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Journal articles on the topic 'Oil fields'

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Published: 4 June 2021
Last updated: 29 July 2024

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1

Nakstad, Hilde, and Jon Thomas Kringlebotn. "Probing oil fields." Nature Photonics 2, no. 3 (March 2008): 147–49. http://dx.doi.org/10.1038/nphoton.2008.18.

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2

GUMENNIKOV, E. S., N. S. BUKTUKOV, B. ZH BUKTUKOV, and E. S. YESBERGENOVA. "MINING PREPARATION OF OIL FIELDS OF SHALLOW-LYING VISCOUS OIL FIELDS." Neft i Gaz, no. 4 (August 30, 2023): 81–93. http://dx.doi.org/10.37878/2708-0080/2023-4.06.

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In this paper, the idea of combining the experience of mining and oil production with the possibility of using gravity forces to extract oil is considered. It provides for the sinking of mine workings and wells that contribute to the outflow of oil down into the mine workings, thereby eliminating the resistance of gravity forces to the extraction of oil from the oil reservoir. At the same time, the viscosity of the oil, which resists the expiration, is taken into account.
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3

Saeed, Diyar A., and Ibrahim M. J. Mohialdeen. "Biomarker characteristics of oils from Garmian Oil Fields and potential Jurassic source rocks, Kurdistan,NE Iraq: implications for oil–oil and oil-source rocks correlation." Journal of Zankoy Sulaimani - Part A 18, no. 2 (November 12, 2015): 43–62. http://dx.doi.org/10.17656/jzs.10503.

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4

Aldhous, Peter. "Oil fields under control." Nature 354, no. 6348 (November 1991): 5. http://dx.doi.org/10.1038/354005b0.

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5

Denney, Dennis. "Revitalizing Old-Asset Oil Fields Into Intelligent Fields." Journal of Petroleum Technology 61, no. 09 (September 1, 2009): 72–73. http://dx.doi.org/10.2118/0909-0072-jpt.

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6

Elshan Aliyev, Azer Gasimli, Elshan Aliyev, Azer Gasimli. "ON DEVELOPMENT OF OIL FIELDS." ETM - Equipment, Technologies, Materials 21, no. 03 (May 27, 2024): 04–10. http://dx.doi.org/10.36962/etm21032024-01.

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Using a literature review, the article concludes that the displacement of oil by surfactants affects interrelated factors: by affecting the surface tension at the oil-water-rock interface, SAM adsorption occurs on the surface of pore channels, rock surface water and oil wetting changes, the oil layer is broken up and washed from the rock surface, the dispersion of oil in water stabilizes, the phase permeability of the porous medium changes, and finally, the forced displacement of oil by the water phase occurs. Keywords: gravity, elastic, capillary forces, adhesion, adsorption.
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7

Mamalov, E. N., and E. V. Gorshkova. "INTENSIFICATION OF OIL PRODUCTION IN DEPLETED OIL FIELDS." Oilfield Engineering, no. 8 (2019): 30–34. http://dx.doi.org/10.30713/0207-2351-2019-8(608)-30-34.

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8

Denney, Dennis. "To Support Digital Oil Fields." Journal of Petroleum Technology 58, no. 10 (October 1, 2006): 71–72. http://dx.doi.org/10.2118/1006-0071-jpt.

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9

Munisteri, Islin, and Maxim Kotenev. "Mature Oil Fields: Preventing Decline." Way Ahead 09, no. 03 (October 1, 2013): 9–17. http://dx.doi.org/10.2118/0313-009-twa.

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10

McNutt, James C., Paul F. Lambert, Kenny A. Franks, Jim Lanning, and Judy Lanning. "Voices from the Oil Fields." Western Historical Quarterly 16, no. 4 (October 1985): 453. http://dx.doi.org/10.2307/968612.

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11

Ducker, James H., Roger M. Olien, and Diana Davids Olien. "Life in the Oil Fields." Western Historical Quarterly 18, no. 2 (April 1987): 224. http://dx.doi.org/10.2307/969613.

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12

Camponogara, Eduardo, Melissa Pereira de Castro, Agustinho Plucenio, and Daniel Juan Pagano. "Compressor scheduling in oil fields." Optimization and Engineering 12, no. 1-2 (October 23, 2009): 153–74. http://dx.doi.org/10.1007/s11081-009-9093-3.

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13

Deryaev, Annaguly Rejepovich. "BASICS OF OIL FIELDS DEVELOPMENT." Theoretical & Applied Science 118, no. 02 (February 28, 2023): 289–92. http://dx.doi.org/10.15863/tas.2023.02.118.24.

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14

Seggie, R., F. Jamal, A. Jones, M. Lennane, G. McFadzean, and J. Rogers. "SUB-SURFACE UNCERTAINTY IN OIL FIELDS: LEARNINGS FROM EARLY PRODUCTION OF LEGENDRE OIL FIELDS." APPEA Journal 43, no. 1 (2003): 401. http://dx.doi.org/10.1071/aj02021.

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The Legendre North and South Oil Fields (together referred to as the field) have been producing since May 2001 from high rate horizontal wells and had produced 18 MMBBL by end 2002. This represents about 45% of the proven and probable reserves for the field.Many pre-drill uncertainties remain. The exploration and development wells are located primarily along the crest of the structure, leaving significant gross rock volume uncertainty on the flanks of the field. Qualitative use of amplitudes provides some insight into the Legendre North Field but not the Legendre South Field where the imaging is poor. The development wells were drilled horizontally and did not intersect any fluid contacts.Early field life has brought some surprises, despite a rigorous assessment of uncertainty during the field development planning process. Higher than expected gas-oil ratios suggested a saturated oil with small primary gas caps, rather than the predicted under-saturated oil. Due to the larger than expected gas volumes, the gas reinjection system proved to have inadequate redundancy resulting in constrained production from the field. The pre-drill geological model has required significant changes to reflect the drilling and production results to date. The intra-field shales needed to be areally much smaller than predicted to explain well intersections and production performance. This is consistent with outcrop analogues.Surprises are common when an oil field is first developed and often continue to arise during secondary development phases. Learnings, in the context of subsurface uncertainty, from other oil fields in the greater North West Shelf are compared briefly to highlight the importance of managing uncertainty during field development planning. It is important to have design flexibility to enable facility adjustments to be made easily, early in field life.
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15

Altunina, L. K., and V. A. Kuvshinov. "Physicochemical methods for enhancing oil recovery from oil fields." Russian Chemical Reviews 76, no. 10 (October 31, 2007): 971–87. http://dx.doi.org/10.1070/rc2007v076n10abeh003723.

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16

Filippov, Aleksandr, Pavel Mikhaylov, and Rustyam Salikhov. "Temperature fields during filtration wax oil in porous formation." Modern science: researches, ideas, results, technologies 8, no. 1 (April 26, 2017): 40–59. http://dx.doi.org/10.23877/ms.ts.26.007.

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17

Ismayılov, F. S., F. G. Gasanov, Kh A. Soltanova, S. Ch Bayramova, and N. M. Mammadzadeh. "Increasing performance efficiency of reconstructed oil fields." Azerbaijan Oil Industry, no. 05 (May 15, 2023): 38–42. http://dx.doi.org/10.37474/0365-8554/2023-5-38-42.

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In the oil-gathering stations of most OGPDs, oil water sand clay mixtures that enter the settling equipment after passing through the separators are initially separated and collected in appropriate tanks. Prior to the production of commercial oil, more labor and energy is utilized to separate water and sand-clay mixtures from oil. Tanks are quickly contaminated with bottom sediments consisting of sand-clay and cleaning of them is difficult. Mixtures of sand-clay-water from settler, formation water from oil tanksa are drained into open oil traps, as a result, the environment is polluted with oil wastes and oil losses occur. It is more efficient to use a horizontal oil and gas separator to overcome shortcomings identified in the reconstruction of the tank farm with a capacity of more than 1.500 m3/day. Sand-clay separator should be installed at the inlet of it to protect the separator and tanks from sand-clay mixed sediments. Sand-clay separators should be installed inside the overflow tanks for better separation of formation water and sand-clay mixtures from oil, oil suspensions and sand-clay mixtures from water in formation water storage tanks. In order to reduce evaporation losses in the tanks, an auxiliary palte should be used under the PSV and the gas phase of the technological tanks and commercial oil tanks should be connected via pipes.
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18

Ramazanova, Y. B. "DEPRESSOR ADDITIVE FOR OIL PUMPING." Chemical Problems 19, no. 3 (2021): 143–49. http://dx.doi.org/10.32737/2221-8688-2021-3-143-149.

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The purpose of the research was to study rheological properties of Azerbaijani oils from the Sangachali and Muradkhanli fields. In order to improve rheological properties of the oil produced from the Muradkhanli and Sangachali fields, a Russian-made depressant СНПХ -2005 additive was used. To determine the optimal concentration of the СНПХ-2005 and confirm its positive effect on oil and oil products, control samples were prepared with this additive in oil M-8 and the oil from the above fields with the calculation of 0.5 kg/t, 0.8 kg/t and 1.0 kg/t. In parallel, similar samples were prepared with the depressant АзНИИ. The pour points of the samples were investigated at -5 0С, -100С and -200С on the rotational viscometer REOTECT-2. It found that the sample with the СНПХ -2005 additive (at the concentration of 0.8%) in the M-8 oil has a lower pour point (minus 40°C) as compared to a similar sample with the depressant АзНИИ (-32°C). The sample with the depressant СНПХ-2005 (at the concentration of 0.8%) and oil reveals the best rheological properties (minus 38°C versus -30°C). As a result of the studies carried out, it was determined that the introduction of the depressant СНПХ-2005 improves rheological parameters of the oil from the above fields, and thereby makes it possible to refuse additional heating in low temperature areas when pumping oil through the oil pipeline.
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19

Jangulova, G., and A. Kuanyshkyzy. "Engineering-geodetic support on oil fields." Journal of Geography and Environmental Management 41, no. 2 (2015): 268–72. http://dx.doi.org/10.26577/jgem.2015.2.248.

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20

Dyachuk, I. A. "Reformation of oil fields and reservoirs." Georesursy 60, no. 1 (2015): 39–45. http://dx.doi.org/10.18599/grs.60.1.8.

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21

Abdelrehim Abouelnaga, Ahmed Abdelkader, and Mohamad Ali Alawiyeh. "DEVELOPING OIL FIELDS BY BACTERIA (MEOR)." Теория и практика современной науки, no. 5 (2021): 7–9. http://dx.doi.org/10.46566/2412-9682_2021_71_7.

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22

Wilkerson, Bob, Tony Shelton, and Allen Caudle. "MEDIA RELATIONS IN THE OIL FIELDS." International Oil Spill Conference Proceedings 1997, no. 1 (April 1, 1997): 988. http://dx.doi.org/10.7901/2169-3358-1997-1-988.

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ABSTRACT Developing and implementing an integrated field media relations strategy during an oil spill is critical to the success of an overall response effort. A company's crisis media relations plan should address all of the issues associated with communicating with the media during an oil spill incident. The plan should place particular emphasis on how one will coordinate the media strategy with one's field, the regional and corporate staff, and the public information officers from all of the involved regulatory agencies. If the effort is coordinated, everyone can respond quickly with the facts that the media want to know and speak with one voice.
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23

Magot, Michel. "Similar bacteria in remote oil fields." Nature 379, no. 6567 (February 1996): 681. http://dx.doi.org/10.1038/379681b0.

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24

Tyusenkov, A. S., and O. A. Nasibullina. "Corrosion of tubing of oil fields." IOP Conference Series: Materials Science and Engineering 687 (December 10, 2019): 066016. http://dx.doi.org/10.1088/1757-899x/687/6/066016.

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25

Mikhailov, N. N., O. M. Ermilov, and L. S. Sechina. "Adsorbed oil of gas condensate fields." Russian Geology and Geophysics 57, no. 6 (June 2016): 958–66. http://dx.doi.org/10.1016/j.rgg.2015.01.027.

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26

Rohlf, Greg. "Dreams of Oil and Fertile Fields." Modern China 29, no. 4 (October 2003): 455–89. http://dx.doi.org/10.1177/0097700403257134.

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27

Kok, Mustafa Versan, Egemen Kaya, and Serhat Akin. "Monte Carlo Simulation of Oil Fields." Energy Sources, Part B: Economics, Planning, and Policy 1, no. 2 (July 2006): 207–11. http://dx.doi.org/10.1080/15567240500400770.

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28

Marakushev, A. A., and S. A. Marakushev. "Formation of oil and gas fields." Lithology and Mineral Resources 43, no. 5 (September 2008): 454–69. http://dx.doi.org/10.1134/s0024490208050039.

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29

Durlofsky, Louis J., and Roussos Dimitrakopoulos. "Smart Oil Fields and Mining Complexes." Mathematical Geosciences 49, no. 3 (April 2017): 275–76. http://dx.doi.org/10.1007/s11004-017-9683-0.

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30

Fanchi, J. R., R. L. Christiansen, and M. J. Heymans. "Estimating Oil Reserves of Fields With Oil/Water Transition Zones." SPE Reservoir Evaluation & Engineering 5, no. 04 (August 1, 2002): 311–16. http://dx.doi.org/10.2118/79210-pa.

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31

Kharisov, Mansur N., Eleonora A. Yunusova, Elvira A. Kharisova, and Ravil A. Maiski. "ANALYSIS OF DISPLACEMENT CHARACTERISTICS OF OIL WELLS AND OIL FIELDS." Problems of Gathering, Treatment and Transportation of Oil and Oil Products, no. 4 (December 2017): 73. http://dx.doi.org/10.17122/ntj-oil-2017-4-73-83.

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32

Sarancha, A. V., and S. Yu Mikhaylov. "Success probability of oil production on KhMAD-Yugra oil fields." IOP Conference Series: Earth and Environmental Science 194, no. 8 (November 15, 2018): 082035. http://dx.doi.org/10.1088/1755-1315/194/8/082035.

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33

Wang, Jing, Jun Yin, Lei Ge, Jiahui Shao, and Jianzhong Zheng. "Characterization of Oil Sludges from Two Oil Fields in China." Energy & Fuels 24, no. 2 (February 18, 2010): 973–78. http://dx.doi.org/10.1021/ef900925a.

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34

Egorova, G. I., N. I. Loseva, and A. N. Egorov. "Comparative analysis of oil properties from Western Siberia oil fields." IOP Conference Series: Earth and Environmental Science 181 (August 16, 2018): 012008. http://dx.doi.org/10.1088/1755-1315/181/1/012008.

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35

Gao, Changhong. "Experiences of microbial enhanced oil recovery in Chinese oil fields." Journal of Petroleum Science and Engineering 166 (July 2018): 55–62. http://dx.doi.org/10.1016/j.petrol.2018.03.037.

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36

Beliveau, Dennis. "Waterflooding Viscous Oil Reservoirs." SPE Reservoir Evaluation & Engineering 12, no. 05 (October 27, 2009): 689–701. http://dx.doi.org/10.2118/113132-pa.

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Summary In 2004, the large Mangala, Aishwariya, and Bhagyam oil-fields were discovered in the remote Barmer basin of Rajasthan, India. The fields contain light, paraffinic crude oils with wax-appearance temperatures only 5°C less than reservoir temperatures and in situ viscosities that range from 8 to 250 cp. As these were the first significant hydrocarbon discoveries in this part of India, there were few analog performance data available. Development plans for the fields are based on hot waterflooding to prevent problems with in-situ wax deposition, with production startup expected in 2009. This article presents some waterflood results from viscous-oil fields around the world, benchmarks the expected performance of the newly discovered Rajasthan fields to this database, and discusses several issues associated with waterflooding viscous oils. Given that the Rajasthan oils have some properties that might be considered "unusual" and potentially troublesome for waterflooding and that there are no long-term production data or a history match of waterflood performance in hand, these benchmarks were considered important reality checks. In fact, fields with similar or much higher viscosities are waterflooded routinely with excellent recoveries in Canada, the USA, and elsewhere. Introduction Waterflooding is sometimes dismissed as an ineffective process for a viscous-oil field, with development plans focused on more-exotic and -expensive recovery mechanisms such as chemical or thermal processes. However, basic application of Darcy's law and fractional flow theory, combined with operations that focus on production at very high water cuts, clearly shows that viscous-oil fields can yield reasonably good ultimate recoveries under waterflood.
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37

Gupton, C. L. "Living Mulch for Strawberry Production Fields." HortScience 32, no. 3 (June 1997): 427B—428. http://dx.doi.org/10.21273/hortsci.32.3.427b.

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Annual ryegrass (Lolium multiflorum), which grows prolifically during the strawberry production season in the Gulf South, has the potential to serve as a living mulch if its growth is controlled. Sublethal dosages of Embark, a plant growth regulator, and the herbicides Poast and Rely were determined on ryegrass. Growth retardation was rated from 0 = none to 6 = dead. In 1993, all Poast dosages (1/8X – 1X, where X = 8 ml·L–1) were lethal. Embark regulated ryegrass growth, but its study was discontinued because of the unlikelihood that it could be labeled for use on strawberries. Results of the 1994 study suggested that prime oil in the spray may cause an inordinate amount of vegetative browning. In 1995, three levels of oil (1/256X, 1/64X, and 1/32X, where X = 8 ml·L–1) were used with each of four levels of Poast (0, 1/32, 1/64, and 1/128X). Increased levels of oil generally caused increased browning at each level of Poast, but no browning occurred where oil only was applied in the spray. In contrast to results in 1995, oil at 1/32X with no Poast caused considerable browning (score = 3.25) in 1996. The most desirable control (score = 2.75) was accomplished by a spray containing 1/128X Poast and 1/64X oil. The most desirable control by Rely (score = 3.25) was accomplished by 1/64 and 1/32X sprays. Rely is not labeled for strawberries although it is labeled for other fruit crops. Chemical names used: 2-[1-(ethoxylmino)buty1]-5-[2-(ethylthio)propy1]-3-hydroxy-2-cyclohexen-1-one (Poast); Paraffin Base Petroleum Oil + polyol Fatty acid Esters (Prime oil); N-[2,4dimethyl-5-[[(trifluoromethyl)-sulfony]amino]phenyl] acetamide (Embark); ammonium-Dl-homoalanin-4-yl-(methyl) phosphinate (Rely).
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38

Nomoto, Shinsuke, and Kazuo Fujita. "A calculation of oil production performance of the large giant oil fields in the world: based upon Oil Fields Depletion Model." Journal of the Japanese Association for Petroleum Technology 62, no. 3 (1997): 247–56. http://dx.doi.org/10.3720/japt.62.247.

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39

Makanov, Rinat, and Ilyas I. Turgazinov. "NUMERICAL STUDY OF THE POLYMER INJECTION ON DISPLACEMENT OF HIGH-VISCOUS OIL FROM CARBONATE FORMATION." Herald of Kazakh-British technical university 18, no. 3 (September 1, 2021): 46–50. http://dx.doi.org/10.55452/1998-6688-2021-18-3-46-50.

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Residual recoverable reserves of high-viscosity and heavy oils in the Republic of Kazakhstan amount to about 340 million tons. The main oil fields containing high-viscosity and heavy oil are Karazhanbas, Kenkiyak, Zhetybai, North Buzachi, Kenbai, etc. Improving the system for the development of high-viscosity oil fields and the selection of rational EOR is relevant for Kazakhstan, as this will increase the efficiency of their development. Given the high resource potential of such fields, it is necessary to develop and introduce new technologies in the development of high-viscous oil fields using enhanced oil recovery methods. To ensure high oil recovery factors, it is necessary to carefully select the EOR applicable to high-viscosity oil fields at an early stage of their development. This work is devoted to the problem of EOR selection in the development of high-viscosity oil fields. For the research polymer injection was selected. Evaluation of the efficiency of the proposed EOR was carried out based on the results of numerical experiments to displace high-viscosity oil with the creation of reservoir conditions. As a result, the aqueous polymer solution with the concentration of 0.05 % yielded 51% of oil recovery, whereas water injection recovered only 10% of oil. However, the interaction of the polymer with high-viscosity oil has not been deeply studied, which is relevant to the fields of Kazakhstan.
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40

Bint, A. N. "DISCOVERY OF THE WANAEA AND COSSACK OIL FIELDS." APPEA Journal 31, no. 1 (1991): 22. http://dx.doi.org/10.1071/aj90003.

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Exploration of the Dampier Sub-basin on the North West Shelf of Australia commenced with a reconnaissance seismic survey in 1965. In 1969 Madeleine-1, the first well drilled on the Madeleine Trend, encountered water bearing Upper Jurassic sandstones. Following acquisition of a regional grid of modern seismic in 1985 and 1986, and comprehensive hydrocarbon habitat studies, the Wanaea and Cossack prospects were matured updip from Madeleine 1. They were proposed to have improved reservoir development and an oil charge.The Wanaea Oil Field was discovered in 1989 when Wanaea-1 encountered a gross oil column of 103 m in the Upper Jurassic Angel Formation. The well flowed 49° API oil at 5856 BPD (931 kL/d) with a gas-oil ratio of 1036 SCF/STB. Two appraisal wells were drilled in the field in 1990.The Cossack Oil Field was discovered in 1990 when Cossack-1 encountered a gross oil column of 54 m also in the Angel Formation. The oil-water contact is 18 m deeper than in Wanaea-1. Cossack-1 flowed 49° API oil at 7200 BPD (1145 kL/d) with a gas-oil ratio of 98 SCF/STB.The Angel Formation reservoir consists of mass flow sandstones interbedded with bioturbated siltstones. Sandstone porosities average 16 to 17 per cent for both the Wanaea and Cossack Fields. Permeabilities average about 300 mD at Wanaea and about 500 mD at Cossack.An extensive 3-D seismic survey was conducted over the Wanaea and Cossack Fields in 1990. Final reserves calculations await interpretation of this survey, but it is clear that the combined Wanaea and Cossack oil reserve is the largest outside Bass Strait.
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41

Kaiser Abdulmajeed, Rwaida. "New Viscosity Correlation for Different Iraqi Oil Fields." Iraqi Journal of Chemical and Petroleum Engineering 15, no. 3 (September 30, 2014): 71–76. http://dx.doi.org/10.31699/ijcpe.2014.3.8.

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Viscosity is one of the most important governing parameters of the fluid flow, either in the porous media or in pipelines. So it is important to use an accurate method to calculate the oil viscosity at various operating conditions. In the literature, several empirical correlations have been proposed for predicting crude oil viscosity. However, these correlations are limited to predict the oil viscosity at specified conditions. In the present work, an extensive experimental data of oil viscosities collected from different samples of Iraqi oil reservoirs was applied to develop a new correlation to calculate the oil viscosity at various operating conditions either for dead, saturated or under saturated reservoir. Validity and accuracy of the new correlation was confirmed by comparing the obtained results of this correlation and other ones, with experimental data for Iraqi oil samples. It was observed that the new correlation gave the most accurate agreement with the experimental data.
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42

Mikhailov, V. G., M. G. Volkov, and R. S. Khalfin. "MODELING OF CRUDE OIL COMPONENT COMPOSITION FOR WESTERN SIBERIA OIL FIELDS." Petroleum Engineering 15, no. 4 (December 2017): 98. http://dx.doi.org/10.17122/ngdelo-2017-4-98-104.

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43

Sabyrgaliev, N., N. Gabdenov, and A. Koshіm. "Geodetic support mapping oil fields (Fon example the Tengiz oil field)." Journal of Geography and Environmental Management 42, no. 1 (2016): 228–34. http://dx.doi.org/10.26577/jgem.2016.1.305.

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44

Lasdon, Leon, Shawn Shirzadi, and Eric Ziegel. "Implementing CRM models for improved oil recovery in large oil fields." Optimization and Engineering 18, no. 1 (February 9, 2017): 87–103. http://dx.doi.org/10.1007/s11081-017-9351-8.

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45

Fozekosh, D. I. "New Developments in the Sphere of Oil Treatment at Oil Fields." Chemical and Petroleum Engineering 39, no. 11/12 (November 2003): 687–89. http://dx.doi.org/10.1023/b:cape.0000017608.11109.36.

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46

Al-Obaidi, S. H., M. Hofmann, and F. H. Khalaf. "ENHANCED OIL RECOVERY IN TERRIGENOUS OIL FIELDS USING LOW-SALT WATER." Natural Science and Advanced Technology Education 32, no. 2 (July 1, 2023): 107–24. http://dx.doi.org/10.53656/nat2023-2.01.

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In order to improve the development of reserves, optimal technologies must be introduced to meet the regular increase in demand for hydrocarbons. Injection of low-salinity water is one of these technologies that have been shown to be effective in solving this problem. Accordingly, low-salt water is investigated as a potential method to increase terrigenous oil recovery. Based on modelling the flooding of solutions with different salinities, the effect of salt concentration on oil displacement efficiency during re-injection was assessed. Salinity reduction efficiency was examined by comparing oil recovery after flooding with high salinity water. Due to active interactions at the oil-water interface, including an increase in viscoelasticity, the oil recovery factor increased with a decrease in salinity. Oil recovery increased by 1.3 – 2% as water salinity decreased.
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47

Koning, Tako. "Giant and major-size oil and gas fields worldwide in basement reservoirs: state-of-the-art and future prospects." Georesursy, Special issue (August 31, 2020): 40–48. http://dx.doi.org/10.18599/grs.2020.si.40-48.

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Oil and gas occurs in basement reservoirs in many parts of the world. The reserves of basement fields are as small as one or two million barrels of oil or gas-equivalent such as the Beruk Northeast pool in Sumatra, Indonesia to over 1.0 billion barrels of oil as in Viet Nam’s Bach Ho field and Libya’s Augila-Naafora field. This paper focuses on three giant-size oil and gas fields and six major-size fields. Exploration for oil and gas in basement has been remarkably successful in the past decade with important discoveries in basement in Indonesia, United Kingdom, Norway, Chad, and Argentina. In order to successfully develop basement oil and gas fields and also to avoid costly mistakes, all available geological, geophysical, reservoir engineering and economic data must be closely studied. Also, it is very important to study analogues worldwide of basement oil and gas fields in order to understand why some fields are very successful and others turn out to be technical and economic failures.
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Yussupova, L. Y., and A. B. Kalmagambet. "INNOVATIVE DEVELOPMENT OF TECHNOLOGY FOR THE DEVELOPMENT OF OIL FIELDS IN KAZAKHSTAN." ТЕХНИКА ҒЫЛЫМДАРЫ ЖӘНЕ ТЕХНОЛОГИЯ 2, no. 2 (2023): 41–48. http://dx.doi.org/10.52081/tst.2023.v02.i2.015.

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This article discusses the issues of innovative development of the oil and gas industry in Kazakhstan. The features characteristic of the oil and gas industry are revealed. Methods of increasing oil recovery through project documents reviewed and controlled by state structures of subsurface users in the new conditions of subsurface use and with the preservation of state ownership of minerals in the subsurface, further development of innovations in the field of oil field development with an increase in the scientific and technical level of the feasibility of cost-effective application of methods of improving oil recovery (MUN), increasing the efficiency of modern communications involving planning and designing of advanced methodologies, less costly and more efficient technologies, the conditions of the oil recovery coefficient, oil fields are described. The ways of stimulating oil companies to innovate through state mechanisms of influence on the industry are proposed.
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49

Khabibullaev, S., J. Tangirov, N. Amirkulov, and T. Daminov. "Metrological supply of water pumping in oil and gas fields." E3S Web of Conferences 371 (2023): 01024. http://dx.doi.org/10.1051/e3sconf/202337101024.

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In the article, the instructions for the Metrological provision of survey driving in oil and gas fields and the Metrological provision carried out in oil fields,instruments used in the fields and the principle of their operation, the analysis of the main problems of the Metrological calculation of the quantity and quality of oil and oil products, the Prohibition of modern means of Water treatment for oil and gas folding, methods of water treatment for oil and gas folding, water treatment for oil and gas folding (pile), modern methods of exposure to piles aimed at increasing the ultimate oil permeability, standards for thermometers, pressure meters, flow meters, moisture meters, density meters and resistivity meters used in oil and gas fields, well consumption meters АPU-011/630 terms of reference, SIEMENS SITRANS F M MAG 5000/6000 eletromagnetni digital consumption meter test result, the results from the SKJ30М10.00.010PS consumption gauges, which were struck in wells, were highlighted.
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Janakiraman, S. "DIGITAL OIL FIELDS - INTELLIGENT WELLS AND PLATFORMS." Petroleum Engineering 16, no. 5 (December 2018): 24. http://dx.doi.org/10.17122/ngdelo-2018-5-24-29.

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