Schedule Session Details Expand All Collapse All Filter By Date All Dates Sunday, December 09 Monday, December 10 Tuesday, December 11 Wednesday, December 12 Filter By Session Type All Sessions General Activities Social and Networking Events Technical Sessions Panel, Plenary, and Special Sessions Energy4Me Training Course/Seminar Sunday, December 09 07:00 - 15:00 Field Trip: An Integrated Approach to Geologic Outcrops for Boosting Reservoir Understanding Jal Az Zor Escarpment, North of Kuwait City Ticketed Event Field Trip Jal Az Zor Integrated Field Course An Integrated Approach to Geologic Outcrops for boosting Reservoir Understanding When: 9 December 2018 Where: Jal Az Zor Escarpment, north of Kuwait City Organizers: KOC, with KOC and Shell SMEs The field trip will provide an integrated approach to geologic outcrops, using Jal Az Zor examples, that will trigger reflections in the participants about the implications of heterogeneities, scale, and 3D distribution of rock properties to models, studies, activities, and insights pertinent to reservoir analysis. The field course is specifically designed to relate the geology to a variety of subsurface disciplines involved in heavy oil development. Topics addressed will include baffles, reservoir modelling, steam conformance, cap rock integrity, well spacing, integration of well, reservoir, and facilities management (WRFM), and observation wells placement. The ultimate goals are to gain an appreciation for the value that the understanding of vital elements of rock description and sedimentology have for reservoir studies, and for the enhancement of production strategies. Group discussion will be encouraged to share knowledge and trigger new perspectives.
Bao, Yu (Research Institute of Petroleum Exploration & Development, CNPC) | He, Liangchen (Liaohe Oilfield Company Ltd, Petrochina) | Lv, Xue (Sino-Pipeline International Company Ltd.) | Shen, Yang (Research Institute of Petroleum Exploration & Development, CNPC) | Li, Xingmin (Research Institute of Petroleum Exploration & Development, CNPC) | Liu, Zhangcong (Research Institute of Petroleum Exploration & Development, CNPC) | Yang, Zhaopeng (Research Institute of Petroleum Exploration & Development, CNPC)
The Orinoco heavy oil belt in Venezuela is one of the largest extra-heavy oil resources in the world. It has become a major goal for the unconventional oil exploitation in these years. Now, the most common production method is to use the horizontal well cold production without sand. It is an economic and commercial process, and with the reservoir of this area have high initial gas to oil ratio (GOR), porosity and permeability with unconsolidated sand. However, after several years' production, the oil rate draws down quickly caused by the reservoir pressure drops; the key challenge of cold production is that the recovery factor (RF) tends to be only between 8% and 12%, implying that the majority of the oil remains in the oil formation. It is necessary to develop viable recovery processes as a follow-up process for cold production. Generally, steam based recovery method was widely used as a follow-up process for cold production. In this paper, steam fracturing (dilation) Cyclic Steam Stimulation (CSS) operation and Non steam fracturing (No dilation) CSS operation by using reservoir simulator is examined for a post cold production in extra heavy oil reservoir, in order to analyze the performance of the oil rate, cumulative steam-to-oil ratio (cSOR), steam depletion zone, greenhouse gas emission and some necessary parameters.
The key component of the steam fracturing (dilation) is the ability to inject high temperature and pressure steam into the formation to fracture the reservoir rock which in turn raises the rock permeability and mobilized the oil by lowering the visocisity. To compare the results of the dilation and no dilation CSS operation, this study reveal that due to the steam is injected into the reservoir by using the same cumulative cold water equivalent (CWE), the steam condensate; pressurized by steam vapour, fracture the formation. Dilation operation achieves higher oil rate, lower cSOR. The result also show that fraturing (dilation) of the reservoir during steam injection relieves the pressure which in turn lowers the steam injection pressure below the case where No dilation operation ouccurs.
More than four billion barrels of heavy oil remain in the oil fields of Trinidad. If these oil fields are exploited, the country's total oil production can increase significantly. However, heavy oil is difficult to produce, due to its high viscosity, and only a small fraction is recovered after primary recovery. Therefore, it is necessary to implement enhanced oil recovery (EOR) techniques to increase heavy oil production. Two of the most commonly used EOR techniques are cyclic steam stimulation (CSS) and cyclic CO2 stimulation (CCO2S). These processes have a long history of successful heavy oil recovery in Trinidad and Tobago when applied individually. However, very little research was found regarding the combination of both processes which was the basis for this study
A test reservoir, located in the southern basin on land Trinidad was selected and a computer simulation model was built, using the Computer Modelling Group (CMG) software to determine the production analysis. Sand, structure and pay maps were obtained and digitized, using the Didger Five software and then uploaded into the CMG software. Reservoir properties and production data were also uploaded. Wells were then added to the model at the exact location indicated on the structure map. Simulations were conducted using varying injection rates, slug size and soak times for CSS, CCO2S and combined CSS and CCO2S to determine optimal EOR performance and production.
The combination of CSS and CCO2S show an increase in recovery by 8.6% and to be profitable at oil prices higher than USD 14/bbl. It is also best used as a first step for other enhanced oil recovery techniques to further increase recovery. In addition, the results show that 8 out of 17 wells were more responsive to CSS and CCO2S when applied individually than when combined.
Jin, Fu (CNPC Engineering Technology R&D Company Ltd.) | Shunyuan, Zhang (CNPC Engineering Technology R&D Company Ltd.) | Bingshan, Liu (CNPC Engineering Technology R&D Company Ltd.) | Bo, Li (CNPC Engineering Technology R&D Company Ltd.) | Lisheng, Chen (Baoding Second Chemical Engineering Factory)
As a kind of methodology to develop coalbed methane in China, RMRS (Rotating Magnet Ranging System) has been popular in SAGD operation in recent years. In Liaohe Oilfield SAGD (Steam Assisted Gravity Drainage) is becoming a more and more mature methodology. In a pair of parallel wells high pressure steam is injected into a horizontal well to drain heavy oil into the lower production well. However, not all thermal resources have not been exploited, such as heat of the hot production fluid, flue gas and hot brine separated by the steam-water separator in the boiler.
Trials and researches were finalized on many dual-horizontal wells in Liaohe Oilfield to learn about the present situation and technical capabilities, while thermodynamic models of various types were established and experimental means were applied to analyze thermal distribution and each of the thermal sources previously mentioned. Effects of various media, flow rates and temperatures on thermal utilization and heat deficit rates were studied on the assumption that one ton crude oil was produced per hour.
Waste heat of flue gas may be utilized to help combust air and the thermo-coil may be used as the air preheater, which improves boiler’s heat efficiency. The high temperature production fluid may be used to heat water in the boiler first and then used as the heat source of the absorption heat pump, so that heat is transferred from the low temperature heat source to the high temperature heat source and the low grade heat energy is recycled. As a high grade waste heat, the HPHT brine that is separated from moist steam in the boiler takes up twenty percent of the total water and shall not be only used to heat injected water. Instead, it may be used to achieve flash evaporation. Thus, waste water is heated and distilled water is recycled.
The waste heat recyling model applies thermo-coil air preheaters to recycle flue gas and flash evaporated hot brine to evaporate waste water. Beside, hot production fluid is recycled to heat boiler water. On a basis of the same fuel consumption volume, the recovery rate and marketability of crude oil are both improved.
Sun, Renyuan (China University of Petroleum) | Sun, Ying (China University of Petroleum) | Fan, Kunkun (China University of Petroleum) | Yang, Shikai (China University of Petroleum) | Qiao, Mingquan (Xinjiang Xinchun Petroleum Development Company) | Wang, Xuezhong (Xinjiang Xinchun Petroleum Development Company) | Yang, Yuanliang (Xinjiang Xinchun Petroleum Development Company)
In order to develop the super-heavy oil reservoir with thin layer, low reservoir temperature and shallow depth in CF oilfield of China, a new technology of HDNS (Horizontal well, viscosity Depressant, Nitrogen and Steam) was proposed and a series of experiments were conducted and the factors effecting oil recovery factor were analyzed. The self-designed equipment, which includes the steam generation system, gas injection system, chemical injection system, the sand-parking sample system, the temperature-controlled system, the metering system of produced fluids and the data collecting system, was used for the experimental studies. Experiments shows that the displacement efficiency increases with the increase of the steam temperature and the injection rate of steam, but too high steam injection rate will decrease the displacement efficiency because of Steam channeling. Compared with steam huff and puff, the displacement efficiency of viscosity depressant assisted steam (DS) increases about 20% because of the thermal chemical effect. The viscosity depressant, N2 assisted steam huff and puff (DNS) can increase the displacement efficiency in about 18% by using the synergistic effects of viscosity depressant, N2 and steam. In the process of DNS stimulation, the viscosity depressant can reduce the viscosity of super heavy oil combined with the effect of steam, which is called as thermal chemical effect. The N2 can prevent the steam chanelling in the reservoir and decrease the heat loss in the process of steam stimulation. The DNS stimulation can effectively reduce the oil viscosity and the steam injection pressure, expand the steam sweep efficiency. By using this technology, Block X of CF oilfield has been successfully developed in these years.
Zhang, R. X. (China University of Petroleum) | Hou, B. (China University of Petroleum) | Zhang, Q. Y. (Liaohe Oilfield Construction Engineering Company) | Zhou, X. W. (Changqing Oilfield Company No.5 Oil Production Plant) | Shan, Q. L. (China University of Petroleum) | Liu, X. (China University of Petroleum)
ABSTRACT: Six true tri-axial laboratory experiments were conducted to investigate fracture propagation behavior in tight formation. Meanwhile, the effects of perforation parameters on fracture initiation and propagation under different horizontal stress differences were discussed. The experimental results showed that: induced fractures would like to initiate at the base of perforation, and then propagate along the maximum horizontal stress direction. Main fracture morphologies were divided roughly into three different types in our experiments: a single flat fracture, multiple-parallel fracture, and spiral-shape fracture. Moreover, high perforation density preferred to create spiral-shape fracture, and large perforation phase was keen on generating multiple-parallel fracture. In addition, a high horizontal stress difference prevented induced fractures from interacting and linking up with each other, resulting in obvious complex fractures near wellbore. However, it reduced fracturing pressure and the roughness of fracture surface effectively. Ultimately, low perforation density, 12 holes/m, with perforation phase of 60° should be used in a low horizontal stress difference for a simple flat fracture. However, high perforation density as 18 holes/m with perforation phase of 60° should be adopted in a high horizontal stress difference for a low fracturing pressure.
More and more tight formations, rich in Sichuan basin of China, were stimulated by hydraulic fracturing to obtain a high production rate because of its special rock properties, such as high density, low permeability, and low porosity (Hou et al., 2017). This technology, however, faced lots of challenges when was applied in a casing perforated wellbore. High friction near wellbore, large operation pressure, and premature screen-out were observed in the perforated fracturing (Aud et al., 1994; Cleary et al., 1993; Davidson et al., 1993), resulting in a low production. Abass et al. (1994) affirmed that complex in-situ stress distribution and the casing effect caused that. In addition, Behrmann and Elbel (1991) claimed that the existence of perforations was the cause of the above problems.
The development of offshore heavy oil field need to reduce investment, energy consumption for oil and gas processing and transportation, we should improve the process, in order to simplify the process by using advanced technology, reduce processing facilities, improve equipment utilization, reduce energy consumption. This paper analyzes the current new technology of heavy oil processing in domestic and foreign oil field being used and in the test phase. The heavy oil in Bohai oilfield with viscosity reduction and experimental research, applied to Bohai heavy oil dehydration conveying process, as well as the feasibility and foreground of application in offshore heavy oil processing.
There is large and increasing proportion of heavy oil in oil and gas reserves in China and how to reduce the cost to maximize the heavy oil and super heavy oil production is the biggest problem facing China's petroleum industry. Onshore oil field has been using steam drive as the main development technology. The viscosity of degassed heavy oil at reservoir temperature is 10000 ~ 50,000 mPa. s, and super heavy oil (natural asphalt) more than 50,000 mPa.s. In recent years, China's offshore heavy oil development has been increasing. There have been new heavy oil field/ block put into production. How to reduce investment and increase economic benefits of heavy oil field is the focus of consideration. However, due to high density, high viscosity and poor fluidity it is difficult to achieve economic, safe and stable transportation.
Compared with the onshore oil field heavy oil reserve, the offshore heavy oil field well depth is relatively deeper, and there are more constrains on offshore platform space, equipment deploying, and Capex/Opex. Bohai heavy oil reserve is very large, well is deep, and characteristic viscosity range is wide. The oilfield is located in the Bohai Bay area, oil containing layers are mainly Qianshan, Guantao and Minghuazhen group, and crude oil viscosity range under reservoir conditions is 50 ~ 10,000 mPa - S.
Heavy oil reservoirs embrace 70% of worldwide oil reserves. A lot of challenges face such oil production like its large viscosity which can be reduced under the action of aquathermolysis reaction. Aquathermolysis reaction is the main objective used to analysis and explain the effect of nanoparticles addition on heavy oil. Several thermal recovery techniques have been implemented using different nanometals for recovery improvement of heavy oil reservoirs and viscosity reduction.
These published trials focused on nanometals but none of them addressed usage of Graphene oxide nanoparticles for such improvement of heavy oil recovery, and therefore this paper represents an experimental investigation of graphene oxide effect on heavy oil production. The present work examines graphene oxide nanoparticle in heavy oil viscosity since graphene is a superlative material that has an extraordinary thermal conductivity up to ten times value of any nanometal. In order to check its efficiency for Heavy oil recovery, several published scenarios have been executed on light oil which leads to recovery reaches 12.5 %.
In our work, the concentration used for these nanoparticles is ranging from 0.01: 0.5 wt. %. The viscosity of these nanoparticles with heavy oil sample has been measured to explain the expected improvement in recovery factor. The Experimental work showed a large change in the viscosity after using nano Graphene oxide reached to 40:60% reduction in its original values. In addition to the viscosity, the effect of reservoir temperature is investigated. The range of temperature used in this study varies between 40° to 100° C. These results reflect strong indications for better viscosity reduction. Therefore, better recovery factor for this heavy oil.
Meanwhile, this present research provides an investigation of aquathermolysis reaction for such materials which is the main reason for heavy oil viscosity reduction, also it represents Graphene Oxide as new nanoparticles for improving Heavy Oil Recovery that will create a new era in thermal recovery for heavy oil. Also, an economic study is investigated.