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1
Daniel, Joshua, Chad Penn, João Antonangelo, and Hailin Zhang. "Physicochemical Characterization of Horizontal Directional Drilling Residuals." Sustainability 12, no. 18 (September 18, 2020): 7707. http://dx.doi.org/10.3390/su12187707.
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Horizontal directional drilling (HDD) is a trenchless technology mainly used for the installation of gas, sewer lines, and fiber optic cables. Spent HDD fluid is a by-product of the boring process. However, little is known of its constituency, although the land application of spent HDD residuals would be an economical and less time-consuming method of disposal. Physicochemical analysis of spent HDD residuals from broad geographic regions was conducted to determine if the land application would be an environmentally safe option for disposal. Fifty-eight HDD samples were collected from 26 states throughout the United States. After separation of the liquid and solid portion, the materials were assessed for carbon (C), nitrogen (N), plant nutrients, soluble and total trace metals, total dissolved solids, sodium adsorption ratio (SAR), and potential “leachable metals”. All trace metal concentrations in the digested solid portion were well below the limits for biosolids set by the EPA 40 Part 503 rule for land application. Metal concentrations did not exceed the limits of drinking water standards. Besides the total amount of solids, there was nothing chemically limiting HDD residuals from land application. However, if boring through soil with suspected contamination, testing the residual before the application is recommended.
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Fan, Sen, Yue Xiang Li, Jin Qiang Cao, and Jian Bo Xie. "Optimization Technique in Double Stepped Thin Horizontal Well." Advanced Materials Research 734-737 (August 2013): 1226–29. http://dx.doi.org/10.4028/www.scientific.net/amr.734-737.1226.
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Oil industry at home and abroad has paid attention to the usage of horizontal well with the development of horizontal drilling technology, the number of horizontal well is increasing year by year inland, but some horizontal well constructions in thin oil pay is not ideal. Nanzhong 1H well has used double stepped horizontal well technology to develop thin oil pay, it has optimized the constructions in different stages and combined the steering technique in the drilling practice of thin oil pay, it has accelerated the drilling speed and reached the target fast and safely. It provides the reference for the further development of deep thin oil pay of horizontal well technology.
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Zhang, Hui, De Li Gao, and Wen Sheng Liu. "Risk Assessment of Extended Reach Well Based on Gray Matter-Element." Advanced Materials Research 361-363 (October 2011): 386–92. http://dx.doi.org/10.4028/www.scientific.net/amr.361-363.386.
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Drilling is one of the major means for oil and gas exploration and development. Extended reach wells (ERWs) are defined as directional wells or horizontal wells with horizontal displacement (HD) to vertical depth (VD) ratio greater than or equal to 2. Extended reach drilling (ERD) confronted many technical difficulties. Risk analysis of ERD before drilling is of great significance for preventing complex accidents during drilling operations, improving the drilling rate and efficiency. Based on gray matter-element theory, this paper established a comprehensive risk assessment model for ERD operations and applied this model to evaluate the drilling risk of Well B6ERW07(HD to VD ratio 5.94, horizontal displacement 7,419.42 m, vertical depth 1,248.50 m, measured depth 8,144.31 m)in the Liuhua oil field, South China Sea. The assessment results show that the predicted success rate of drilling this ERW is 49.9%. This result can be important criteria and thus contributes greatly to decision making.
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Niu, Hong Bo, Hong Shan Zhao, and Ji Fei Cao. "Application and Cognition of Unconventional Horizontal Well Drilling Technology in Shengli Oilfield." Applied Mechanics and Materials 318 (May 2013): 513–18. http://dx.doi.org/10.4028/www.scientific.net/amm.318.513.
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Long Horizontal Section Well has been an important way to explore deficient oil/gas field. Relative drilling technology has developed rapidly in recent years in China. This article puts focus on the methodology of well plan, trajectory control and matched tools and application situation of drilling fluid and drilling equipment for long horizontal section well. Based on the analysis of drilling and completion technical difficulties, suitability of some well design methods such as catenary curve used to decline friction and torque have been discussed, and even more practical means proven in many designs have been recommended. After introducing the drilling capability of the long horizontal-section well, the article indicated some special characteristic of the horizontal section wells and difference from ERD wells. Consequently, some advice is given on the definition and development of the drilling technology of long horizontal section wells.
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Nie, Gui Min, Dan Guo, Yan Wang, and Xiao Wei Cheng. "Research and Application of the Deep Horizontal Drilling and Completion Technology for Liaohe Oilfield Buried Hill Reservoir." Applied Mechanics and Materials 241-244 (December 2012): 1396–99. http://dx.doi.org/10.4028/www.scientific.net/amm.241-244.1396.
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With the depletion of shallow-layer oil and gas pools inLiaohe oilfield, buried hill stratigraphic reservoirs in Liaohe oil field are becoming main objectives for exploration in recent years, especially in high-risk areas of Xinglongtai deep the Hing ancient buried hill resources are particularly rich. Since 2007, Liaohe oilfield increased investment for Buried Hill reservoirs with deep horizontal drilling developt the buried hill reservoir. Liaohe has completed 36 deep horizontal, with a total footage of 183920m, the average depth of 5109m. Improving drilling speed of "buried hill deep horizontal and branch horizontal wells”, and reducing drilling costs are of great urgency. “Hing buried hill deep horizontal, horizontal wells,” with composite drilling technology, supporting the optimization of PDC bits, the high-pressure jet drilling, the MWD borehole trajectory control and optimization of drilling parameters, the new drilling fluid technology and so on. With a large number of horizontal wells put into Buried Hill stratigraphic reservoirs, oil and gas production of average deep horizontal well increase of 2-5 times. Besides, the previous recovery and production of oil and gas reservoirs significantly improved to create an objective economic and social benefits.
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bdul-Aali Al-Dabbaj,, Ayad A. Al-Haleem, A. "Horizontal Drilling Well Proposal in West Qurna Oil Field (Iraqi Oil Field)." International Journal of Innovative Research in Science, Engineering and Technology 5, no. 5 (May 15, 2016): 7296–303. http://dx.doi.org/10.15680/ijirset.2016.0505094.
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He, Jun, Shuai Qin Ren, Fu Ping Feng, and Guo Yong Liu. "The Position Analysis of Drilling Fluid Retention in Horizontal Well." Applied Mechanics and Materials 52-54 (March 2011): 2076–81. http://dx.doi.org/10.4028/www.scientific.net/amm.52-54.2076.
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The driving force caused by density difference of slurry and drilling fluid is a function of circumference angle and radius in horizontal well displacing. The closer to annulus bottom, the larger is the driving force, which leads to the displacing interface more easily to extend downward annulus. Based on the mechanics analysis of annular fluid displacing infinitesimal in horizontal well, this paper sets up the calculation model of drilling fluid layer dynamic shearing stress in displacing process. According to the equilibrium condition of displacing interface stability, the boundary position of drilling fluid retention layer at casing and sidewall with different circumference angles for horizontal well is acquired, which will enhance the pertinence of displacing techniques in horizontal well.Calculation results show that with the same circumference angle, the thickness of drilling fluid retention layer at sidewall is far larger than at casing. For this reason, the cement bond quality of the second cementing interface should be used as one of criterions for evaluating horizontal well cementing quality. And the retention at sidewall and casing gradually increases from the lower annulus to the upper part. The retention layer at upper sidewall is thickest. So the oil/gas/water channeling-path is easy to form and special attention should be given to cleaning the upper sidewall drilling fluid . Low permeable horizontal wells generally take subsection fracturing method for exploitation , requirements of cementing quality is higher. The guarantee of higher displacing efficiency is the premise of obtaining high quality of cement quality , in the horizontal well because of dirlling fluid retention and free water precipitation , the oil/gas/water channeling-path is easy to form at the upper wellbore , seriously restricted the implementation[1-2] of the horizontal well stimulation measures. At present technology about improving the displacing efficiency develope rapidly[3-6],but because of drilling fluid retention laws and the retention position is uncleared in horizontal well,which lead to these measures are not well targeted. Analysed by displacing interface dynamic extension process in the process of slurry displace drilling fluid , this article establishes dynamic shearing stress calculation model of horizontal well annular fluid displacing infinitesimal , according to the condition of displacing interface stability, the drilling fluid retention law and retention position in horizontal well is acquired.
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Sun, Yu Xue, Yu Ning Xie, and Chang Xiao. "MEG and its Application in Drilling Fluid." Advanced Materials Research 287-290 (July 2011): 2088–93. http://dx.doi.org/10.4028/www.scientific.net/amr.287-290.2088.
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Recently, oil-based drilling fluids are used mainly in horizontal wells, which are highly cost and have a poor performance to carry cuttings and may result in environmental problems because of the ineffective dispose of drilling waste. Therefore, a study is commenced to develop a water-based drilling fluid system (MEG drilling fluid system) that can satisfy the needs of horizontal well. The study begins with the molecular structure and properties of monomers about MEG. Then it selected the treatment agent which has a good compatibility with MEG, and confirms a best formula of MEG drilling fluid system. By the comparison between MEG and other drilling fluids, the former has evident advantages in cave preventing, lubricity, solid carrying and formation damage controlling; also it can minimize the environmental effects. The above proves that MEG drilling fluid system can well meet the need for horizontal well drilling.
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Ding, Y., and G. Renard. "Evaluation of Horizontal Well Performance After Drilling-Induced Formation Damage." Journal of Energy Resources Technology 127, no. 3 (March 22, 2005): 257–63. http://dx.doi.org/10.1115/1.1924463.
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It is well recognized that near-wellbore formation damage can dramatically reduce well productivities, especially for open hole completed horizontal wells. The economic impact of poor productivity of these wells has pushed toward significant efforts in recent years to study laboratory testing techniques and numerical modeling methods for predicting and controlling drilling-induced formation damage. This paper presents an integrated approach, combining a near-wellbore modeling with laboratory experiments for data acquisition as input for the model, to evaluate the performance of oil and gas wells after drilling-induced formation damage.
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Bondarenko, M., V. Kulyk, Z. Yevstakhevych, S. Danyliv, V. Zinenko, and M. Los. "APPARATUS AND METHODICAL COMPLEX FOR DETERMINATION OF OIL-GAS RESERVOIRS PARAMETERS WHILE DRILLING HORIZONTAL WELLS." Visnyk of Taras Shevchenko National University of Kyiv. Geology, no. 4 (87) (2019): 20–25. http://dx.doi.org/10.17721/1728-2713.87.03.
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The paper is devoted to the basic principles of the trend of logging, namely logging while drilling (LWD), which is new for Ukraine. The LWD technology has a number of advantages over other logging types, in particular, in supplementary exploration and production of hydrocarbons in fields that are in longterm development. In this case, the drilling of horizontal wells, which by productivity is much higher than the vertical ones, is important. For the investigations of horizontal wells, we proposed a universal compact radioactive logging tool with small diameter, which is placed in entire drill collar just before drilling. The combined radioactive logging tool LWD-КПРК-48 (48 mm in diameter) contains dual-spacing modules of neutron logging, neutron-gamma logging, density logging, as well as separately placed gamma-logging unit. Calibration works with the developed combined tool were carried out on physical models of reservoirs in the presence of drill collars and corresponding calibration dependences on porosity and density were obtained. They, together with the developed methods and other data, allow us to determine an extended set of petrophysical parameters, namely, the porosity of water-, oil- and gas-saturated reservoirs, the identification parameters of fluid: water – oil and water – gas, oil-, gas- and water saturation, volume content of oil and gas, etc. Test of a logging tool LWD-КПРК-48 when drilling a horizontal well in an oil-bearing bed showed high informativity and efficiency of product. The created apparatus and methodical complex for the investigation of horizontal oil and gas wells while drilling has several advantages over known analogues, in particular, is universal, convenient, more available to mining and well logging oil and gas companies.
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Ali, Fadi, Hassan Bahrami, Po Chu Byfield, and Jijin Mathew. "Production optimisation and water control in oil/water producing wells using horizontal downhole water sink technology." APPEA Journal 51, no. 1 (2011): 577. http://dx.doi.org/10.1071/aj10041.
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Water breakthrough and the flow of water towards the perforations of a producing well increase production operation costs and influence overall recovery efficiency. To control water production, a downhole water sink can be used in which a well is completed in both oil and water zones. Water is produced from an interval in water zone, which can result in the same pressure drop below water oil contact (WOC) as the pressure drop created by oil or gas production. This system can reduce water production through oil zone perforations. Water produced from water zone perforations can then be injected in deeper aquifers intervals. This technology can also be implemented in horizontal and multi-lateral wells to further increase hydrocarbon recovery with fewer water problems. This study examines the use of horizontal downhole water sink technology to increase oil recovery. Numerical simulation is performed to optimise oil production and water control in a multi-layered oil reservoir, by optimising the direction of drilling and the downhole water sink method. Different scenarios of drilling direction and horizontal down-hole water sink method are examined to identify the option that provides maximum oil recovery. The simulation results showed that drilling horizontal wells in a north–south direction resulted in higher well productivity, and that wells with significantly more water production problems can be controlled using a horizontal downhole water sink.
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A.Alrazzaq, Ayad A. Alhaleem. "Development of East Baghdad Oil Field By Clusters of Horizontal Wells." Iraqi Journal of Chemical and Petroleum Engineering 20, no. 3 (September 30, 2019): 75–79. http://dx.doi.org/10.31699/ijcpe.2019.3.10.
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There are varieties of reasons lead for drilling horizontal wells rather than verticals. Increasing the recovery of oil, especially from thin or tight reservoir permeability is the most important parameter.
East Baghdad oil field considered as a giant field with approximately more than 1billion barrel of a proved reserves accompanying recently to low production rate problems in many of the existing wells.
It is important to say that presence of of horizontal wells in East Baghdad field especially by converting some of already drilled wells by re-entry drilling horizontal sections may provide one of best solutions for the primary development stage in East Baghdad field which may be followed by drilling new horizontal wells or using multilateral wells.
Advance software (Well Test/FAST) has been used to convert the production data for the already drilled vertical wells to horizontals to simulate the productivity. It can be concluded that no measurements available for the ratio of anisotropy (Kv/Kh); in East Baghdad Oil Field therefore, the wells productivity has been estimated using wide range of anisotropy ratios that will help the field operator to determine exactly wells productivity. Moreover, it helps to recommend the effectiveness of applying hydraulic fracturing in improving horizontal well productivity.
The results show that it could be used well EB-32 as a re-entry horizontal well with an optimum section length of 1500-2000ft wich give the best production rate. The same result could be stated for EB-10 with somewhat higher productivity than EB-32.
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Xie, Gang, Ming Yi Deng, Jun Lin Su, and Liang Chun Pu. "Study on Shale Gas Drilling Fluids Technology." Advanced Materials Research 868 (December 2013): 651–56. http://dx.doi.org/10.4028/www.scientific.net/amr.868.651.
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Via discussing the advantages and disadvantages of different types of oil-based drilling fluids, the main reason why oil-based drilling fluids are less used in our country is obtained that dont form a complete series of matching technology. The essence of wellbore instability caused by using water-based drilling fluids to drill shale is analyzed that the formation collapse pressure is greater than drilling fluids column pressure. The fundamental way of controlling borehole wall stability that use water-based drilling fluids to drill shale horizontal well was proposed that deeply researched the shale hydration mechanism, developed efficient blocking agent and inhibitors and established shale gas drilling fluid suppression system, which made water-based drilling fluids have excellent performance.
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Saltykov, V. V., Yu S. Makovsky, and M. M. Mansurova. "Domestic rotary steerable systems development potential for drilling horizontal wells." Oil and Gas Studies, no. 5 (November 12, 2020): 74–80. http://dx.doi.org/10.31660/0445-0108-2020-5-74-80.
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A complex of special equipment is required for the construction of high-tech wells. The basis of modern time efficient, precise and safe drilling is rotary steerable systems (RSS). For the past five years, rotary steerable systems have been using in Russia as a technical and technological solution to reduce accidents and to improve the quality of well construction with large vertical deviations of the extended drilling radius. These systems allow drilling to be oriented along the entire length of the well. Rotary steerable systems allows drilling both perfectly vertical wells with a deviation angle of not more than 0,2°, and horizontal wells more than 2 000 metres long. Implementation of rotary steerable systems allows building wells with extremely extended reach and conducting wells in 1–2 metres thick reservoirs with precision. In 2016, OktoGeo LLC carried out pilot well program with APS Technology's 172 mm RSS (with power section) at an oil field in the territory of KhantyMansiysk Autonomous Okrug — Ugra. All the rotary steerable system positioning programs were completed based on the results of that work and results of drilling 2 205 metres long directional well.
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Wu, Fang Fang, Jin Chuan Zhang, Hao Zhang, and Jin Long Wu. "Integrated Formation Evaluation of a Complex Tight Oil Reservoir in Junggar Basin, Northwest China." Advanced Materials Research 1073-1076 (December 2014): 2286–91. http://dx.doi.org/10.4028/www.scientific.net/amr.1073-1076.2286.
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Jimusaer tight oil reservoir is characterized by complex lithology, low permeability and high total organic carbon (TOC) content. These features make conventional logging responses very complicated and bring big troubles to reservoir identification. Horizontal well drilling is extremely difficult due to high heterogeneity and uncertain faulting. To maximize oil production with low cost, an integrated solution is provided. First, accurate reservoir characteristics of the pilot well was got using an unconventional evaluation approach by combining capture spectroscopy log, micro-resistivity imager log, nuclear magnetic resonance log, et al. Second, structure analysis for sidetracking well and well correlation between the sidetracking well and the pilot well were done to guide the horizontal section drilling. Third, reservoir quality and completion quality were evaluated for horizontal well, and a 3D structural model was built to optimize the stimulation design by combining reservoir quality, completion quality and natural fractures.
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Portilla, Carlos, Alamir Alvarez, and Romel Erazo. "Análisis comparativo técnico - económico de producción de crudos pesados en pozos horizontales y direccionales, arena “m-1” formación napo, bloque 16, oriente ecuatoriano." Revista Científica y Tecnológica UPSE 3, no. 3 (December 23, 2016): 165–71. http://dx.doi.org/10.26423/rctu.v3i3.208.
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Los tipos de perforación ejecutados en el campo Amo son: perforación vertical, direccional y horizontal. El objetivo de este trabajo es analizar qué tipo de perforación conviene hacer en el campo Amo. La selección del pozo a perforar, es mediante un análisis comparativo técnico-económico entre un pozo horizontal y un pozo direccional. Para este análisis es necesario disponer de la información técnica de los pozos seleccionados que se obtuvo a través de la operadora del Bloque 16. La formación Napo (arenisca M-1) son areniscas delgadas permeables. La completación de cada pozo está diseñada para extraer grandes cantidades de fluidos; la parte más elemental de este trabajo se basa en la comparación técnico-económica de los dos pozos seleccionados. En la evaluación técnica, se puede decir que el pozo horizontal Tigre 1, tiene una mayor producción de petróleo y agua, lo cual tiene un mejor rendimiento de ganancias. Finalmente, la perforación de los pozos, horizontal como direccional, ayuda a disminuir considerablemente la deforestación. Se concluye que la perforación de un pozo horizontal, comparado con un direccional, es más conveniente tanto técnica como económicamente, para los intereses de la empresa operadora de un campo. Abstract The types of drilling well executed in the Amo oilfield are vertical, directional and horizontal. The main objective of this paper is to analyze the best drilling way should be made in the Amo oilfield. The drilling well selection is by a techno-economical comparative analysis of a horizontal well and a directional well. For to make this analysis was necessary the use technical information of the selected wells, the data was obtained through the operator-company of Block 16 (Amo Oil field). The Napo (sandstone M-1) sandstones are thin and permeable. The completion of each well is designed to extract large quantities of fluids. The most important part of this work is based on technical and economic comparison of the two selected wells. In the technical evaluation, we can say that the Tiger (horizontal well) has increased production of oil and water, which performs better profit. The horizontal and directional well drilling would help to significantly reduce deforestation on the oilfield and increase the oil production. And, the horizontal drilling is more convenient than directional well according techno-economical aspects.
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Liu, Xiao Lan, Jian Gang Liu, and Hong Bo Niu. "Feasibility Study on Supercritical Carbon Dioxide Drilling Equipment." Applied Mechanics and Materials 318 (May 2013): 519–21. http://dx.doi.org/10.4028/www.scientific.net/amm.318.519.
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Some novel drilling technology has promoted the exploration of unconventional oil and gas resources greatly, such as gas drilling, long horizontal section well drilling and so on. As special matter, Supercritical carbon dioxide has many useful characteristic. For example, relative higher gravity like water, lower viscosity like gas and wonderful crude oil displacement characteristics, these could play some important role if being used in exploration of unconventional oil and gas. Therefore, the feasibility study of supercritical carbon dioxide drilling technology and equipment matching plan are discussed in this article to make the preliminary studies and preparation of related technology. On the basis of a lot of research and study, This paper carries out a feasibility study of supercritical carbon dioxide drilling equipment.
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Wu, Pengcheng, Chengxu Zhong, Zhengtao Li, Zhen Zhang, Zhiyuan Wang, and Weian Huang. "Oil-Based Drilling Fluid Plugging Method for Strengthening Wellbore Stability of Shale Gas." Geofluids 2021 (February 16, 2021): 1–13. http://dx.doi.org/10.1155/2021/6674574.
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Finding out the reasons for wellbore instability in the Longmaxi Formation and Wufeng Formation and putting forward drilling fluid technical countermeasures to strengthen and stabilize the wellbore are very crucial to horizontal drilling. Based on X-ray diffraction, electron microscope scanning, linear swelling experiment, and hot-rolling dispersion experiment, the physicochemical mechanism of wellbore instability in complex strata was revealed, and thus, the coordinated wellbore stability method can be put forward, which is “strengthening plugging of micropores, inhibiting filtrate invasion, and retarding pressure transmission.” Using a sand bed filtration tester, high-temperature and high-pressure plugging simulation experimental device, and microporous membrane and other experimental devices, the oil-based drilling fluid treatment agent was researched and selected, and a set of an enhanced plugging drilling fluid system suitable for shale gas horizontal well was constructed. Its temperature resistance is 135°C and it has preferable contamination resistibility (10% NaCl, 1% CaCl2, and 8% poor clay). The bearing capacity of a 400 μm fracture is 5 MPa, and the filtration loss of 0.22 μm and 0.45 μm microporous membranes is zero. Compared with previous field drilling fluids, the constructed oil-based drilling fluid system has a greatly improved plugging ability and excellent performance in other aspects.
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Faizullin, Rinat, Sergey Miroshnichenko, and Ravil Sultanov. "Bottom-hole pressure optimization when operating the well lateral horizontal hole." E3S Web of Conferences 217 (2020): 03008. http://dx.doi.org/10.1051/e3sconf/202021703008.
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The problem of optimization of technological parameters as a way to improve the efficiency of oil deposit exploitation is considered in the paper. There are no standards for parameters of well bottom-hole pressure for exploitation of lateral horizontal holes. The paper presents the evaluation of optimum bottom-hole pressure at which it is advisable to exploit the deposit lateral horizontal hole with maximum “water-free” production rate. Following the calculations carried out and analysis of the graphs of additional oil and liquid production dependence on bottom-hole pressure, graphs of production dynamics and water encroachment, it was concluded that 3 groups of drilling (kickoff) of lateral holes (KLH) should be distinguished: with high forecasted starting water encroachment (>90%), average starting water encroachment (about 80%), and low starting water encroachment (about 20-50%). The distinguished 3 groups allow applying the differentiation of parameters, for which optimum bottom-hole pressure parameters for each drilling group were found.
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Carpenter, Chris. "Smart-Horizontal-Well Drilling and Completion for Thin-Oil-Rim Reservoirs in Malaysia." Journal of Petroleum Technology 67, no. 05 (May 1, 2015): 103–7. http://dx.doi.org/10.2118/0515-0103-jpt.
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Lake, B. D., and V. Santostefano. "BASS STRAIT DRILLING - PREPARING FOR THE NINETIES." APPEA Journal 30, no. 1 (1990): 300. http://dx.doi.org/10.1071/aj89019.
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Future development drilling in Bass Strait will be challenged by small field sizes, thin oil columns and increasing drilling difficulty due to greater hole angle and reach. New drilling technology successfully introduced in the recent Bream, Whiting, Perch and Dolphin developments including Steerable Drilling Systems (SDS), Polycrystalline Diamond Compact (PDC) bits and Logging While Drilling (LWD) tools, coupled with the successful use of jackup rigs for miniplatform development, has given Esso the tools and confidence to meet the development challenges of the 'nineties. Bass Strait's first horizontal well has been successfully drilled and completed with further wells planned in the current Bream development. There still remain some areas requiring improvements, including hole cleaning in high angle holes. Improvements in this and other areas will further improve drilling capability.Given the right incentives Bass Strait drilling technology is well positioned for the challenge of oil development in the 'nineties.
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Kumar, Rajesh, S. Ramanan, and J. L. Narasimham. "Redevelopment of a Matured Multilayered Carbonate Offshore Field Through High Technology Horizontal and Multilateral Wells." SPE Reservoir Evaluation & Engineering 10, no. 05 (October 1, 2007): 453–57. http://dx.doi.org/10.2118/97520-pa.
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Summary Oil productivity from Mumbai High field, an offshore multilayered carbonate reservoir, increased significantly through the implementation of a major redevelopment program. Geoscientific information available from approximately 700 exploratory and develop- ment wells drilled in the field during nearly 25 years was incorporated during geological and reservoir simulation modeling of the field. High-technology drilling (viz. horizontal/multilaterals for the new development wells) was adopted on field scale to effectively address typical complexity of the layered carbonate reservoirs. Since the commencement of the project in 2000, approximately 140 new wells were drilled, mostly with horizontal and multilateral drainholes. Besides these, more than 70 suboptimal producers were also converted as horizontal sidetracks under brownfield development. The horizontal sidetracks were drilled as long-drift sidetrack (LDST), extended-reach drilling (ERD), LDST-ERD, short-drift sidetrack (SDST), and medium-radius drainhole (MRDH) types of wells through the application of innovative and emerging drilling technologies with nondamaging drilling fluids, whipstocks to kick off sidetrack wells, rotary-steering systems, and expandable tubulars to complete horizontal sidetracks in lower layers. With the implementation of this project, the declining trend was fully arrested and a significant upward trend in production has been established. Introduction The field redevelopment process requires the intergration of reservoir-development strategies, facility options, and drilling and production philosophies to maximize oil and gas recovery from a matured field. A significant number of case studies are available on mature field revitalization using a multidisciplinary team concept, exhaustive geo-scientific data analysis, and new drilling technologies (Chedid and Colmenares 2002; Clark et al. 2000; Dollens et al. 1999; Kinchen et al. 2001). Advancements in drilling and completion technology have enabled construction of horizontal wells with longer wellbores, more-complex well geometry, and sophisticated completion designs. Horizontal wells provide an effective method to produce bypassed oil from matured fields. In the early 1980s, this technology was in the development stage and was used in limited applications. By the 1990s, the technology had matured, and its acceptance in the industry had increased significantly. Performance of horizontal/multilateral wells, risk assessment of horizontal-well productivity and comparison of horizontal- and vertical-well performance in different fields is available in literature (Babu and Aziz 1989; Brekke and Thompson 1996; Economides et al. 1989; Joshi 1987; Joshi and Ding 1995; Mukherjee and Economides 1991; Norris et al. 1991; Vij et al. 1998). A significant number of horizontal/multilateral development wells were drilled as a part of redevelopment of Mumbai High, a matured multilayered carbonate offshore field in Western India. The details of new technologies applied and performance of these new high-technology wells are presented in this paper. Besides comparison of well productivity of horizontal and conventional sidetrack wells, this paper presents some technical issues faced.
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Ofei, Titus N., Sonny Irawan, and William Pao. "CFD Method for Predicting Annular Pressure Losses and Cuttings Concentration in Eccentric Horizontal Wells." Journal of Petroleum Engineering 2014 (April 10, 2014): 1–16. http://dx.doi.org/10.1155/2014/486423.
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In oil and gas drilling operations, predictions of pressure losses and cuttings concentration in the annulus are very complex due to the combination of interacting drilling parameters. Past studies have proposed many empirical correlations to estimate pressure losses and cuttings concentration. However, these developed correlations are limited to their experimental data range and setup, and hence, they cannot be applicable to all cases. CFD methods have the advantages of handling complex multiphase flow problems, as well as, an unlimited number of physical and operational conditions. The present study employs the inhomogeneous (Eulerian-Eulerian) model to simulate a two-phase solid-fluid flow and predict pressure losses and cuttings concentration in eccentric horizontal annuli as a function of varying drilling parameters: fluid velocity, diameter ratio (ratio of inner pipe diameter to outer pipe diameter), inner pipe rotation speed, and fluid type. Experimental data for pressure losses and cuttings concentration from previous literature compared very well with simulation data, confirming the validity of the current model. The study shows how reliable CFD methods can replicate the actual, yet complex oil and gas drilling operations.
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Bagnall, A. C., and J. B. Blanche. "The Use of Horizontal Drilling in International Exploration." Energy Exploration & Exploitation 10, no. 4-5 (September 1992): 230–45. http://dx.doi.org/10.1177/014459879201000404.
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Internationally (outside the USA) more than 300 horizontal wells were drilled in 1991. Horizontal well reservoir targets generally consist of a preponderance of clastic reservoirs over carbonates in the ratio of approximately 60% to 40%. The concept of using horizontal wells as an exploration tool can be defined as a means not only of proving new reserves in undrilled plays, but as a means of re-exploring previously drilled and poorly productive terrains. The Austin Chalk play in South Texas is the prime example of this concept in action. Exploration in this case can be defined as the adding of multiple orders of additional reserves value. International basin selection criteria are discussed which can optimise the chances of finding high value additional reserves in the initial stages of an exploration campaign by using horizontal drilling (with the important help of previous subsurface coverage or pilot drilling). These criteria include the presence of self sourcing carbonate reservoirs, the presence and predictability of regional fracturing, the mechanical properties of the reservoir rocks, the presence of significant original oil or gas-in-place and the reservoir depth criteria in which horizontal drilling technology is practicable and cost-effective.
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Luo, Min, Ting Ting Xu, Ting Ting Zhao, Wen Xin Zhao, and Ju Bao Liu. "Dynamic Analysis of Rotary Drillstring in Horizontal Well Based on the Fluid-Structure Interaction." Applied Mechanics and Materials 385-386 (August 2013): 146–49. http://dx.doi.org/10.4028/www.scientific.net/amm.385-386.146.
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With the development of drilling technology, rotary drillstring not only produces random multi-directional collisions with the inner wall of pipe, also couples with the inner and outer annular fluids. This results in a complex system of nonlinear fluid-structure interaction. In the paper, structure and mode of operation about rotary drillstring are considered, the equations of the structure dynamics, fluid equation of continuity and momentum equation are coupled. The three-dimensional numerical model and computational method is established about the fluidstructure interaction dynamic analysis of rotary drillstring. Take the rotary drillstring and inner and outer fluids as a research object, dynamic analysis of the rotary drillstring is finished, considering the fluid-structure coupled characteristics and compare the air medium, the results show the effect of fluidstructure interaction. It can provide the feasible method for the study of the string in the oil drilling and production engineering and conduct the development of drillstring dynamics in horizontal well drilling engineering.
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Anderson, Paul, Paul Bingaman, Sam Betts, Kyle Graves, Fred Fernandes, and Fiona O'Sullivan. "Improvements in development strategy for the Stag Oil Field, North West Shelf, Australia—implications for production success and drilling risk minimisation." APPEA Journal 52, no. 2 (2012): 657. http://dx.doi.org/10.1071/aj11071.
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Located on the North West Shelf of Western Australia, the Stag Oil field has proven to be a prolific reservoir, having produced more than 55 million barrels (MMbbls) of oil since 1998. This has not been without its challenges, however; with premature water breakthrough from injection wells occuring in several wells, potentially stranding large volumes of oil in the ground. Using the multicomponent processing and joint amplitude-versus-offset (AVO) inversion of an ocean bottom cable (OBC) seismic survey acquired in late 2007, new light has been shed on the distribution of unswept oil. This data has led to the succesful drilling of six wells and a marked increase in field production. Additionally, the seismic data has also been used to minimise drilling risks by using seismic coherency to steer the well around potential problems with a significant impact on well costs due to reduction of wellbore problems associated with horizontal drilling in the Muderong shale. To date, four wells have been drilled using this technique, resulting in a significant decrease in non-productive time while drilling during the most recent drilling campaign, which has a significant impact upon the profitability of these late-stage development wells.
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Salam, Massara, Nada S. Al-Zubaidi, and Asawer A. Al-Wasiti. "Lubricating Properties of Water-Based Drilling Fluid Improvement Using Lignite NPs as well as Their Effect on Rheological and Filtration Properties." Association of Arab Universities Journal of Engineering Sciences 26, no. 1 (March 31, 2019): 81–88. http://dx.doi.org/10.33261/jaaru.2019.26.1.011.
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In the process of drilling directional, extended-reach, and horizontal wells, the frictional forces between the drill string and the wellbore or casing can cause severe problems including excessive torque which is one of the most important problems during drilling oil and gas well. Drilling fluid plays an important role by reducing these frictional forces. In this research, an enhancement of lubricating properties of drilling fluids was fundamentally examined by adding Lignite NPs into the water-based drilling fluid. Lubricity, Rheology and filtration properties of water-based drilling fluid were measured at room temperature using OFITE EP and Lubricity Tester, OFITE Model 900 Viscometer, and OFITE Low-Pressure Filter Press, respectively. Lignite NPs were added at different concentrations (0.05 %, 0.1 %, 0.2 %, 0.5 %, and 1 %) by weight into water-based drilling fluid. Lignite NPs showed good reduction in COF of water-based drilling fluid. The enhancement was increased with increasing Lignite NPs concentrations; 23.68%, 35.52%, and 45.3 % reduction in COF were obtained by adding 0.2%, 0.5%, and 1% by weight Lignite NPs concentration, respectively.
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Panikarovskii, Evgeny V., Valentin V. Panikarovskii, and Alexandra E. Anashkina. "Vankor oil field development experience." Oil and Gas Studies, no. 1 (April 4, 2019): 47–51. http://dx.doi.org/10.31660/0445-0108-2019-1-47-51.
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The Vankor oil field is in the third stage of the development. Well stock mostly includes horizontal and directional wells. Analysis of the field development showed that actual development rate is much higher than planned. Energy potential of the field is drained out due to formation pressure decline and water flooding. New technologies for restoring well productivity, such as acid treatment and hydraulic fracturing should be introduced to maintain planned development rate. Drilling multilateral wells should be used as main enhanced oil recovery technique.
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Danilovskiy, K. N., A. R. Dudaev, V. N. Glinskikh, M. N. Nikitenko, and I. A. Moskaev. "Web-Technologies Based Software for Oil and Gas Wells Geosteering." Vestnik NSU. Series: Information Technologies 17, no. 2 (2019): 5–17. http://dx.doi.org/10.25205/1818-7900-2019-17-2-5-17.
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Accuracy of the horizontal well placement in the target reservoir becomes essential for efficient oilfield development. Geosteering of a well with a complex trajectory is performed using real-time geophysical data obtained while drilling. The presented work is devoted to the development of a new software for horizontal oil and gas wells geosteering. Algorithms based on logging data correlation and electromagnetic logging data numerical inversion methods are used for well placement. The developed application is based on web-technologies and has a client-server architecture. To optimize the resource-intensive calculations execution time, high-performance cloud computing is used.
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Chen, Xuyue, and Deli Gao. "The Maximum-Allowable Well Depth While Performing Ultra-Extended-Reach Drilling From Shallow Water to Deepwater Target." SPE Journal 23, no. 01 (August 16, 2017): 224–36. http://dx.doi.org/10.2118/183025-pa.
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Summary Ultra-extended-reach wells can be drilled from one platform to develop the remote surrounding satellite oil and gas reservoirs in deepwater. Although the platform is in shallow water, some ultra-extended-reach wells can target the reservoirs in deep water. In ultra-extended-reach drilling from shallow water to deepwater target, some challenges that may be faced are the presence of low temperature, typically weak overburden sediments, unconsolidated formations, and a small sedimentary coverage above the reservoir. This results in a narrow safe-mud-weight window and a limited well depth for ultra-extended-reach drilling operation. In this work, considering the pressure balance of bottom hole including the specific thermal and seepage effects, a method for predicting the well's maximum-allowable measured depth (MD) (MAMD) while performing ultra-extended-reach drilling from shallow water to deepwater target is presented. Meanwhile the factors affecting the MAMD are also investigated. The study shows that seepage significantly affects the MAMD while performing ultra-extended-reach drilling from shallow water to deepwater target: seepage turns out to significantly decrease the MAMD whereas heating the formation is found to be helpful in extending the MAMD. It also shows that the predicted MAMD turns out to be obvious anisotropy; for a normal regime depositional environment, drilling in the direction of minimum horizontal in-situ stress in the formation is prone to attain a wider safe-mud-weight window and a longer MAMD than other directions. Moreover, for a given target zone, the ultra-extended-reach drilling with a horizontal bottom hole has a much longer MAMD than that of ultra-extended-reach drilling with an inclined bottom hole, and the MAMD can also be effectively increased by reducing the annular friction-pressure loss. This work provides a practical tool for enhancing the design of ultra-extended-reach wells to develop the remote satellite oil and gas reservoirs in deep water.
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Liu, Tianle, Ekaterina Leusheva, Valentin Morenov, Lixia Li, Guosheng Jiang, Changliang Fang, Ling Zhang, Shaojun Zheng, and Yinfei Yu. "Influence of Polymer Reagents in the Drilling Fluids on the Efficiency of Deviated and Horizontal Wells Drilling." Energies 13, no. 18 (September 9, 2020): 4704. http://dx.doi.org/10.3390/en13184704.
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Improving the efficiency of well drilling process in a reservoir is directly related to subsequent well flow rates. Drilling of deviated and horizontal wells is often accompanied by an increase in pressure losses due to flow resistance caused by small size of the annular space. An important role in such conditions is played by the quality of borehole cleaning and transport capacity of drilling fluid, which is directly related to the rheological parameters of the drilling fluid. The main viscosifiers in modern drilling fluids are polymer reagents. They can be of various origin and structure, which determines their features. This work presents investigations that assess the effect of various polymers on the rheological parameters of drilling fluids. Obtained data are evaluated taking into account the main rheological models of fluid flow. However, process of fluid motion during drilling cannot be described by only one flow model. Paper shows experimentally obtained data of such indicators as plastic viscosity, dynamic shear stress, non-linearity index and consistency coefficient. Study has shown that high molecular weight polymer reagents (e.g., xanthan gum) can give drilling fluid more pronounced pseudoplastic properties, and combining them with a linear high molecular weight polymer (e.g., polyacrylamide) can reduce the value of the dynamic shear stress. Results of the work show the necessity of using combinations of different types of polymer reagents, which can lead to a synergetic effect. In addition to assessing the effect of various polymer reagents, the paper presents study on the development of a drilling fluid composition for specific conditions of an oil field.
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Berean, D., T. Slate, T. Wallace, R. Aldred, L. Hedger, P. Mills, and R. Cowley. "PLANNING AND DRILLING OF SINUOUS HORIZONTAL WELLS FOR THE GRIFFIN AREA DEVELOPMENT." APPEA Journal 34, no. 1 (1994): 19. http://dx.doi.org/10.1071/aj93002.
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The Griffin Area Development in the Barrow Sub-basin of Western Australia consists of three major oil fields, the Griffin, Scindian and Chinook fields.One of many new concepts of subsea technology used for the Griffin Area Development is the application of horizontal wells with a sinuous profile to improve oil recovery in the Birdrong reservoir.Reservoir simulation modelling initiated the concept and as a result, a multi-disciplined team was formed early in the pre-development phase to plan and implement a horizontal drilling program. Issues which were addressed by this team during planning included wellbore stability, drilling fluids, liner and completion design, wellpath orientation, reservoir constraints and formation evaluation techniques.After an extensive planning period, three sinuous path horizontal wells, Griffin-5(H), Griffin-6/ST1(H) and Scindian-2/STI(H) were successfully drilled in early 1993 by a semi-submersible rig as part of the Griffin/Scindian fields development drilling program.These sinuous wells have a well path profile which intersects the reservoir in three low-angle passes of the vertical section over a horizontal length of between 800 and 950 m, in the shape of a sine wave.A feature of the wells was the use of geosteering techniques to keep the sinuous profile on track to intersect specific reservoir targets, using the latest in formation evaluation measurement while drilling (FEMWD) technology.Although technically successful, the economic benefit of the horizontal wells will be measured by their production performance when tied into the 'Griffin Venture' floating production facility, expected on stream in early 1994.
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Rahnema, Milad, Hamed Rahnema, Marcia D. Mcmillan, Ali Reza Edrisi, and Hamid Rahnema. "Numerical Study of Single Well Vapor Extraction Process." Journal of Petroleum Engineering 2016 (November 8, 2016): 1–9. http://dx.doi.org/10.1155/2016/8925190.
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Vapor extraction (Vapex) is an emerging technology to produce heavy oil and bitumen from subsurface formations. Single well (SW) Vapex technique uses the same concept of Vapex process but only with one horizontal well. In this process solvent is injected from the toe of the horizontal well with oil production at the heel section. The main advantage of SW-Vapex process lies in the economic saving and applicability in problematic reservoirs, where drilling of two horizontal wells is impractical. The performance of SW-Vapex seems to be comparable with dual horizontal Vapex process using proper optimization schemes. This study is grouped into two sections: (i) a screening study of early time operating performance of SW-Vapex and (ii) a sensitivity analysis of the effect of the reservoir and well completion parameters. Simulation results show that solvent injection rate can be optimized to improve oil production rate. Higher injection rates may not necessarily lead to increase in production. This study confirms that SW-Vapex process is very ineffective in reservoirs with high oil viscosity (more than 1,500 cp) and thin formations (less than 10 m).
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Epikhin, Anton, Vitaly Zhironkin, and Michal Cehlar. "Prospects for the Use of Technology of Rotary Steerable Systems for the Directional Drilling." E3S Web of Conferences 174 (2020): 01022. http://dx.doi.org/10.1051/e3sconf/202017401022.
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In the process of gradual reorientation of the oil industry to the production of heavy hydrocarbons, inaccessible to traditional methods of production, the need arises for the application of modern technological solutions. One of these technologies is directional drilling, which poses new challenges for drilling equipment, such as facilitating sliding - changing the angle of well bore, improving the cleaning of the wellbore, reducing the risks of differential sticking, overcoming resistance during horizontal drilling, etc. A modern technological solution is rotary steerable systems (RSS) representing a new generation of downhole systems used in directional drilling. The article discusses the advantages and disadvantages of RSS technology, its modifications, gives a classification, also provides a comparative analysis of well wiring using rotary steerable systems and, the most widely used, mud motor.
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Wang, Xingming, Ping Chen, Wanzhi Huang, and Jiayan Zou. "Development of torque clutch drilling tool and evaluation of drag reduction performance." Advances in Mechanical Engineering 10, no. 10 (October 2018): 168781401880665. http://dx.doi.org/10.1177/1687814018806655.
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Horizontal well is one of the important methods of unconventional oil and gas resource development. As increasing length of horizontal section, there is a serious problem that axial force cannot transfer to bit. The drilling field needs a low-friction and low-cost drag reduction tool. This article summarized existing technologies of drag reduction in the horizontal and inclined well and proposes an integrated design of torque clutch. Detailed design of tool sub-systems is introduced. The tool includes three sub-systems: clutch, hydraulic system, and monitoring system. The clutch is consisted of multiple clutch units mounted in a parallel arrangement. Power of hydraulic control system adopts difference in pressure between inside and outside of drill pipes. It can efficiently reduce power consumption. The design function and minimum working pressure are validated and obtained by indoor test. According to theoretical calculation, reasonable distance from tool to bit can be obtained for an actual drilled well. During directional drilling mode, the tool can reduce more than 30% axial drag of drill string according to theoretical calculation. The tool can effectively improve the capacity of transfer weight to bit and overcome the excessive drag in horizontal drilling. No similar tools are reported in the current field.
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Carpenter, Chris. "Drilling Dynamics, Mechanical Specific Energy Data Help Drill Record Extended-Reach Well." Journal of Petroleum Technology 73, no. 05 (May 1, 2021): 59–60. http://dx.doi.org/10.2118/0521-0059-jpt.
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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 203335, “Using MSE and Downhole Drilling Dynamics in Achieving a Record Extended-Reach Well Offshore Abu Dhabi,” by Nashat Abbas and Jamal Al Nokhatha, ADNOC, and Luis Salgado, Halliburton, et al., prepared for the 2020 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, held virtually 9–12 November. The paper has not been peer reviewed. Complex extended-reach-drilling (ERD) wells often present challenges with regard to geological aspects of data requirement and transmittal, reactive geosteering response times, and accuracy of well placement. Such scenarios may require innovative approaches in Middle East carbonate reservoirs. The objective of the complete paper is to illustrate that, by assessing the details of reservoir geology and key operational markers relevant for best practices, drilling approaches can be customized for each reservoir or scenario. Reservoir Background and Geology The planned reservoir section is a single horizontal of approximately 25,000-ft lateral length at a spacing of 250 m from adjacent injectors. The well was drilled from an artificial island. Field A, a shallow-water oil field, is the second-largest offshore field and the fourth-largest field in the world. Horizontal drilling was introduced in 1989, and an extensive drilling campaign has been implemented since then using steerable drilling technologies. This study is concerned only with wells drilled to develop Reservoir B in Field A, which contributes to the main part of initial oil in place and production. The thick limestone reservoir is subdivided into six porous layers, labeled from shallow to deep as A, B, C, D, E, and F. Each porous layer is separated by thin, low-porosity stylolites. The reservoir sublayer B, consisting of approximately 18-ft-thick calcareous limestones, was selected as the target zone for the 25,420-ft horizontal section. ERD, constructed on artificial islands, began on 2014 with a measured depth (MD)/true vertical depth (TVD) ratio approaching 2.2:1 or 2.4:1. A recent ERD well, Well A, was drilled at the beginning of 2020 with a MD/TVD ratio of 5:1. This value is a clear indication of progressively increasing challenges since the start of the project. Mechanical specific energy (MSE) has long been used to evaluate and enhance the rate of penetration (ROP); however, its use as an optimization tool in ERD wells has not been equally significant. This may have been mostly because of historical use of surface-measured parameters, which do not necessarily indicate the energy required to destroy the rock, particularly in ERD wells. Using optimization tools as part of the bottomhole assembly (BHA) downhole close to the bit provides actual weight-on-bit (WOB) and torque-on-bit (TOB) applied to the drilling bit to destroy the rock and, thus, results in more-representative MSE measurements to optimize drilling parameters and ROP in ERD wells.
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Zaitcev, Roman A., and Aleksei V. Raspopov. "EXPERIENCE OF OILFIELD DEVELOPMENT IN PERM KRAI USING HORIZONTAL WELLS." Вестник Пермского национального исследовательского политехнического университета. Геология. Нефтегазовое и горное дело 20, no. 2 (June 2020): 182–91. http://dx.doi.org/10.15593/2224-9923/2020.2.8.
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Hydrocarbon reservoir engineering has a top priority to achieve the highest possible value of the cost-effective oilrecovery factor. Structural deterioration of residual oil reserves and inevitable development of hard-to-recover reservesrequire new effective technologies and engineering solutions. Today, there is a tendency to replace the standard sizewell drilling technologies (including vertical, directional, horizontal, multilateral wells) and standard size dualcompletion equipment usage by slim-hole drilling technologies. In Perm Krai fields, more than 385 horizontal wellshave been drilled, while 3.4 % of them, i.e. 13 wells, have a small diameter. The conducted well operation analysisshows that the effectiveness of the horizontal well operations in a number of instances is significantly lower than thepotential one. This leads to a deteriorated economic performance of reservoir developments, and, eventually, to assetvalue reductions. Perhaps, the main reason of low effectiveness of the horizontal well operations lies is an insufficientunderstanding of geological and physical conditions of their successful operations. It has become obvious that drillinghorizontal wells in reservoirs with high compartmentalization, low net oil thickness, and decreased hydrodynamicconnectivity to the edge water zone offer a low level of performance. Productivity tends to decrease to average outputvalues of directional wells. Therefore, the problem of choosing a well design and its direction in specific geological andphysical conditions is highly relevant.
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Cravens, Daniel. "US experiences in water management of shale gas developments." APPEA Journal 54, no. 2 (2014): 541. http://dx.doi.org/10.1071/aj13114.
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More than 1,700 drilling rigs are operating in the US, with more than half in Texas. The avid and dry Permian Basin in southwest Texas is one of the most prolific oil and gas basins in the US. Vertical drilling to depths of 4,000 m, with horizontal laterals 2,000 m, is common. The fraccing of a horizontal well requires large amounts of water. In areas that completely depend on groundwater for frac water, the demand for the resource is high. Water transport and treatment costs can threaten the viability of even the best of projects. The volume of water required for different horizontal frac operations, changes depending on the formation, frac solutions, and lateral frac distances. Discoveries are being made that have determined that larger diameter horizontal fracs are yielding more product, but they require even more water. The oil and gas industry is beginning to realise that groundwater drilling and resource management can make or break an oil and gas project. In these areas where water availability depends initially on groundwater supply, a complete understanding of the available groundwater resource is critical. Economically viable solutions can ultimately be a combination of new wells, treated water, moveable water distribution systems, mobile treatment plants, surface storage, and deep injection of brine fluids. In this extended abstract, the experiences gained on existing shale gas developments in the US are used to address specific challenges faced in Australia.
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Yang, Erlong, Huan Li, Huijuan Gao, Juquan Jia, and Meng Qi. "Layer Selection Method of Ultra-Short Radius Horizontal Wells." Open Petroleum Engineering Journal 9, no. 1 (August 26, 2016): 169–77. http://dx.doi.org/10.2174/1874834101609160169.
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Study on the technology that sidetracking horizontal wells with ultra-short radius to select boundary layer has certain practical meaning. But recently this kind of research, especially the study on sidetracking position for horizontal well, is less or even none. In this paper, on the basis of the potential superposition method and the equivalent flowing resistance method, the cumulative oil production calculation model of the horizontal well after sidetracking is established. Then the dimensionless height from the top is introduced to modify the model with the means of numerical simulation. Therefore set up the relationship between the cumulative oil production and six factors such as cumulative oil production, effective thickness, the dimensionless height from the top, average permeability, oil and water wells, the average remaining oil saturation and completeness of drilling stage for horizontal well. By combining break-even analysis, layer selection method of ultra-short radius horizontal wells is determined. A relevant chart is also obtained. The method established in this paper can help to choose the optimal layer of sidetracking horizontal well with ultra-short radius.
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Nguyen, Lucien Jason, Paul F. Pickering, and Zachary M. Aman. "The application of risk-based methods to multilateral well design." APPEA Journal 56, no. 1 (2016): 427. http://dx.doi.org/10.1071/aj15031.
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Horizontal and multilateral oil and gas wells are used to maximise hydrocarbon recovery while reducing the required well count and associated costs. Presently, lateral lengths are designed using semi-quantitative methods. Guided by a desire to minimise the risk of poor well deliverability, the tendency is to design producing lengths longer than required, with the rationale that the well connects with sufficient hydrocarbon bearing reservoir to provide good deliverability. Drilling long producing lengths, however, is expensive and generates a higher risk of drilling and lifecycle (intervention and workover) problems. Furthermore, attempting to increase deliverability by extending the producing length encounters the law of diminishing returns as the flow becomes constrained by tubing friction loss. This paper seeks to quantify the optimal length for a horizontal well for a given range of reservoir conditions through multiphase fluid modelling and stochastic analysis. A discretised horizontal well model was created, which shows how changing the well length transforms the probability density function of the production rate for the well. A parametric case study was conducted, which demonstrates the evolution of the optimal well length and production rate with parameters including well diameter, fluid viscosity and well flowing bottomhole pressure. A simplified economic analysis illustrates the incremental change in discounted cash flow and quantified risk from drilling a longer well. The model also considered the influence of inflow control devices (ICDs) to adjust the inflow to match permeability and even-out inflows along the producing length, thus reducing the risk of gas and water coning, and improving hydrocarbon recovery.
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Tank, W. J., B. C. Curran, and E. E. Wadleigh. "Targeting Horizontal Wells—Efficient Oil Capture and Fracture Insights." SPE Reservoir Evaluation & Engineering 2, no. 02 (April 1, 1999): 180–85. http://dx.doi.org/10.2118/55984-pa.
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Summary Horizontal well targeting is often a greater challenge in massive, fractured carbonates than in low-productivity, poorly connected, and relatively thin reservoirs. This paper discusses methods to target horizontal wellbores in three-dimensional space to both confirm the fracture interpretation and establish high-efficiency oil capture. Several well examples are presented to illustrate the targeting objectives and the resulting well performance. Early in the program, the horizontal drilling objectives sought to maximize the lateral length in a direction determined by offset well productivity; the sample philosophy as is used in matrix-dominated reservoirs. Analysis of these results and employment of methods presented in this paper indicate profit can be maximized by drilling to a specific target to intersect a fracture trend at an optimum elevation instead of concentrating on maximizing length of lateral. Intervals of rapid penetration, lost circulation, and/or bit slides, along with cutting sample compositions, provided insight for confirmation and extension of the fracture network interpretation. The width of disturbance and degree of fracturing observed along interpreted fracture trends are valuable data for improved fracture network interpretation and computer simulation. Both the elevation and number of fracture branches encountered are significant strategic planning issues for oil recovery from unconfined oil columns in a massive carbonate system. Results from a large number of horizontals indicate significant productivity increases are achieved by proper targeting of laterals into major fracture features. Introduction Horizontal wells provide a unique assessment tool for formations containing reservoirs dominated by discontinuous flow features such as fractures or interbedded sandstones. Massive carbonate formations are the most extreme setting for large-scale, high-contrast, discontinuous reservoir properties. In sandstones of moderate to low quality, horizontals are typically applied to improve rate by exposing additional formation for fluid entry at high drawdown. In carbonates, horizontals serve to intersect high-conductivity flow features. In sandstones, high flow quality often coincides with sand accumulation. In contrast, carbonate flow is often highly discontinuous while storage capacity remains a relatively continuous function (as limited by depositional and diagenetic porosity history). Since 1993, significant study has gone into identifying the extent and quality of fracture networks and the impact these systems have had on reservoir management, fluid reinjection, and completion efficiency.1,2 In west Texas alone, well over 100 short-radius horizontal wells have been drilled in one field since 1986. Horizontals drilled in this fractured carbonate reservoir were initially done to maximize oil production while limiting gas coning.3 With the recent fracture studies, emphasis has moved to using horizontal boreholes to connect with large flow features not penetrated in existing wellbores.4,5 These more recent wells have targeted fracture zones interpreted from flexure maps which are developed from a second derivative analysis of structural surface maps. This paper provides results of several horizontal wells drilled with the intent of cutting the interpreted fracture zones. Targeting horizontal wells requires an understanding of massive carbonate features as well as discontinuous flow features. This paper will discuss how mapping was used to determine flow-feature locations; how horizontal drilling techniques were used to intersect these targeted flow features; and a discussion of the refinement of the interpretation and the drilling operations. Massive Carbonate Flow Features What is a massive carbonate? Carbonates that have relatively thick (100 ft or greater) intervals of mixed porous and tight/brittle rock types, free of continuous soft shale or anhydrite layers, are considered massive for this discussion. Structural deformation is subtle in many massive carbonate reservoirs, but still highly significant in generating preferential flow within the reservoir body. Minor deformation, as resulting from differential compaction and formation dip growth is accommodated in a range of extensional fracturing of the relatively brittle carbonates. Potential solution enhancement of fracture and fault zones further enhances flow. The highly conductive flow features of these carbonates often are a mix of bedding parallel (matrix) and subvertical (fracture) features.2 Data gathered from vertical wells can bias the interpretation of flow-feature population due to sampling a greater population of bedding parallel features. Vertical wells statistically encounter numerous short, mostly random-oriented fractures, but very few of the largest subvertical fracture features. Horizontal wells, in contrast, encounter few bedding parallel flow features in exchange for a full range of subvertical fracture flow features. Horizontal wells can provide data for direct assessment of fracture frequency and matrix block size in contrast to the highly interpretive approach required for assessment from vertical well data. More importantly, horizontal well data provides insight into the lateral variance in subvertical fracture features. Significant variation is expected between low fracture intensity near the center of a large formation block relative to the high frequency expected near the edges of this block where strain is concentrated. Block edges for large-scale features may follow obvious faults, hingelines (linear trends of dip change), or structural noses. Fig. 1 conceptually illustrates a fractured rock mass with a horizontal well intersecting a strain zone of likely high-flow capacity. Often, the structural indications of block-edge strain zones are subtle and easily merged with interpreted depositional or erosional changes across the field. Here, horizontal well data are critical to generation of an adequate flow-feature model.
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Majdi, Abbas, Mansour Mostafa-zadeh, and Vali Ahmad Sajjadian. "Direction and prediction of well priority drilling for horizontal oil and gas wells (A case study)." Journal of Petroleum Science and Engineering 49, no. 1-2 (October 2005): 63–78. http://dx.doi.org/10.1016/j.petrol.2005.06.011.
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Pogrebnaya, I. A., and S. V. Mikhailova. "Efficiency Analysis of the Geological-Technical Activities in Severo-Ostrovnoe Field." Journal of Computational and Theoretical Nanoscience 16, no. 11 (November 1, 2019): 4584–88. http://dx.doi.org/10.1166/jctn.2019.8359.
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The work is devoted to identifying the most relevant geological and technical measures carried out in Severo-Ostrovnoe field from the period of its development to the present. Every year dozens of geotechnical jobs (GJ) are carried out at each oil field-works carried out at wells to regulate the development of fields and maintain target levels of oil production. Today, there are two production facilities in the development of the Severo-Ostrovnoe field: UV1a1 and BV5. With the help of geotechnical jobs, oil-producing enterprises ensure the fulfillment of project indicators of field development (Mikhailov, N.N., 1992. Residual Oil Saturation of Reservoirs Under Development. Moscow, Nedra. p.270; Good, N.S., 1970. Study of the Physical Properties of Porous Media. Moscow, Nedra. p.208). In total, during the development of the Severo-Ostrovnoe field, 76 measures were taken to intensify oil production and enhance oil recovery. 12 horizontal wells were drilled (HW with multistage fracking (MSF)), 46 hydraulic fracturing operations were performed, 12 hydraulic fracturing operations were performed at the time of withdrawal from drilling (HW with MSF), five sidetracks were cut; eight physic-chemical BHT at production wells; five optimization of well operation modes. The paper analyzes the performed geological and technical measures at the facilities: UV1a1∦BV5 of the Severo-Ostrovnoe field. Four types of geological and technical measures were investigated: hydraulic fracturing, drilling of sidetracks with hydraulic fracturing, drilling of horizontal wells with multi-stage hydraulic fracturing, and physic-chemical optimization of the bottom-hole formation zone. It was revealed that two geotechnical jobs, namely, formation hydraulic fracturing (FHF) and drilling of lateral shafts in the Severo-Ostrovnoe field are the most highly effective methods for intensifying reservoir development and increasing oil recovery. SXL was conducted at 5 wells. The average oil production rate is 26.6 tons per day, which is the best indicator. Before this event, the production rate of the well was 2.1 tons per day. Currently, the effect of ongoing activities continues.
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Mohamed, Abdulrahman. "Novel approach for anti-collision planning optimization in directional wells." International Journal of Engineering & Technology 9, no. 2 (April 3, 2020): 333. http://dx.doi.org/10.14419/ijet.v9i2.30306.
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One of the most application of the directional drilling is drilling multiple wells from one location or platform. In drilling multiple wells from one location the major problem that faced is avoiding the collision with the offset wells that drilled near the proposed well in the same region. Therefore, the Potential of Collison between the wells can cause severe catastrophic accidents such as an explosion or oil spill. Several measurements of proximity calculation or methods have been adopted to control the distance between the wells, avoid the Collison, increas-ing the clearance along with smoothing the trajectory, Reducing the drilling time based on the anti-collision rules. A real case study of an offshore directional horizontal well drilled from the platform is studied through the paper. The proposed well is drilled in the neighboring of three Offset wells that should be Planned completely to avoid the Collison with them. The well is planned through an advanced anti-collision method that results in preventing the collision of well with optimized drilling performance through Oriented separation factor (OSF). This factor yields appropriate separation with OSF greater than 5. This yield efficient separation with offset well 1, offset well 2 and offset well 3 greater thant5, In addition to optimized drilling performance of 84% drilling versus 16% sliding that results in the completion of the well in 50 days with positive income that result in 8.55 Return on Investment (ROI).
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Carter, A., and J. Heale. "The Forties and Brimmond Fields, Blocks 21/10, 22/6a, UK North Sea." Geological Society, London, Memoirs 20, no. 1 (2003): 557–61. http://dx.doi.org/10.1144/gsl.mem.2003.020.01.45.
Full textAbstract:
AbstractThis paper updates the earlier account of the Forties Field detailed in Geological Society Memoir 14 (Wills 1991), and gives a brief description of the Brimmond Field, a small Eocene accumulation overlying Forties (Fig. 1).The Forties Field is located 180 km ENE of Aberdeen. It was discovered in 1970 by well 21/10-1 which encountered 119 m of oil bearing Paleocene sands at a depth of 2131 m sub-sea. A five well appraisal programme confirmed the presence of a major discovery including an extension into Block 22/6 to the southeast. Oil-in-place was estimated to be 4600 MMSTB with recoverable reserves of 1800 MM STB. The field was brought onto production in September 1975. Plateau production of 500 MBOD was reached in 1978, declining from 1981 to 77 MBOD in 1999.In September 1992 a programme of infill drilling commenced, which continues today. The earlier infill targets were identified using 3D seismic acquired in 1988. Acquisition of a further 3D survey in 1996 has allowed the infill drilling programme to continue with new seismic imaging of lithology, fluids and saturation changes. The performance of the 1997 drilling showed that high step-out and new technology wells, including multi-lateral and horizontal wells, did not deliver significantly better targets than drilling in previous years.In line with smaller targets, and in the current oil price environment, low cost technology is being developed through the 1999 drilling programme. Through Tubing Rotary Drilling (TTRD) is currently seen as the most promising way of achieving a step
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Kamyab, Mohammadreza, Nelson Chin, Vamegh Rasouli, Soren Soe, and Swapan Mandal. "Coiled tubing drilling for unconventional reservoirs: the importance of cuttings transport in directional drilling." APPEA Journal 54, no. 1 (2014): 329. http://dx.doi.org/10.1071/aj13033.
Full textAbstract:
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.
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Zhao, Meng, Xiang Zhe Zhu, and Chun Lei Wang. "Nonlinear Dynamic Analysis of Drill String System for Horizontal Oil Well with Different Positions of Stabilizers." Applied Mechanics and Materials 716-717 (December 2014): 615–18. http://dx.doi.org/10.4028/www.scientific.net/amm.716-717.615.
Full textAbstract:
For the horizontal well of petroleum drilling engineering, the horizontal section of drill string was selected as a research object. Collision and friction between drill string and well wall, displacement response on the drill bit and other boundary conditions were considered in this simulated modeling. By using finite element analysis software ANSYS, the dynamic characteristics of horizontal section of drill string were calculated and discussed. The effect of different positions of stabilizers on the vibration characteristics of drill string were studied specially. The calculated results show that the installation positions of stabilizers have remarkable effects on the dynamic characteristics of drill string. It will change the lateral vibration and whirling motion of drill string remarkably. Furthermore, the reasonably installation of the stabilizers can decrease the amplitudes of lateral vibration and transient torque. Those results may provide some guidance for the vibration analysis of drill string system.
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Sha, Linxiu, and Zhongqi Pan. "FSQGA based 3D complexity wellbore trajectory optimization." Oil & Gas Sciences and Technology – Revue d’IFP Energies nouvelles 73 (2018): 79. http://dx.doi.org/10.2516/ogst/2018008.
Full textAbstract:
Determination of the trajectory of a complex wellbore is very challenging due to the variety of possible well types, as well as the numerous complicated drilling variables and constraints. The well type could be directional wells, cluster wells, horizontal wells, extended reach wells, redrilling wells, and complex structure wells, etc. The drilling variables and constraints include wellbore length, inclination hold angles, azimuth angles, dogleg severity, true vertical depths, lateral length, casing setting depths, and true vertical depth. In this paper, we propose and develop an improved computational model based on Fibonacci sequence to adjust the quantum rotation step in quantum genetic algorithm for achieving cost-efficient complex wellbore trajectories. By using Fibonacci sequence based quantum genetic algorithm (FSQGA) in a complex searching problem, we can find high-quality globally optimal solutions with high speed through a parallel process. The simulation results show that FSQGA can significantly reduce computation complexity, and reach minimum objection values faster. Meanwhile, minimization of the true measurement depth of complex wellbore trajectory in actual gas-oil field shows that the drilling cost can be reduced up to 4.65%. We believe this new algorithm has the potential to improve drilling efficiency, to reduce the drilling time and drilling cost in real-time wellbore trajectory control.
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Yi, Xian Zhong, Jun Feng Zhang, and Sheng Zong Jiang. "Cuttings Characteristics and Mechanics Behavior in Horizontal Wells of Liaohe Oil Field." Applied Mechanics and Materials 316-317 (April 2013): 842–45. http://dx.doi.org/10.4028/www.scientific.net/amm.316-317.842.
Full textAbstract:
Cuttings transport of drilling and washing process in horizontal well is a typical two-phase (liquid-solid) or three-phase (gas-liquid-solid) flow phenomena. In this paper, it analyzes the flow characteristics of Huan 127-Lian H2 horizontal wellbore , then uses experimental method to study the behavior of the particle size distribution and the mechanics. This study provides an important way to master cuttings settling in fluid medium, it can explain how the cuttings bed is generated and cleared, and why the procession of cuttings of migration is stopped. In addition, measurement and analysis of drill cuttings is the basis erosion and abrasion analysis of BHA.
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Al Kindi, M., M. Al-Lawati, and N. Al-Azri. "Estimating Drilling Cost and Duration Using Copulas Dependencies Models." Journal of Engineering Research [TJER] 14, no. 1 (March 1, 2017): 1. http://dx.doi.org/10.24200/tjer.vol14iss1pp1-9.
Full textAbstract:
Estimation of drilling budget and duration is a high-level challenge for oil and gas industry. This is due to the many uncertain activities in the drilling procedure such as material prices, overhead cost, inflation, oil prices, well type, and depth of drilling. Therefore, it is essential to consider all these uncertain variables and the nature of relationships between them. This eventually leads into the minimization of the level of uncertainty and yet makes a "good" estimation points for budget and duration given the well type. In this paper, the copula probability theory is used in order to model the dependencies between cost/duration and MRI (mechanical risk index). The MRI is a mathematical computation, which relates various drilling factors such as: water depth, measured depth, true vertical depth in addition to mud weight and horizontal displacement. In general, the value of MRI is utilized as an input for the drilling cost and duration estimations. Therefore, modeling the uncertain dependencies between MRI and both cost and duration using copulas is important. The cost and duration estimates for each well were extracted from the copula dependency model where research study simulate over 10,000 scenarios. These new estimates were later compared to the actual data in order to validate the performance of the procedure. Most of the wells show moderate - weak relationship of MRI dependence, which means that the variation in these wells can be related to MRI but to the extent that it is not the primary source.