of Polymeric Fluid Flow in Coiled Tubing

2008 ◽  
Vol 131 (1) ◽  
Author(s):  
Subhash N. Shah ◽  
Yunxu Zhou
Keyword(s):  
Drag Reduction ◽  
Oil And Gas ◽  
Guar Gum ◽  
Oil And Gas Industry ◽  
Flow Loop ◽  
Polymeric Fluids ◽  
Curvature Ratio ◽  
Coiled Tubing ◽  
Industry Applications ◽  
Maximum Drag Reduction

This study experimentally investigates the drag reduction characteristics of the most commonly used polymer fluids in coiled tubing applications. The flow loop employed consists of 12.7mm straight and coiled tubing sections. The curvature ratio (a∕R, where a and R are the radii of the tubing and the reel drum, respectively) investigated is from 0.01 to 0.076, which covers the typical curvature ratio range encountered in the oil and gas industry applications. Fluids tested include xanthan gum, guar gum, and hydroxypropyl guar at various polymer concentrations. It is found that the drag reduction in coiled tubing is significantly lower than that in straight tubing, probably due to the effect of secondary flow in curved geometry. The onset of drag reduction is also found to be delayed as the curvature ratio was increased. A correlation for the maximum drag reduction (MDR) asymptote in coiled tubing is developed. When the curvature ratio is set to zero, the new correlation reduces to the well-known Virk’s MDR asymptote for dilute polymer solutions in straight pipes. A new drag reduction envelope is proposed for the analysis of drag reduction behavior of polymeric fluids in coiled tubing. Application of the new drag reduction envelope is also discussed.

Coiled tubing drilling for unconventional reservoirs: the importance of cuttings transport in directional drilling

2014 ◽  
Vol 54 (1) ◽  
pp. 329
Author(s):  
Mohammadreza Kamyab ◽  
Nelson Chin ◽  
Vamegh Rasouli ◽  
Soren Soe ◽  
Swapan Mandal
Keyword(s):  
Rheological Properties ◽  
Oil And Gas ◽  
Fluid Velocity ◽  
Oil And Gas Industry ◽  
Unconventional Reservoirs ◽  
Directional Drilling ◽  
Flow Loop ◽  
Cuttings Transport ◽  
Cleaning Efficiency ◽  
Coiled Tubing

Coiled tubing (CT) technology has long been used in the oil and gas industry for workover and stimulation applications; however, the application of this technology for drilling operations has also been used more recently. Faster tripping, less operational time, continuous and safer operation, and the requirement for fewer crew members are some of the advantages that make CT a good technique for drilling specially deviated wells, in particular, in unconventional reservoirs for the purpose of improved recovery. Cuttings transport in deviated and horizontal wells is one of the challenges in directional drilling as it is influenced by different parameters including fluid velocity, density and rheological properties, as well as hole deviation angle, annulus geometry and particle sizes. To understand the transportation of the cuttings in the annulus space, therefore, it is useful to perform physical simulations. In this study the effect of wellbore angle and fluid rheological properties were investigated physically using a flow loop that has been developed recently for this purpose. The minimum transportation velocity was measured at different angles and an analysis was performed to study the fluid carrying capacity and hole cleaning efficiency. The results indicated how the change in wellbore angle could change the cuttings transport efficiency.

Micro Foam Drilling Fluid System Performance Research and Application

2013 ◽  
Vol 868 ◽  
pp. 601-605 ◽  
Author(s):  
Nan Nan Wang ◽  
Yong Ping Wang ◽  
Dong Zhang ◽  
Hui Min Tang
Keyword(s):  
Oil And Gas ◽  
Drilling Fluid ◽  
Field Application ◽  
Fluid System ◽  
Foaming Agent ◽  
Fluid Properties ◽  
Single Well ◽  
Set Up ◽  
Reservoir Protection ◽  
Foam Drilling

Micro foam drilling fluid has irreplaceable advantages in reservoir protection, drilling speed, improve the cementing quality and leak plugging, especially suitable for the "three low" Daqing peripheral oilfield Haita area. Indoor the foaming agent, foam stabilizing agent were screened, Preferably choose the efficient composite foaming agent, stabilizer and thickener, the drilling fluid system is transformed into micro foam drilling fluid system. And evaluate the inhibition, anti temperature, anti pollution (anti clay, calcium, anti kerosene) reservoir protection capability, The micro foam drilling fluid leakage, oil reservoir protection, speed up mechanism and micro foam drilling fluid rheological characteristics were studied, Set up a specific rheological model of Micro Foam Drilling fluid, According to the characteristics of Gulong oilfield,R&D the calculation software of Micro Foam drilling fluid density changes with the temperature, pressure and provide guidance for safe drilling. Field application shows that the system has the advantages of simple preparation,convenient maintenance, easy transformation, drilling fluid properties can meet the requirements of drilling technology, To ensure the safe, fast, and high quality drilling of oil and gas,reduce pollution,improve the productivity of a single well.

scholarly journals Porównanie wyników metod pomiaru skuteczności usuwania osadu płuczkowego

Nafta-Gaz ◽  
2021 ◽  
Vol 77 (1) ◽  
pp. 34-46
Author(s):  
Marcin Kremieniewski ◽  
Keyword(s):  
Fluid Flow ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Measurement Methods ◽  
Annular Space ◽  
Drilling Mud ◽  
Mud Cake ◽  
Incomplete Removal ◽  
Cement Sheath ◽  
Flow Drilling

The proper cleaning of the annular space before cementing is one of the most important factors affecting the proper sealing of the casing column. Inadequate or incomplete removal of the mud cake or residues of the mud may result in the formation of uncontrolled gas outflows (migration or exhalation) at the contact of the cement sheath with the rock formation and with the surface of run-down casing. It is related to the lack of compatibility in the contact of the mud and the cement. Additionally, the lack of proper cleaning of the annular space will reduce the adhesion value of the cement sheath to the contact surface. The result of the above may be the lack of adequate stabilization of the column of pipes due to its weakened connection in the lower part with the wall, and in the upper part with the previous column of larger diameter pipes. Therefore, to improve both the tightness of the borehole as well as the quality of the cementation condition, laboratory tests of the efficiency of cleaning the annular space are carried out by measuring the efficiency of washing mud removal. So far, measuring the efficiency of mud removal or the effect of washing utilization have been done using a rotary viscometer. During the test, a mud cake is produced on the rotor surface and then removed with washing liquid. Recently, the Oil and Gas Institute – National Research Institute developed a new method for measuring the efficiency of drilling mud removal by using a newly developed drilling fluid flow simulator (Patent P.423842). The device enables the simulation of the drilling fluid flow (drilling fluid, washing fluid, spacer) in the simulated annular space. It is possible to select the parameters of the flow (delivery rate) and the contact time of the liquid with the tested surface. Due to the different measurement principles during the tests with the viscometer and the simulator, it was decided to conduct a comparison and determine the degree of convergence of the discussed methods. The same rinsing liquids were tested to remove the same type of mud, but using different measurement methods. The obtained values of mud removal efficiency were subjected to the correlation analysis, which made it possible to compare the results of the analyzed measurement methods.

Maximum Drag Reduction Asymptote of Polymeric Fluid Flow in Coiled Tubing

2006 ◽  
Author(s):  
Subhash N. Shah ◽  
Yunxu Zhou
Keyword(s):  
Drag Reduction ◽  
Oil And Gas ◽  
Guar Gum ◽  
Oil And Gas Industry ◽  
Flow Loop ◽  
Polymeric Fluids ◽  
Curvature Ratio ◽  
Coiled Tubing ◽  
Industry Applications ◽  
Maximum Drag Reduction

This study experimentally investigates the drag reduction characteristics of the most commonly used polymer fluids in coiled tubing applications. The flow loop employed consists of 1/2-in. straight and coiled tubing sections. The curvature ratio (a/R where a and R are the radii of the tubing and the reel drum respectively) investigated is from 0.01 to 0.076 which covers the typical curvature ratio range encountered in the oil and gas industry applications. Fluids tested include xanthan gum, guar gum, and HPG (hydroxypropyl guar) at various polymer concentrations. It is found that the drag reduction in coiled tubing is significantly lower than that in straight tubing, probably due to the effect of secondary flow in curved geometry. The onset of drag reduction is also found to be delayed as the curvature ratio was increased. A correlation for the maximum drag reduction (MDR) asymptote in coiled tubing is developed. When the curvature ratio is set to zero, the new correlation reduces to the famous Virk's MDR asymptote for dilute polymer solutions in straight pipes. A new drag reduction envelope is also proposed for the analysis of drag reduction behavior of polymeric fluids in coiled tubing. Application of the new drag reduction envelope is also discussed.

Monitoring Effects of Catchment Management Practices on Phosphorus Loads into the Eutrophic Peel-Harvey Estuary, Western Australia

1986 ◽  
Vol 18 (4-5) ◽  
pp. 53-61 ◽  
Author(s):  
P. B. Birch ◽  
G. G. Forbes ◽  
N. J. Schofield
Keyword(s):  
Management Practices ◽  
Major Change ◽  
High Flow ◽  
Catchment Management ◽  
Flow Rates ◽  
Early Results ◽  
Phosphorus Loads ◽  
Time Of Year ◽  
High Runoff

Early results from monitoring runoff suggest that the programme to reduce application of superphosphate to farmlands in surrounding catchments has been successful in reducing input of phosphorus to the eutrophic Peel-Harvey estuary. In the estuary this phosphorus fertilizes algae which grow in abundance and accumulate and pollute once clean beaches. The success of the programme has been judged from application of an empirical statistical model, which was derived from 6 years of data from the Harvey Estuary catchment prior to a major change in fertilizer practices in 1984. The model relates concentration of phosphorus with rate of flow and time of year. High phosphorus concentrations were associated with high flow rates and with flows early in the high runoff season (May-July). The model predicted that the distribution of flows in 1984 should have resulted in a flow-weighted concentration of phosphorus near the long-term average; the observed concentration was 25% below the long-term average. This means that the amount of phosphorus discharged into the Harvey Estuary could have been about 2 5% less than expected from the volume of runoff which occurred. However several more years of data are required to confirm this trend.

scholarly journals Optimization of Silver Nanoparticle Separation Method from Drilling Waste Matrices

Energies ◽  
2021 ◽  
Vol 14 (7) ◽  
pp. 1950
Author(s):  
Monika Gajec ◽  
Ewa Kukulska-Zając ◽  
Anna Król
Keyword(s):  
Inductively Coupled Plasma ◽  
Oil And Gas ◽  
Produced Water ◽  
Technological Development ◽  
Drilling Fluid ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Inductively Coupled ◽  
Drilling Waste ◽  
Wastewater Samples

Significant amounts of produced water, spent drilling fluid, and drill cuttings, which differ in composition and characteristics in each drilling operation, are generated in the oil and gas industry. Moreover, the oil and gas industry faces many technological development challenges to guarantee a safe and clean environment and to meet strict environmental standards in the field of processing and disposal of drilling waste. Due to increasing application of nanomaterials in the oil and gas industry, drilling wastes may also contain nanometer-scale materials. It is therefore necessary to characterize drilling waste in terms of nanomaterial content and to optimize effective methods for their determination, including a key separation step. The purpose of this study is to select the appropriate method of separation and pre-concentration of silver nanoparticles (AgNPs) from drilling wastewater samples and to determine their size distribution along with the state of aggregation using single-particle inductively coupled plasma mass spectrometry (spICP-MS). Two AgNP separation methods were compared: centrifugation and cloud point extraction. The first known use of spICP-MS for drilling waste matrices following mentioned separation methods is presented.

Field Determination of Fracture Propagation Mode Using Downhole Pressure Data

2015 ◽  
Author(s):  
Ali Daneshy ◽  
Chad Touchet ◽  
Fred Hoffman ◽  
Mike McKown
Keyword(s):  
Propagation Mode ◽  
Fluid Migration ◽  
Pressure Data ◽  
Isolation System ◽  
Fracture Orientation ◽  
Coiled Tubing ◽  
Treatment Data ◽  
Set Up ◽  
Adjacent Fractures ◽  
First Time

Abstract This paper presents the analysis results of 60 single stage fracturing treatments performed in a horizontal well using cemented casing sleeves and a coiled tubing deployed frac isolation system as the completion method. In this carefully set-up and executed treatment, separation between the toe stages was 97 feet, and near the heel it was 55 feet. Pressure data was collected above and below the retrievable plug used for stage isolation. This data was used for analysis of fracturing treatment data which included mode of propagation, completion efficiency, and a rough estimate of fracture orientation. The analysis showed that; There was no interaction between adjacent fractures during five of the sixty fracturing stages. None of these was in the well interval with shorter fracture spacingFracture shadowing occurred during six fracture stages, again none in the shorter spacing intervalMinor cement defects (micro-annuli) caused some fluid migration into the passive segment of the well. This happened in 27 stages. Of these; In eleven cases the cement defects were plugged after a while, causing the migration of fracturing fluid into the passive interval to stop.In sixteen other cases the fluid migration through cement micro-annuli continued during fracturing.During ten stages, defective zone isolation and fluid migration caused a pressure increase of several hundred psi in the passive segment of the well. But this did not result in extension of passive fractures.The volume of migrated slurry due to inadequate zone isolation was mostly a very small fraction of the injected volume.During five stages poor cement quality hampered stage isolation and caused immediate link between adjacent active and passive intervals and extension of passive fractures.The data indicate possible connection between the active and one passive fracture in four stages.Shorter spacing between stages increased the incidents of fluid migration due to poor cement qualityThe fracturing pressure variations during the treatments did not indicate presence of large stress shadowingA rough estimation of fracture orientation indicates that they were likely to be vertical and nearly perpendicular to the wellbore.The fracture growth pattern can best be described as off-balance. To our knowledge, this is the first time existence of direct communication between adjacent fractures has been observed through actual pressure interference data.

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.

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.

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