The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
- Data Science & Engineering Analytics
The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
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Rdwan, M. F. (Ministry of Petroleum & Gas/University of Khartoum) | Elbaloula, H. A. (Petro-Energy E&P Co Ltd) | Erpeng, G.. (China Natl. Petroleum Corp.) | Shahin, A. F. (Sudapet Co Ltd) | Mohammed, H. A. (Sudapet Co Ltd) | Fidial, A.. (SUDAPET)
Abstract Steam flooding is acontinues steam injection heats a large portion of the reservoir while reducing oil viscosity and achieves the most efficient heavy oil recovery. FNE oil field started production since 2009. In 2010 a pilot Cyclic Steam Stimulation (CSS) was implemented and showed double oil production incremental. Then full field Cyclic Steam Stimulation (CSS) was carried out, in September 2015 steam flooding pilot project was started with obvious increament. In this paper, an evaluation and optimization are made for the pilot test project in line with design, implementation, and production performance of the steam flooding pilot test in Fula North East. This paper will present the results from a study that done using advanced thermal software simulator on a sector model that extracted from FNE full field model, pilot area coverage 4 injectors and 9 producers. History matching and optimization was carried out along with perforation interval, steam intensity, steam quality and production rate. Optimum run case was determined among different sensitivity runs. The results show that oil production performance of steam flooding had significant effect on enhancing oil production. Oil rate increased from 715.66 to 1733.8 BOPD and clear water cut dwindled. After the optimization of steam injection parameters and perforation intervals observable increment in production was achieved, oil production rate increased from 966 to 1160 BOPD and clear water cut decreased.
Tang, Xueqing (1Petro Energy Co., Khartoum, Sudan) | Dou, Lirong (1Petro Energy Co., Khartoum, Sudan) | Wang, Ruifeng (2RIPED, PetroChina, Beijing, China) | Gabir, Alsadig Mohmoud (1Petro Energy Co., Khartoum, Sudan) | Musa, Mouiz Hamza (1Petro Energy Co., Khartoum, Sudan)
ABSTRACT Fula field at Block 6, Sudan contains crude of 16.8 to 19 °API with in-situ viscosity of 497 cp in Bentiu formation. It was on production in March, 2004 and has produced 14% of original oil in place. Massive and unconsolidated sandstones inter-bedded with thin (3 to 13 ft) and discontinuous shales possess high horizontal and vertical permeabilities (2 to 9.53 Darcies). Lateral dimensions of shale bodies range from 1,000 to 2,000 ft. To extend oil production life with water-free, initial development strategy was to perforate the upper and more permeable zones (Perforations are 30% of entire zones) to obtain profitable productivity. After fieldwide water breakthrough, based on the studies of bypassed oil distribution, the following innovative deeper re-completions have been applied in high-water-cut wells (water cut more than 80%) to exploit the bypassed oil zones and new pay zones that have been missed below the existing productive zones. squeeze cement into the existing high-water-cut zones, located at the upper portion of entire pay zones. Those long wormholes communicating with aquifer caused by deep sanding should be cemented. perforate partially the lower portion of pay zones with optimal shot density. 30 to 40% of entire pay zones and shot density of 5 shots per foot are recommended. Perforation tunnel optimization can be run for concrete well conditions. Progressing Cavity Pumps operate at low frequencies less than 30 Hz to regulate proper pressure drawdown less than observed critical value of sanding from field tests and water coning. Field production data indicate that this workover campaign has achieved more than 2-fold oil gain and reducing water cut by 30 to 50% compared to previous water cuts of over 80%, also, water cut plus dynamic fluid level remain relatively stable over 6 months.
Wu, Yongbin (RIPED, Petrochina Company Limited) | Li, Xiuluan (RIPED, Petrochina Company Limited) | Liu, Shangqi (RIPED, Petrochina Company Limited) | Ma, Desheng (RIPED, Petrochina Company Limited) | Jiang, Youwei (RIPED, Petrochina Company Limited)
Abstract Thermal recovery technology particularly cyclic steam stimulation (CSS) is always an effective means to develop the conventional heavy oil reservoirs, which can be validated from literature. While most of the heavy oil reservoirs developed by CSS are the thick, well-deposited, high quality reservoirs and there are no much reports of producing oil from mid-depth oil reservoirs with large acquifers. In this paper, according to the petrophysical properties and geologic characteristics of the target block F in Greater Fuld oilfield in Sudan, based on the oil test results, detailed 3D geologic model is established and the type well model for CSS and SF is extracted, to study the real performance with the real geological properties. The development zone, the perforation strategies, the cylic steam injection quantity, the steam injection rate, soak time, and cyclic period are optimized for CSS. Based on the production performance of CSS, the optimal cycles of CSS followed by SF is determined. And the wellpattern and well spacing, the parameters of SF such as unit steam injection rate, steam quality, effects of bottom acquifer on the SF are also simulated and optimized. The simulation results indicate that the thermal recovery technique especially 4 cycles of CSS followed by SF can acquire satisfied performance, which shows an effective and economic future in the development of the heavy oil deposits in Greater Fula Oilfield.
Abstract Fula is a heavy oil field located in Muglad basin in Sudan. Aradeiba reservoir in the field consists of highly heterogeneous sandstone that is thinly bedded, unconsolidated, bearing typical heavy oil. Bentiu reservoir is composed of massive sandstone, unconsolidated and traped very high viscous oil. Production performance of vertical wells indicates that the reservoirs are facing problems of low productivity, bottom water conning and sand production. In his circumstance CNPCIS set itself a daunting task of tripling the production in less than a year. Horizontal wells were considered as best option for improving the productivity in this small to medium sized heavy oil field, and controlling the sand production due to low drawdown pressure and increased exposure the reservoir. This paper discusses about comprehensive geological study , identification of target oil pools, well design, selection of fit for purpose technologies and the complete well placement cycle including detailed analysis on the drilling and steering challenges while placing horizontal well through reactive shales and channel sand environment. The paper also discusses about various completion strategies , the results of well placement, value of using new technology , lessons learnt and cost /production analysis. Team work, communication, knowledge sharing and deployment of fit for purpose technologies has resulted in a five fold increase in production through horizontal wells compared to vertical wells with no sand production. The paper illustrates how integration of different disciplines led to successful well placement, enhanced production with sand and water management in heavy oil environment. Introduction Fula Oilfield is located on central structutre belt of Fula depression in Muglad Basin which consists 3 main blocks -Fula-1, Fula Central and Fula North. Three reservoirs have been found by the exploratory and appraisal wells in the area. Bentiu formation is the main reservoir in Fula Oilfield with massive lose sand and average viscosity is about 1536.39 cp at 500C. Aradeiba is the second reservoir with stratified unconsolidated paysand and average viscosity around 450 cp at 500C. Bentiu reveroir is prone to sand production and water break through very quickly and Aradeiba reservoir is prone to serious sand production and very low output rate in conventional vertical wells. In order to prevent sand production from both reservoirs, to delay water production from Bentiu formation and increase productivity and enhace the reservoir recovery factor operator decided to drill horizontal wells. Another important driving force behind drilling horizontal wells is to improve the light oil production from Aradeiba reservoir that is crucial for blending and transporting the heavy oil from Bentiu reservoir through the pipeline. Seven horizontals have been drilled, out of which four of them are in Aradeiba formation and three are placed in Bentiu fiormation. The production performances of all the wells are extremely good year to date. Geological Setting and Stratigraphy Being a rift and Cretaceous sedimentary basin, Muglad basin is located south of Republic of Sudan. Tectonics was complicated by faulting and continuous fault movement and several sub-basins formed result in this large numbers of tensional faults. Structures within these depressions show significant variations in age of formation, complexity and size. The result of regional stratigraphy study indicates a major East Africa rift basin appeared and developed in the Late Jurassic to early Cretaceous. Early rift sediments interbedded with coarse rift clastics derived from surrounding uplifted basement source rocks. Several types of continental depositional environment may had existed in different areas including fluvial and lacustrine during the Cretaceous and younger period. Fula Sub-basin is located in north part of Muglad Basin and consists of 5 structure belts namely south step-faulted belt, south depression, central structure belt, north depression and north step-faulted belt. Several oilfields like Moga, Keyi and Jake have been discovered after Fula field in Fula Sub-basin recent years. Located in Central Structure Belt of the sub-basin, Fula is one of the earliest oilfield put into production.
Wang, Xugang (Research Oil Co. VVNP) | Zou, Honglan (Langfang Branch of RIPED) | Li, Guocheng (China National Oil and Gas Exploration and Development Corporation) | Nie, Changmou (China National Oil and Gas Exploration and Development Corporation) | Chen, Jianbin (Shengli oil field,SinaPec)
Abstract Fula oil field is composed of unconsolidated sandstones, buried as deep as 3500ft, with high porosity (31%) and permeability(2 Darcy), producing viscous oil with 19–21°API on the south flank of Muglad Basin. It is well-known that under proper conditions formation flow characteristics can be improved by non-thermal massive sand production and foamy oil behavior, referred to CHOPS. Integrated well completion strategies with CHOPS were used to increase heavy oil production. Limited sand influx provides a means for effective sand control while eliminating the need for conventional sand control processes. The principle of limited sand flux is ‘coarse sands controlled and finer sands produced’, which is using the screen liner to inhibit 0.5mmor larger sands flowing into the wellbore, in addition, the rest smaller solids can be produced to the surface by viscous oil. Experiments were conducted to study the capability of lifting sands by crude oil. It showed that the sand of 0.9mm can be allowed to move up with heavy oil to the surface while 510 mPa.s of viscous oil is lifted in 3 1/2 in tubing. Using progressing cavity pump deliberately initiated sand influx but only 15% solids were controlled to form wormhole to improve permeability of the pay zone. This paper describes initial field test results of the new system that 20 heavy oil wells were equipped with PCP which is helpful for handling sanding effectively. The sand cuts range from 0.1 to 12% by volume. Average oil rate of each well is up to 580bopd from 175bopd before CHOPS. The best well can produce as much as 1200 BOPD. Oil production has reached to 2,450,000 bbl/y with attractive result. Introduction Cold Heavy Oil Production with Sand (CHOPS) is a technology to recovery heavy oil reservoirs by inducing sand production to form wormhole net to increase porosity and permeability of the formation greatly and improve flowability of heavy oil. The recovery mechanism of CHOPS includes: wormhole net formed due to a great deal of sand production, steady foamy oil flow, elastic expansion of reservoir, compressive drive of overlying formation and edge/bottom water providing drive energy, etc. CHOPS is a technology of heavy oil production starting from Canada originally. In the middle 1980's, with the falling of global oil price and widening of price difference between light oil and heavy oil, many heavy oil recovery technologies such as steam process technology were faced with severe challenge economically. In order to reduce oil production cost and increase economic benefit of heavy oil production, Canada put forward CHOPS.[1,2] After over ten years especially recent years of development, this technology especially the technology of heavy oil production with sand has been very mature, and satisfactory economic benefit has been achieved. Daily oil production of single well is generally 210∼350bbl, which is several times even tens of times of production by conventional blowdown. Oil recovery ratio is about 8∼15%, even up to 20% in maximum. Operating cost of crude oil is only 3.0∼4.6 US$/bbl, so oil production cost is far lower than other production methods such as steam stimulation.[3,4] Under present high oil price, favorable economic benefit will be achieved.