PETRONAS FLNG SATU (PFLNG1) is a floating liquefied natural gas facility producing 1.2 million tonnes per annum (mtpa) of LNG, on a facility that is 365m long, and 60m wide, making it among the largest offshore facility ever built. The PFLNG1 project is the first of its kind in the world and is the first deployment of PETRONASâ€™ Floating Liquefied Natural Gas (FLNG) technology, consolidating the traditional offshore to onshore LNG infrastructure into a single facility. This will see a giant floating facility capable of extracting, liquefying and storing LNG at sea, before it is exported to customers around the globe. The FLNG journey has come a long way since 2006, with many technological options explored to monetise and unlock the potential of small and stranded gas fields. Moving an LNG production to an offshore setting poses a demanding set of challenges â€“ as every element of a conventional LNG facility needs to fit into an area roughly one quarter the size in the open seas whilst maintaining safety and increased flexibility to LNG production and delivery. The keynote address describes the breakthrough features of PFLNG1 â€“ the worldâ€™s first floating LNG facility; and the pioneering innovation that it brings to the LNG industry.
Achieving zero harm has been the talk of the industrial sector to reduce harm to as low as possible. The management of health, safety, security and environment (HSSE) should not be stagnant. It is time to rethink and reassess how the industry can prepare, mitigate and respond to stay ahead of emerging technical, regulatory and societal challenges. This session will engage leaders to discuss opportunities and challenges, share experiences and lessons learnt, and on how technology and digitalisation may affect the quality and productivity of the work sites - all of which are critical in shaping the future of HSSE in the region. The current presentation date and time shown is a TENTATIVE schedule.
Zhao, Ruidong (RIPED, CNPC) | Li, Jinya (China University of Petroleum) | Tao, Zhen (RIPED, CNPC) | Liu, Meng (RIPED, CNPC) | Shi, Junfeng (RIPED, CNPC) | Xiong, Chunming (RIPED, CNPC) | Huang, Hongxing (NCCBM) | Sun, Chengyan (Daqing Oilfield Company, CNPC) | Zhang, Yufeng (RIPED, CNPC) | Zhang, Xiaowen (RIPED, CNPC)
With the development of many kinds of oilfields, deep well, high deviated well and cluster well are increasing rapidly. Sucker rod pumping still remains a major artificial lift method. There are such problems as severe rod/tubing wearing and shortened rod/tubing life in high deviated rod-pumped wells, and the mechanism and prevention of rod/tubing wearing have not been understood properly.
In order to understand the mechanism of rod/tubing wearing, a lateral load calculation model of rod/tubing is solved in this paper. The calculation results show that both the magnitude and direction of lateral force change dynamically with time and space in one stroke cycle. To better describe the rod/tubing wearing phenomenon, the lateral load is divided into two parts: the primary normal vector related to wellbore trajectory and axial force, and the secondary normal vector only related to wellbore trajectory and invariant with time.
The three-dimensional and dynamic nature of lateral force can account for the rod/tubing wearing partially. The results of mathematical model show that the magnitude of lateral force at the same depth may differ greatly at different times, and its direction may also change periodically. It is likely to be bidirectional rod/tubing wearing when the primary normal force direction changes periodically. Simulation results show that the direction of lateral force is very likely to change periodically below the neutral point of rod string. This finding has accounted for the common double-faced and multi-faced rod/tubing wearing on the lower rod string. The periodic change of lateral force direction will cause rod/tubing collision, which is also an important cause for the rod/tubing wear below the neutral point. It is assumed qualitatively that the production parameters such as pump depth, stroke, stroke frequency and pump diameter are the major factors of the rod/tubing wearing according to field experience. In this paper, mathematic model is used to analyze the impact of these parameters on lateral force and the quantitative analysis is also conducted which provide theoretical foundation for the design of anti-wear production parameters.
The mathematic model and method proposed in this paper are favorable to better accounting for the important phenomenon of rod/tubing wearing in rod-pumped deviated wells. They are capable of the quantitative calculation of lateral forces under different parameter conditions and the anti-wear design. This model has been applied to hundreds of highly deviated wells at Jidong Oilfield, prolonging rod/tubing life 58 days in average.
Zhu, Daoyi (China University of Petroleum, Beijing) | Hou, Jirui (China University of Petroleum, Beijing) | Wei, Qi (China University of Petroleum, Beijing) | Chen, Yuguang (China University of Petroleum, Beijing)
The PG Reservoir in Jidong Oil Field is at a depth of approximately 4500 m with an extremely high temperature of approximately 150°C. The average water cut has reached nearly 80%, but the oil recovery is less than 10% after only 2 years of waterflooding process. It is of great importance to develop a high-temperature-resistant plugging system to improve the reservoir conformance and control water production. An in-situ polymer-gel system formed by the terpolymer and a new crosslinker system was developed, and its properties were systematically studied under the condition of extremely high temperature (150°C). Suitable gelation time and favorable gel strength were obtained by adjusting the concentration of the terpolymer (0.4 to 1.0%) and the crosslinker system (0.4 to 0.7%). An increase of polymer and crosslinker concentration would decrease the gelation time and increase the gel strength. The gelant could form continuous 3D network structures and thus have an excellent long-term thermal stability. The syneresis of this gel system was minor, even after being heated for 5 months at the temperature of 150°C. The gel system could maintain most of the initial viscosity and viscoelasticity, even after experiencing the mechanical shear or the porous-media shear. Core-flow experiments showed that the gel system could have great potential to improve the conformance in Jidong Oil Field.
Zhu, Daoyi (China University of Petroleum, Beijing) | Hou, Jirui (China University of Petroleum, Beijing) | Chen, Yuguang (China University of Petroleum, Beijing) | Wei, Qi (China University of Petroleum, Beijing) | Zhao, Shuda (Missouri University of Science and Technology) | Bai, Baojun (China University of Petroleum, Beijing, at Karamay and Missouri University of Science and Technology)
A terpolymer-gel system using low toxic polyethylenimine (PEI) as the crosslinker was developed for conformance improvement in high-temperature reservoirs. Suitable gelation time (GT), gel strength, and thermal stability could be obtained by selecting PEI molecular weight and adjusting terpolymer concentrations. With the increase of terpolymer concentration, GT decreases and the gel strength increases. However, in this research, the effect of PEI concentration on the gelation performance was much less obvious than that of the polymer concentration. Very low concentrations of sodium chloride (NaCl) can slightly shorten the GT. After critical concentrations were reached, the authors determined that the ions will delay the crosslinking reaction. Moreover, the addition of sodium carbonate (Na2CO3) can also lengthen GT. The gel systems were able to maintain thermal stability at 150°C. Uniformly distributed 3D network microstructures and the small size of the gel-grid pores made the network structure maintain thermal stability. The use of the terpolymergel-system gelation mechanism crosslinked by PEI can help petroleum engineers better understand and apply this terpolymer-gel system.
The development of a new low-carbon operation mode of artificial lift in high-water-cut oilfields, is significant for reducing energy consumption, improving operation efficiency and lowering production costs of oilfields. The annual electric consumption of the oilfield is increasing year by year. In 2016, the total electric consumption exceeded 35 billion kWh, of which the mechanical production system accounts for 57%.
The rodless artificial lift eliminates the use of the sucker rod, and reduces the installed motor power over 50%. The electric consumption is greatly decreased, while tremendous gain is seen in the system efficiency. Moreover, the application performance is especially good for low-production wells. Under such circumstances, the operation cost of the oilfield declines. The current rodless artificial lift is basically based on two types of pumps, namely submersible plunger pump and submersible direct-drive screw pump.
The submersible plunger pump lifts liquid via vertical reciprocation of the moving body driven by the motor, with daily electric consumption of an individual well decreasing by 46%, from 133.4 kWh to 72.5 kWh. The reduced annual electric cost per well is RMB 14,000, and the annual single-well carbon emission falls by 17.5 tons. As for the submersible direct-drive screw pump, the rotation of the pump is directly motivated by the downhole submersible motor, through which the downhole liquid is elevated to the surface. The daily electric consumption of an individual well decreases by 38.4%, from 224kWh to 138kWh, contributing to the annual electric cost reduction per well of RMB 13,600 and annual carbon emission decline per well of 17.1 tons.
The application of the two types of rodless artificial lift has taken initial shape. The submersible plunger pump has been applied to over 200 wells, and the submersible direct-drive screw pump, over 60 wells. The new low-carbon operation mode of artificial lift is critical for the energy saving, efficiency improvement and consequent cost reduction of oilfields, particularly in cases of the industry downturn triggered by low oil prices.
Accurate calculation of reservoir porosity is the key to geological interpretation and petroleum exploration decision. Porosity is influenced by various geological factors such as buried depth, tectonic position, sedimentary environment, lithologic change and diagenesis. How to make full use of multi logging information for comprehensive analysis and calculate the porosity is of great significance for reducing the risk of oil and gas exploration and development. From the point of view of petrophysics, reservoir porosity and logging data are typical nonlinear relations. Deep learning technology can automatically extract high-dimensional nonlinear features from data, then solve complex nonlinear problems through feature transformation. We propose a method for porosity prediction based on deep learning technology, the nonlinear relationship between multiple logging parameters and porosity is established with compensated neutron, acoustic time difference, natural gamma and compensation density well logs. The application results in real data indicate the effectiveness and practicability of porosity prediction using deep learning technology.
Presentation Date: Wednesday, October 17, 2018
Start Time: 9:20:00 AM
Location: Poster Station 9
Presentation Type: Poster
Yuan, Meng (The Unconventional Natural Gas Institute, China University of Petroleum-Beijing) | Huang, Handong (The Unconventional Natural Gas Institute, China University of Petroleum-Beijing) | Bian, Caiyun (Academy of Chinese Energy Strategy, China University of Petroleum-Beijing)
With the development of the hydrocarbon reservoirs exploration in China, structural reservoir has become unable to meet the needs of oil and gas exploration. Thus, lithologic reservoir becomes the focus of current oil and gas exploration. There are lithologic reservoirs characterized by deposition of narrow channel sand bodies in the middle-shallow formation of Matouying Uplift in the Bohai Bay Basin, China. Seismic data in this area is of good quality but the oil layer is thin, averaging less than 10m. Firstly, we conducted an experiment using seismicfacies-inversion method in a physical model of thin-bed channel sandstone. The inversion resolution is high, so we could identify thin sand bodies and characterize the distribution of channel. Then we also use this method to predicted the thin reservoirs in the Matouying area and successfully portrayed the narrow channel. In order to measure the accuracy of our method in this study area, we chose to compare conventional logging constrained inversion with seismic-facies-control inversion. The results show that our method overcomes the problem of low resolution, and we can precisely describe approximately 5m thick reservoir.
Presentation Date: Wednesday, October 17, 2018
Start Time: 1:50:00 PM
Location: 209A (Anaheim Convention Center)
Presentation Type: Oral
Haitao, Li (School of Geosciences, China University of Petroleum–East China) | Shaogui, Deng (School of Geosciences, China University of Petroleum–East China) | Xiyong, Yuan (School of Geosciences, China University of Petroleum–East China)
A physical simulation experiment is established by downscaled azimuthal resistivity logging tool. Typical azimuthal resistivity logging responses of the cavernous formation are conducted based on the similar feature between the experimental model and the physical prototype. Influential factors such as the cave size, infilling materials and caves position are investigated to recognize the azimuthal resistivity log responses, aiming at discrimination and evaluation of the cavernous formation. The results show that the degree of opening of the azimuthal resistivity curve is positively correlated with the size of the caver model; the greater the contrast between the resistivity of the cave and the bedrock, or the closer the cave is to the wellbore, the greater the difference in the amplitude of the azimuthal resistivity curve.
Presentation Date: Tuesday, October 16, 2018
Start Time: 1:50:00 PM
Location: 212A (Anaheim Convention Center)
Presentation Type: Oral
Chen, Yuanzhong (University of Electronic and Technology of China) | Hu, Guangmin (University of Electronic and Technology of China) | Cai, Hanpeng (University of Electronic and Technology of China) | Wu, Junjun (BGP Inc., CNPC) | Li, Yanpeng (BGP Inc., CNPC) | Yu, Gang (BGP Inc., CNPC) | Li, Fei (BGP Inc., CNPC)
In order to adapt to the characteristics of shallow shale gas exploration and development in southwest China and to overcome the difficulties of low coverage and difficult imaging of shallow target layers of 3D surface seismic, a 3D surface and 3D-VSP synchronous acquisition was implemented in Z oil field, and DAS (Distribute Acoustic Sensor) technique was applied in the 3D-VSP. This paper takes Z Oilfield 3D DAS-VSP project as an example to introduce the data quality of DAS acquisition, and the signal to noise ratio (SNR) improvement technique in DAS data processing. The difference between common fibers and armored fibers has been focused on to discuss the possibility of DAS system’s industrialization.