Relevant bibliographies by topics / Underbalanced drilling (Petroleum engineering)

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  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers

Academic literature on the topic 'Underbalanced drilling (Petroleum engineering)'

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Published: 4 June 2021
Last updated: 17 February 2022

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Journal articles on the topic "Underbalanced drilling (Petroleum engineering)"

1

Aremu, Olukayode J., and Samuel O. Osisanya. "Reduction of Wellbore Effects on Gas Inflow Evaluation Under Underbalanced Conditions." SPE Journal 13, no. 02 (June 1, 2008): 216–25. http://dx.doi.org/10.2118/91586-pa.

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Summary Wellbore storage effects have been identified to significantly smear the accuracy of evaluating reservoir productivity through the fluid outflow rate from the annulus during underbalanced drilling. Such effects have continuously introduced considerable errors in characterizing the reservoir during underbalanced drilling. Conceptually, because of the ready volume-changing ability of the gas, wellbore storage becomes a determining factor during underbalanced drilling of a gas reservoir. Wellbore storage could either cause decrease (unloading effects) or increase (loading effects) in the annular gas density, depending on the choke opening procedures. Correspondingly, annular fluid outflow rate is considerably affected. Because it is practically difficult to deduct the fluid-flow rate attributable to the wellbore storage from the total fluid outflow rate, reducing the influence of wellbore effects on the evaluation of gas-reservoir productivity is presented in this study. Volumetric production analysis at the wellbore-sand face is introduced through a mathematical modeling of inflow of gas bubbles into the wellbore. This mathematical modeling utilizes forces such as the viscous force, drilling fluid ejecting forces from the bit nozzles, buoyancy, interfacial tension, and gas-reservoir forces for its analyses. Some analytical results that are overshadowed by wellbore storage are presented and supported by extensive experimental studies. Introduction One of the derivable benefits from underbalanced drilling is the ability to evaluate the productivity of a reservoir during drilling operations (Beiseman amd Emeh 2002). Other benefits include little to no invasive formation damage; higher penetration rate, especially in hard rocks; and lower cost of drilling operations if underbalanced drilling could consistently be maintained (Bennion et al. 2002). However, from the real-time bottomhole pressure measurements taken while drilling, it is obvious that continuous maintenance of underbalanced conditions at the bottomhole is difficult. Pressure surges that occur during some subsidiary operations such as pipe connections and surveys tend to jeopardize the avoidance of invasive formation damage (Yurkiw et al. 2002). From the recent literature, reservoir evaluation has been approached through the estimation of the reservoir fluids flow rates into the wellbore. Assumption of the reservoir fluid inflow rate being the difference in the drilling fluid surface injection rate and the fluid outflow rate from the annulus has consistently been used (Kardolus and van Kruijsdijk 1997; Larsen and Nilsen 1999; Hunt and Rester 2000; Kneissl 200l; Lorentzen et al. 2001; Vefring et al. 2002; Biswas et al. 2003). So far, efforts in modeling reservoir fluid inflow have been concentrated on the oil inflow (Kardolus and van Kruijsdijk 1997; Larson and Nilsen 1999; Hunt and Rester 2000; Kneissl 200l; Lorentzen et al. 2001; Vefring et al. 2002; Biswas et al. 2003). These present approaches to production evaluation and characterization of gas formation recognize the important effects of wellbore phenomena, but have not been able to provide adequate means of reducing the influences. These wellbore phenomena include the gas-bubble coalescence and breakage, and bubble expansion and compression that are not possible to practically quantify during bubble annular upward flow. Because the present approaches involve the comparison of the surface fluid injection rate with the annular outflow rate, the influence of these phenomena on the gas formation evaluation is inevitable. Unfortunately, all of these wellbore phenomena cause additional annular flow rates that cannot be individually and practically measured, and thus the reservoir fluid inflow rate at the bottomhole cannot be practically modified for their influences. Not recognizing the impact of such additional annular flow rates could cause misjudgment of the inflow capabilities of the gas reservoir. In order to properly alleviate these effects on gas-inflow analyses, a volumetric production analysis at the wellbore-sand face contact is presented in this study. The conduction of gas-inflow analyses have been similarly performed as the liquid inflow in the petroleum engineering sectors. Practically speaking, gas inflow into a denser fluid system is bubbly in character, while liquid inflow is streaky. It is, therefore, proper to mathematically couple the forces of the viscosity, surface tension, inertia, and buoyancy that are responsible for gas-bubble formation or development to the drilling-fluid-ejecting forces from the bit nozzles and the reservoir forces in modeling gas-inflow scenarios. Therefore, with the existence of underbalanced pressure conditions at the bottomhole, the modeling procedures presented in this study could be used for predicting the total volume of gas inflow with significantly reduced wellbore effects while drilling. This is possible as long as an underbalanced condition is maintained at the bottomhole. This is a computer-simulation approach that utilizes real-time surface measurable underbalanced drilling data to predict quantitative gas volumes at the wellbore-sand face during drilling. As an additional advantage, the analyses do not involve knowing the gas inflow rate at the sand face, which could be difficult to accurately measure during underbalanced drilling operations. Standard engineering concepts are used to estimate downhole conditions for the analyses. Among the benefits from this study are reduced influences of the wellbore effects on the evaluation of gas-reservoir volumetric productivity during underbalanced drilling, the revealing of possible greater near-wellbore damage in some gas reservoirs, and possible in-situ permeability impairment through pore space compression.
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Bennion, D. B., F. B. Thomas, R. F. Bietz, and D. W. Bennion. "Underbalanced Drilling: Praises and Perils." SPE Drilling & Completion 13, no. 04 (December 1, 1998): 214–22. http://dx.doi.org/10.2118/52889-pa.

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3

Zhang, Wei, Wenhui Dang, Wenbo Zhang, Xiaorui Sun, and Zhongxi Zhu. "Underbalanced Drilling Optimum Methodology." E3S Web of Conferences 198 (2020): 03004. http://dx.doi.org/10.1051/e3sconf/202019803004.

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A methodology to properly screen all UBD techniques to reduce failure/misapplication and align objectives with expectations had been absent. The paper addresses the latest enhancements to better understand and screen options for UBD operations according to two aspects: formation applicability and engineering applicability. The screening tool considers a range of economic and technical parameter to provide a relative ranking for each candidate of the Underbalanced drilling (UBD) technique. As a case, the methodology was available to optimize the UBD techniques in a risky exploration well in Xinjiang oilfield, which provided guidance and technical support to screen the UBD candidate, design the drilling modeconversion, and establish the emergency schedule.
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Wei, Na, YingFeng Meng, Gao Li, LiPing Wan, ZhaoYang Xu, XiaoFeng Xu, and YuRui Zhang. "Cuttings Transport Models and Experimental Visualization of Underbalanced Horizontal Drilling." Mathematical Problems in Engineering 2013 (2013): 1–6. http://dx.doi.org/10.1155/2013/764782.

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Aerated underbalanced horizontal drilling technology has become the focus of the drilling industry at home and abroad, and one of the engineering core issues is the horizontal borehole cleaning. Therefore, calculating the minimum injection volume of gas and liquid accurately is essential for the construction in aerated underbalanced horizontal drilling. This paper establishes a physical model of carrying cuttings and borehole cleaning in wellbore of horizontal well and a critical transport mathematical model according to gas-liquid-solid flow mechanism and large plane dunes particle transport theory.
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Guo, Li Ping, and Lei Wang. "Study on the Flow Behavior of Underbalanced Circulative Micro-Foam Drilling Fluid." Advanced Materials Research 706-708 (June 2013): 1585–88. http://dx.doi.org/10.4028/www.scientific.net/amr.706-708.1585.

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Underbalanced drilling is a new method for the exploratory development of low pressure and permeability reservoirs; circulative micro-foam drilling fluid is a new technology which is developed for realizing near-balanced drilling and underbalanced drilling. The flow behavior of circulative micro-foam drilling fluid in wellbore was researched by applying HPHT experiment apparatus. It is concluded that the flow behavior parameters of circulative micro-foam drilling fluid is only related to temperature but not to pressure; the constitutive equation accords with the rheological law of power-law fluid, the expressions of consistency coefficient and liquidity index were obtained through analyzing the flow behavior experiment data under the condition of HTHP. The density of circulative micro-foam drilling fluid increases as the increase of pressure and decreases as the increase of temperature, but in wellbore the rate of increase as pressure is greater than that of decrease as temperature, so the density of drilling fluid in wellbore is greater than that under ground condition. The fluid drag force of micro-foam drilling fluid in annulus were analyzed theoretically and the pressure distribution formulas of micro-foam drilling fluid in wellbore were given.
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Samuel, G. Robello, and Stefan Miska. "Performance of Positive Displacement Motor (PDM) Operating On Air." Journal of Energy Resources Technology 125, no. 2 (June 1, 2003): 119–25. http://dx.doi.org/10.1115/1.1575776.

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Recent increase in application of horizontal wells and in particular underbalanced drilling, has triggered the necessity of a powerful pneumatic downhole motor. To enhance the technology and make the system effective, a mathematical model is required to identify the opportunities for the modification of power section design. It is well known that the performance of positive displacement motor operating on compressible fluid drops down drastically as compared to the operation under incompressible fluids. The frequent motor replacement during the operation incrementally increases the operating cost despite deriving potential benefits from underbalanced drilling.
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Ozbayoglu, M. E., M. Sorgun, A. Saasen, and K. Svanes. "Hole Cleaning Performance of Light-Weight Drilling Fluids During Horizontal Underbalanced Drilling." Journal of Canadian Petroleum Technology 49, no. 04 (April 1, 2010): 21–26. http://dx.doi.org/10.2118/136689-pa.

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Lage, Antonio C. V. M., Kjell K. Fjelde, and Rune W. Time. "Underbalanced Drilling Dynamics: Two-Phase Flow Modeling and Experiments." SPE Journal 8, no. 01 (March 1, 2003): 61–70. http://dx.doi.org/10.2118/83607-pa.

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Ferguson, Helen A., S. A. (Raj) Mehta, R. Gordon Moore, Nancy E. Okazawa, and Matthew G. Ursenbach. "Oxidation Characteristics of Light Hydrocarbons for Underbalanced Drilling Applications." Journal of Energy Resources Technology 125, no. 3 (August 29, 2003): 177–82. http://dx.doi.org/10.1115/1.1586935.

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This investigation is directly relevant to various applications associated with the safety aspects of underbalanced drilling operations where de-oxygenated air may be co-injected with oil-based drilling fluid. However, de-oxygenated air often still contains up to 5% oxygen by volume. This residual oxygen can react with oil during the drilling process, thereby forming potentially hazardous oxidized hydrocarbons and compromising the safety of drilling operations. This article examines the conditions and processes by which oxidation reactions occur and may be helpful in reducing risk in drilling operations. This project characterizes the oxidation behavior of several oils and a typical oil-based drilling fluid at atmospheric and elevated pressures using thermogravimetry (TG) and pressurized differential scanning calorimetry (PDSC). Tests performed on mineral matrix (core) from the oil reservoirs showed no reactivity in both inert and oxidizing atmospheres. In an inert atmosphere, tests on all hydrocarbon samples showed only vaporization, no reactivity. In an oxidizing environment, the tests on hydrocarbons showed several oxidation regions. The presence of core had no effect on the behavior of the hydrocarbons tested in an inert atmosphere but accelerated the higher temperature oxidation reactions of the oil samples. The oil-based drilling fluid exhibited the opposite effect—the presence of core material retarded the oxidation reactions. This is perhaps due to the presence of an oxygen scavenger reacting with oxygen-containing clays present in the mineral matrix. In all tests performed on mixtures of hydrocarbon and core in oxidizing atmospheres, elevated pressures resulted in acceleration of the lower and higher temperature reaction regions.
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Cox, R. J., Jeff Li, and G. S. Lupick. "Horizontal Underbalanced Drilling of Gas Wells with Coiled Tubing." SPE Drilling & Completion 14, no. 01 (March 1, 1999): 3–10. http://dx.doi.org/10.2118/55036-pa.

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Dissertations / Theses on the topic "Underbalanced drilling (Petroleum engineering)"

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Ozer, Ceren. "Hydraulics Optimization Of Foam Drilling In Drilling Operations." Master's thesis, METU, 2009. http://etd.lib.metu.edu.tr/upload/2/12611059/index.pdf.

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ABSTRACT HYDRAULICS OPTIMIZATION OF FOAM DRILLING IN DRILLING OPERATIONS Ö
zer, Ceren M. Sc., Department of Petroleum and Natural Gas Engineering Supervisor: Assoc. Prof. Dr. Evren Ö
zbayoglu September 2009, 72 pages In drilling, drilling fluid affects every single step of operation. If rig system is thought as the human body, drilling mud can be defined as the blood system of it. Drilling fluid carries the cuttings, cools the bit, it conditions the hole and so on. Some special kinds of drilling fluids are used for special purposes such as underbalanced drilling. Underbalanced drilling is generally used to prevent formation damage, lost circulation and to increase the penetration rate.Since 1980&rsquo
s foam is used as drilling fluid for underbalanced drilling purposes and there are some models for bit hydraulic optimizations. In this study, mathematical model has been derived considering not the volumetric flow rate but the mass flow rate of the foams. Maximum hydraulic horse power at the bit is determined as a function of mass flow rate. Using this concept, optimum volumetric flow rates for liquid and gas phases as well as optimum nozzle size are determined.Using this mathematical model, a computer program is developed for comparing the results with the existing data available in the literature. It accounts for the compressibility of foam and pressure losses inside the drill string, bit and annulus.Hole size, drill-string properties, formation temperature and pressure, maximum inlet pressure are used as input parameters. Program calculates static back pressure,pressure losses in the whole system, bottom hole foam properties such as quality and velocity and optimum liquid and gas flow rates which are the key parameters of foamdrilling optimization. Results show that liquid and gas rates should be increased with increasing hole sizeand formation pressure. Increasing temperature gradient causes a minimal decrease on foam rate properties. In addition, pressure losses due to friction increases with increasing hole size and formation pressure. Decrease in formation temperature also decreases the foam quality. Changes in temperature gradient causes minimal changes on foam rate properties. Comparisons of the proposed model with other models from the literature also gave good match. The optimization criteria and assumptions are differing from the existing models. As a result the comparison does not have to one to one match with the others. The results from this study may be used for optimization of flow rate of foam as drilling fluid based on mass flow.
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Sigurjonsson, Kjartan Örn. "Dual gradient drilling simulations." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-18362.

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The system studied in this thesis is called the Low Rise Return system and uses a partly filled marine drilling riser with a variable mud level which is used control the bottom holes pressure.Initially main components of the Low Riser Return System are listed and explained. Then the performance characteristics of the system are explored. Level movements in riser during level increase and decrease at constant mud pump rates are explained along with the effect of mud pump rate on maximum level increase and decrease rates.A simple simulator is then presented that calculates the bottom hole pressure when pump rates are changed. The simulator includes a function that enables it to simulate lost circulation scenarios.The simulator is used to simulate some preferred scenarios. First a pressure increase and decrease at constant mud pump rates are simulated. Then it is shown how a faster pressure decrease can be achieved by temporarily lowering the mud pump rate. Next simulations are shown where changes in mud level are used to compensate for changes in equivalent circulation density as mud pump rates are changed. Finally simulations are run that demonstrate how mud level can be reduced to cure lost circulation scenarios. Results and lessons learned are then discussed.
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Song, Jinze. "Limit of Horizontal Wellbore in Extended Reach Drilling with Gas." Thesis, University of Louisiana at Lafayette, 2015. http://pqdtopen.proquest.com/#viewpdf?dispub=1585874.

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The limit of drilling ERD comes from the excessive friction between the drill string and borehole. This study investigates the potential of increasing the limit of horizontal displacement through optimization of drilling fluid and bottom hole assemblies. We conclude that lubricating bottom hole with water can significantly increase the maximum permissible WOB. This effect is more pronounced in drilling tight sands than shales with gas. Cooling the bottom hole with gas expansion after bit nozzles can greatly increase the maximum permissible WOB in drilling formations with geothermal temperatures above 200 °C. Three mathematical methods have been developed for calculating the limit of horizontal displacement in extended drilling with gas. The Rigorous Method is recommended because it gives conservative result. Among several factors affecting the ERD with gas, friction coefficient and the weight of pipe in the horizontal section are the two controlling factors. Adequate weight of BHA in the curve section should be used to overcome the friction.

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Cai, Xiao. "An Analytical Method for Predicting Wellbore Temperature Profile During Drilling Gas Hydrates Reservoirs." Thesis, University of Louisiana at Lafayette, 2016. http://pqdtopen.proquest.com/#viewpdf?dispub=10163276.

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Production of natural gas from unconventional gas-hydrate reservoirs faces kinds of challenges and uncertainties. One of the main and most common problems in gas-hydrates drilling is the dissociated gas from gas hydrates with decrease of pressure, increase of temperature, or combination of them. A reliable method that can be applied to predict the temperature profile of fluid during circulating in the drilling pipe and the annulus is needed. An analytical model was developed in this study for predicting temperature profiles in drilling gas-hydrate deposits. A case study is provided and indicates a good consistency between model-implications and field observations. According to the sensitivity analyses, the temperature profile of fluid in the drill pipe can be affected by the thickness of drill pipe, density and heat capacity of drill mud, pumping rate of drill mud, geo-thermal gradient, and the surface geo-temperature. The bottom hole temperature is dominated by the temperature and flow rate of the injected drilling fluid, thermal conductivity of cement, heat capacity and density of drill mud, geo-thermal gradient and geothermal temperature at surface, thickness of drill pipe, and cement sheath. Higher geothermal gradient and surface geothermal temperature can lead to a higher temperature profile of fluid in the annulus. The Joule-Thomason cooling effect below the drill bit nozzles will rapidly diminish in a short interval above the bottom hole by the heating effect of geo-thermal gradient. The rate of penetration of drill bit has negligible effect on the fluid temperature profile due to the low percentage of heat flow contributed by the drill cuttings.

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Ettehadi, Osgouei Reza. "Determination Of Cuttings Transport Properties Of Gasified Drilling Fluids." Phd thesis, METU, 2010. http://etd.lib.metu.edu.tr/upload/12612676/index.pdf.

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The studies conducted on hole cleaning have been started with single phase drilling fluids for vertical holes in 1930&rsquo
s, and have reached to multiphase drilling fluids for directional and horizontal wells today. The influence of flow rate and hole inclination on cuttings transport has been well understood, and many studies have been conducted on effective hole cleaning either experimentally or theoretically. However, neither the hydraulic behavior nor the hole cleaning mechanism of gasified drilling fluids has been properly understood. The aims of this study are to investigate and analyze the hole cleaning performance of gasified drilling fluids in horizontal, directional and vertical wells experimentally, to identify the drilling parameters those have the major influence on cuttings transport, to define the flow pattern types and boundaries as well as to observe the behavior of cuttings in detail by using digital image processing techniques, and to develop a mechanistic model based on the fundamental principles of physics and mathematics with the help of the experimental observations. A mechanistic model is developed with the help of the obtained experimental data. Developed model is used for estimating optimum flow rates for liquid and gas phases for effective cuttings transport as well as for determining the total pressure losses and void fraction of each phase for a given drilling conditions. The v mechanistic model obtained using the experimental data within the scope of this study will be used to develop the hydraulic program and equipment selection to be used in the field during underbalanced drilling applications.
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Leamon, Gregory Robert Petroleum Engineering Faculty of Engineering UNSW. "Petroleum well costs." Awarded by:University of New South Wales. School of Petroleum Engineering, 2006. http://handle.unsw.edu.au/1959.4/30599.

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This is the first academic study of well costs and drilling times for Australia???s petroleum producing basins, both onshore and offshore. I analyse a substantial database of well times and costs sourced from government databases, industry and over 400 recent well completion reports. Three well phases are studied - Pre-Spud, Drilling and Completion. Relationships between well cost factors are considered, including phase time, phase cost, daily cost, rig day rate, well depth, basin, rig type, water depth, well direction, well objective (e.g. exploration), and type of completion (P&A or producer). Times and costs are analysed using scatter plots, frequency distributions, correlation and regression analyses. Drilling times are analysed for the period 1980 to 2004. Well time and variability in well time tend to increase exponentially with well depth. Technical Limits are defined for both onshore and offshore drilling times to indicate best performance. Well costs are analysed for the period 1996 to 2004. Well costs were relatively stable for this period. Long term increases in daily costs were offset to some extent by reductions in drilling times. Onshore regions studied include the Cooper/Eromanga, Surat/Bowen, Otway and Perth Basins. Offshore regions studied include the Carnarvon Basin shallow and deepwater, the Timor Sea and Victorian Basins. Correlations between regional well cost and well depth are usually high. Well costs are estimated based on well location, well depth, daily costs and type of completion. In 2003, the cost of exploration wells in Australia ranged from A$100,000 for shallow coal seam gas wells in the Surat/Bowen Basins to over A$50 million for the deepwater well Gnarlyknots-1 in the Great Australian Bight. Future well costs are expected to be substantially higher for some regions. This study proposes methods to index historical daily costs to future rig day rates as a means for estimating future well costs. Regional well cost models are particularly useful for the economic evaluation of CO2 storage sites which will require substantial numbers of petroleum-type wells.
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Ezekiel, Ekerette Elijah. "EXPERIMENTAL STUDY OF DRILLING MUD RHEOLOGY AND ITS EFFECT ON CUTTINGS TRANSPORT." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19792.

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PICARD, NICOLAS. "DEVELOPMENT OF NOVEL HYDRAULICS FOR OIL WELL DRILLING." University of Cincinnati / OhioLINK, 2002. http://rave.ohiolink.edu/etdc/view?acc_num=ucin1025637714.

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Al-Awad, Musaed Naser J. "Physico-chemical analysis of shale-drilling fluid interaction and its application in borehole stability studies." Thesis, Heriot-Watt University, 1994. http://hdl.handle.net/10399/1368.

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Shale is often the most difficult of all formations to maintain a stable wellbore in when drillincr ::> for oil and gas. Time and money spent overcoming this problem during drilling, together with overall reduced profit margins. has led the oil industry to devote considerable time and effort to solve the problem of unstable boreholes in shales. It has long been established that the moisture adsorption (or desorption) of shale rocks can be controlled by the salinity of drilling fluid. When compacted shale (under constant compaction stress) adsorbs moisture, its total volume increases and swelling strains develop. Developed swelling strains then become an integral part of the effective radial stress acting on the shale formation contributing to borehole failure. A mathematical model has been developed for predicting the swelling behaviour of shale when placed in contact with water under moderate pressures and the effect of the swelling on borehole (in)stability. The model is based on thermodynamic theory which suggests that fluid movement into or out of a shale is driven by an imbalance in the partial molar free energy of the shale and the contacting fluid. Conversion of the free energy of each system (fluid and shale) into "total swelling pressure" made it possible to model transient pressures and strains generated in shale. The analytical solution of the radial diffusivity equation is reduced to a simpler form for the model. The model was validated using equipment and experimental techniques which allow continuous monitoring of shale swelling as function of time and distance from the wetting end. It was found that increasing the compaction stress acting on the shale reduced the rate of swelling, and increasing the hydraulic pressure of the fluid on the shale's wetted surface increased the rate of swelling. This behaviour was adequately described by the model which therefore represents a new method for predicting shale swelling as function of time and radial distance under different environments. Swelling strains are then used to predict related changes in shale mechanical properties (failure criteria) and well (in)stability. Several well-site index tests have been developed to study shale-drilling fluid interaction at wellsite. These index tests can provide input data for the mathematical model. Drilling fluids can be screened for their ability to control shale swelling, thus minimising the risk of well bore instability.
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Eikås, Inger Kamilla. "Influence of Casing Shoe Depth on Sustained Casing Pressure." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-18650.

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In 2006 the Petroleum Safety Authority Norway (PSA) performed a well integrity survey. The survey indicated that about 20 % of wells on the Norwegian Continental shelf (NCS) may suffer from well integrity issues. Most of the problems were related to deficiency in annulus safety valve, tubing, cement and casing. Pressure build-up in annulus, i.e. sustained casing pressure, is one of the main indicators of a significant well integrity problem. Increased understanding on the field may help engineers to design wells with better integrity in the future. This thesis describes SCP and its most common causes with emphasis on the relation between casing shoe setting depth and the occurrence of SCP. Primary and secondary barrier is described together with the common practice of choosing casing shoe depth. Formation strength and its impact on setting depth is explained together with a brief introduction of the different formation integrity tests. Generic cases have been studied to determine the relation between unfavorable casing shoe setting depth and the occurrence of SCP. For each case there is a suggestion as how the well may be redesigned so that the risk of SCP is reduced. Information on the theme has been acquired through studying and comparing different papers, booklets, previous reports and reviews concerning the subject. The Norsok standard D-010 and 117 – OLF recommended guidelines for well integrity have also been very informative during the study. To be able to avoid SCP and at the same time improve well design, it is important to properly understand how SCP arises. Changing the casing shoe setting depth to a more suited depth or formation cannot alone eliminate SCP. To eliminate SCP a good conversion between Top of Cement (TOC) and setting depth of the previous casing shoe is required. The best way of avoiding SCP because of casing shoe setting depth is to make a thorough investigation of the underground and carefully choose the setting depth.
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Books on the topic "Underbalanced drilling (Petroleum engineering)"

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Termeer, Chris. Oil and natural gas exploration and drilling operations. Clearwater Beach, Florida: Chris Termeer, 2013.

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Lyons, William C. Air and gas drilling manual. 3rd ed. Burlington, MA: Gulf Professional Pub., 2009.

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Hyne, Norman J. Dictionary of petroleum exploration, drilling & production. Tulsa, Okla: PennWell Pub. Co., 1991.

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Aadnøy, Bernt Sigve. Mechanics of drilling. Aachen: Shaker, 2006.

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Aadnøy, Bernt Sigve. Mechanics of drilling. Aachen: Shaker, 2006.

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Hyne, Norman J. Nontechnical guide to petroleum geology, exploration, drilling, and production. Tulsa, OK: PennWell Books, 1995.

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Nontechnical guide to petroleum geology, exploration, drilling, and production. 2nd ed. Tulsa, OK: Penn Well Corp., 2001.

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Nontechnical guide to petroleum geology, exploration, drilling, and production. 3rd ed. Tulsa, Okla: PennWell Corporation, 2011.

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Drilling in the permafrost. Rotterdam: A.A. Balkema, 1991.

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Lyons, William C. Air and gas drilling manual: Engineering applications for water wells, monitoring wells, mining boreholes, geotechnical boreholes, and oil and gas recovery wells. 2nd ed. New York: McGraw-Hill, 2001.

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Book chapters on the topic "Underbalanced drilling (Petroleum engineering)"

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Archer, J. S., and C. G. Wall. "Oilwell Drilling." In Petroleum Engineering, 20–39. Dordrecht: Springer Netherlands, 1986. http://dx.doi.org/10.1007/978-94-010-9601-0_3.

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Feng, Yongcun, and K. E. Gray. "Drilling Related Geomechanics." In SpringerBriefs in Petroleum Geoscience & Engineering, 9–19. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-319-89435-5_2.

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Flores-León, J. Omar, Octavio Cazarez-Candia, and Rubén Nicolás-López. "Single- and Two-Phase Flow Models for Concentric Casing Underbalanced Drilling." In Fluid Dynamics in Physics, Engineering and Environmental Applications, 225–32. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-27723-8_16.

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Lavrov, A., and J. Tronvoll. "Mud loss into a single fracture during drilling of petroleum wells: modelling approach." In Development and Application of Discontinuous Modelling for Rock Engineering, 189–98. London: CRC Press, 2021. http://dx.doi.org/10.1201/9781003211389-28.

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"DRILLING." In Introduction to Petroleum Engineering, 137–60. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2016. http://dx.doi.org/10.1002/9781119193463.ch8.

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"petroleum well drilling." In Dictionary Geotechnical Engineering/Wörterbuch GeoTechnik, 986. Berlin, Heidelberg: Springer Berlin Heidelberg, 2014. http://dx.doi.org/10.1007/978-3-642-41714-6_161171.

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"3.0 Drilling engineering." In Developments in Petroleum Science, 29–63. Elsevier, 1998. http://dx.doi.org/10.1016/s0376-7361(98)80005-8.

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"Drilling." In Introduction to Petroleum Exploration and Engineering, 51–66. WORLD SCIENTIFIC, 2016. http://dx.doi.org/10.1142/9789813147799_0005.

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"Exploration and Drilling." In Petroleum Economics and Engineering, 240–57. CRC Press, 2013. http://dx.doi.org/10.1201/b16226-15.

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Jahn, F., M. Cook, and M. Grahm. "Chapter 4 Drilling Engineering." In Developments in Petroleum Science, 47–81. Elsevier, 2008. http://dx.doi.org/10.1016/s0376-7361(07)00004-0.

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Conference papers on the topic "Underbalanced drilling (Petroleum engineering)"

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Cunha, J. C., Fabio Severo Rosa, and Helio Santos. "Horizontal Underbalanced Drilling In Northeast Brazil: A Field Case History." In SPE Latin American and Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/69490-ms.

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Schmigel, Kevin, and Larry MacPherson. "Snubbing Provides Options for Broader Application of Underbalanced Drilling Lessons." In SPE Latin American and Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers, 2003. http://dx.doi.org/10.2118/81069-ms.

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Rommetveit, Rolv, and Antonio Carlos V. M. Lage. "Designing Underbalanced and Lightweight Drilling Operations; Recent Technology Developments and Field Applications." In SPE Latin American and Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/69449-ms.

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Edge, David, Michael Pope, Konstantin Puskarskij, Helio Santos, Henry Pinkstone, and Phil McKenzie. "Successful First Implementation of MPD Technology Offshore Australia: Regulatory, Technical and Operational Lessons Learned." In IADC/SPE Managed Pressure Drilling & Underbalanced Operations Conference & Exhibition. SPE, 2021. http://dx.doi.org/10.2118/206390-ms.

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Abstract This paper details the successful first implementation of closed-loop Managed Pressure Drilling (MPD) technology offshore Australia, on a 6th generation semi-submersible rig. The paper covers the process of achieving safety case acceptance to implement MPD technology from the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA), the government regulatory authority. The paper describes the project concept design phase, including a Drill Well on Simulator (DWOS) exercise, which was completed to confirm MPD techniques would mitigate problems experienced on conventionally drilled offset wells. The MPD risk assessments completed included HAZID / BOWTIE / HAZOP / FEA studies which were included in the safety case formal safety assessment that was submitted to NOPSEMA. In parallel the Well Operations Management Plan was submitted, detailing the planned MPD methodology. The detailed Well Engineering scope including the MPD Programme, Operational and Contingency Procedures and Commissioning Process was developed to form a Joint Operations Manual. Four levels of project specific MPD training were developed, reviewed, accepted and monitored by NOPSEMA, including classroom based and rig site practical training. Post MPD system installation in Singapore, the System Integrity Testing was successfully completed offshore Australia. Lastly the paper details MPD operations on the first well including the effective use of MPD well control, dynamic MPD FIT, LOT and Pore Pressure testing and establishing the high formation temperature effects on drilling mud density. The closed-loop MPD system allowed the riser deployed sections to be drilled using a statically underbalanced mud system and confirmed the improved capability and flexibility in terms of detection and controllability during mud loss events.
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Isgenderov, Islam, Victor Osayande, Svetlana Nafikova, Fajar Budi Prasetyo, and Wouter Alexander van El. "Integrated Approach for Successful Well Abandonment Under Challenging Well Conditions – A Case Study." In SPE/IADC International Drilling Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/204116-ms.

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Abstract Emerging technologies, stringent permanent well abandonment regulations, and increasing well complexity affect the way we execute well intervention operations. One of the major operators in the Netherlands had an objective to set underbalanced cement plugs in brine across a deviated section using managed-pressure equipment to overcome high reservoir bottomhole pressure. The project involved several challenges: large-diameter production casing with a requirement to maintain high shut-in wellhead pressure, complex wellbore geometry, operations from a workover rig with zero discharge allowance, corrosive salt environment, and small cement slurry volume. These challenges had to be addressed to complete well abandonment to minimize safety risks, maximize efficiency, and achieve compliance with industry standards and regulatory requirements. This paper discusses two case studies involving underbalanced pump-and-pull and conventional balanced plug placement techniques. Thorough analysis and risk assessment, engineering design approach, comprehensive laboratory testing, and fit-for-purpose surface equipment and downhole tools enabled flawless job execution and placement and achievement of long-term zonal isolation. The first well-barrier elements were successfully verified by tagging and pressure testing in both cases. Results of this study include the following observations and conclusions: Managed-pressure cementing was proven to be an ideal solution for a well abandonment in a reservoir environment of high bottomhole pressure.Highly magnesium-resistant cement slurry design should be considered when setting cement plugs across an extremely corrosive salt environment.Successful verification of the first well-barrier element simplifies operations for subsequent cement plugs. Cost-effective solutions for permanent well abandonment under challenging downhole conditions attracts increasing interest from petroleum engineers due to increasing well complexity and low oil prices that challenge the economics of wells, leading to abandonment. The current paper describes the challenging conditions under which the wells had to be abandoned, thorough analysis of the risks involved, and an effective solution. The design strategy, execution, evaluation, and results for these two wells are discussed in detail and will help to guide success and solve problems related to permanent well abandonment under similar challenging conditions.
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Karimyan, E., H. Dashtian, and K. Shahbazi. "A Novel Drilling Fluid for Underbalanced Drilling." In 1st International Petroleum Conference and Exhibition Shiraz 2009. Netherlands: EAGE Publications BV, 2009. http://dx.doi.org/10.3997/2214-4609.20145891.

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Matanovi, Davorin, Nediljka Gaurina Meimurec, and Zdenko Kristafor. "Underbalanced Drilling With Coiled Tubing." In Abu Dhabi International Petroleum Exhibition and Conference. Society of Petroleum Engineers, 2000. http://dx.doi.org/10.2118/87242-ms.

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Leising, L. J., and E. A. Rike. "Underbalanced Drilling With Coiled Tubing And Well Productivity." In European Petroleum Conference. Society of Petroleum Engineers, 1994. http://dx.doi.org/10.2118/28870-ms.

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Shadravan, A., M. Khodadadian, K. Shahbazi, and A. Roohi. "Underbalanced Drilling Technology, the Key for Solving Drilling Problems." In 1st International Petroleum Conference and Exhibition Shiraz 2009. Netherlands: EAGE Publications BV, 2009. http://dx.doi.org/10.3997/2214-4609.20145892.

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Qutob, Hani, Khelil Kartobi, and Abdelaziz Khlaifat. "Underbalanced Drilling Technology for Unconventional Tight Gas Reservoirs." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2014. http://dx.doi.org/10.2523/iptc-17279-ms.

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