Since the last event held in Thailand in 2014, the industry has altered significantly. Evolving challenges such as oil price volatility, the "big crew change", and digital disruption, require new approaches in applying business models and technologies to achieve cost and operational efficiencies, whilst meeting stakeholders' expectations to preserve the core business and, at the same time, stimulate progress by exploring challenges, successes, and strategies to create a fit-for-purpose set of tools, systems, models, technologies and capabilities that will reshape the industry for a smart and sustainable future. Complete MPD Rigs: Is this the Future? As the petroleum industry recovers from market lows and business recovers, we ask ourselves, what is next? This panel session shall discuss these and other appropriate topics including: - Rig utilisation forecasts - Regions for future growth - Rig types for expansion: Land, shelf, deep or ultra-deep water - Rig retirements, cold vs warm stacking and reactivation - Shipyard activity: Upgrades vs new build construction - New technologies in rig components or service delivery - Data management and work processes -Partnerships between drilling contractors and drilling service providers The industry's needs to position for recovery and forecasting is an integral component in the planning for next phase.
Green fields today mostly can be regarded as marginal fields and successfully developed. It covers the complete assessment of the oil and gas recovery potential from reservoir structure and formation evaluation, oil and gas reserve mapping, their uncertainties and risks management, feasible reservoir fluid depletion approaches, and to the construction of integrated production systems for cost effective development of the green fields. Depth conversion of time interpretations is a basic skill set for interpreters. There is no single methodology that is optimal for all cases. Next, appropriate depth methods will be presented. Depth imaging should be considered an integral component of interpretation. If the results derived from depth imaging are intended to mitigate risk, the interpreter must actively guide the process.
Oil production decline and excessive water production are prevalent in mature fields and unconventional plays, which significantly impact the profitability of the wells and result in costly water treatment and disposal. To seek for a sustainable development of those wells, reducing the operation cost and extending their economic lives, this paper presents a method of synergistic production of hydrocarbon and electricity, which could harvest the unexploited geothermal energy from the produced water and transfer heat to electricity in the wellbore. Such method is cost-effective, since it does not require any surface power plant facility, and it is replicable in numerous wells including both vertical wells and horizontal wells. By simultaneous coproduction of oil and electricity, the value of existing assets could be fully developed, operation cost could be offset, and the economic life of the well could be extended.
This recently proposed method incorporated thermoelectric power generation technology and oil production. In this method, electricity could be produced by thermoelectric generator (TEG) mounted outside of the tubing wall under temperature gradient created by produced fluid and injected fluids. The aim of this paper is to illustrate the economic practicability of oil-electricity coproduction by using thermoelectric technology in oil wells based on previously proposed design. We examined the technical data of high water-cut oil wells in North Dakota and collected required information with respect to performance thermoelectric power generations. Special emphasis was placed on the key parameters related to project economics, such as thermoelectric material, length of TEG and injection rate. Sensitive studies were carried out to characterize the impact of the key parameters on project profits. We showed that by simultaneously production of oil and electricity, $234,480 of additional value could be generated without interfering with oil production.
The proposed method capitalizes on the unexploited value of produced water and generates additional benefits. This study could provide a workflow for oil and gas operators to evaluate an oil-electricity coproduction project and could act as a guidance to perform and commercialize such project to balance parts of the operation cost and extend the life of the existing assets.
Zhang, Yiming (CNPC Huabei Oilfield Company) | Tian, Jianzhang (CNPC Huabei Oilfield Company) | Yang, Dexiang (CNPC Huabei Oilfield Company) | Chen, Shuguang (CNPC Huabei Oilfield Company) | Liu, Xing (CNPC Huabei Oilfield Company) | Hou, Fengxiang (CNPC Huabei Oilfield Company) | Tian, Ran (CNPC Huabei Oilfield Company) | Zhang, Chuanbao (CNPC Huabei Oilfield Company)
The study area is located in the Langgu sag of Northern Jizhong depression, Bohai Bay Basin, East China. In order to achieve exploration breakthrough in deep buried hill, key engineering technologies are developed and used to accurately demonstrate important target identification by recognizing new hydrocarbon accumulation patterns resulting from the analysis of multi-stage structure-controlled trap mechanism and the detailed study of controlling factors over high-quality Ordovician reservoirs based on new high-accuracy 3D seismic data. This study reveals a new evolution mechanism of buried hill controlled by structural superposition, experiencing "the uplift from thrusting in Indo-Chinese to early Yanshan epoch, uplifted block faulting into horsts in middle Yanshan epoch, horsts tilting into belt in Eocene, and belt reversion into trap", and thus puts forward a new mechanism for reservoir forming controlled by a superposition of "dolomite, karsting, and faulting". Three types of reservoir development are identified, including "regional layered pore, local block micropore-fracture, and fracture hole pore layer-block composite", and an accumulation pattern in deep buried hill is constructed, characterized by "efficient hydrocarbon supply from gas-type source rock, predominant migration through fractured surface-nonconformity surface, and stratum- and mass-controlled accumulation", which has guided the 40 years' exploration of Ordovician Yangshuiwu buried hill zone and made a great breakthroughs. Novel relevant exploration technologies have been developed, involving high-accuracy imaging, high-precision well logging identification of hydrocarbon reservoir, ultra-high temperature deep drilling and completion, ultra-high temperature carbonate reservoir stimulation, etc, which solve a worldwide problem that has restricted the exploration of the ultra-high temperature buried hill for many years. These technologies make possible the highest daily production of over 100 m3 oil and 0.5 million m3 gas respectively and sustain a high and stable production for a long term, which guarantee the clean energy supply for Beijing-Tianjin-Hebei region.
Zhu, Qingzhong (PetroChina Huabei Oilfield Company) | Yang, Yanhui (Exploration and Development Research Institute of PetroChina Huabei Oilfield Company) | Chen, Longwei (Exploration and Development Research Institute of PetroChina Huabei Oilfield Company) | Wang, Yuting (Exploration and Development Research Institute of PetroChina Huabei Oilfield Company) | Chen, Biwu (CBM Exploration and Development Division, PetroChina Huabei Oilfield Company) | Liu, Chunli (Exploration and Development Research Institute of PetroChina Huabei Oilfield Company) | Zhang, Chen (Exploration and Development Research Institute of PetroChina Huabei Oilfield Company) | Wang, Xiaoxuan (Exploration and Development Research Institute of PetroChina Huabei Oilfield Company)
In order to solve the problems of poor adaptability of reservoir stimulation technology and low gas production of single well in high-rank coalbed methane (CBM) reservoir, a new concept of "methane-leading" reservoir stimulation technology and the corresponding technology method system are put forward. The concept of "methane-leading" reservoir stimulation technology emphasizes the complexity of the coal reservoir and the energy releasing process in the coalbed methane development. Through targeted artificial stimulation, a multi-stage interconnected fracture network system is built to reduce seepage resistance and finally improve the gas production of single well. The characteristics of coal reservoir and problems of traditional stimulation technology are analyzed in this paper. And the "methane-leading" reservoir stimulation technology focus on the optimization of the "sweet section", the release of injected energy and the expansion of area stimulated by the fracture network. The application results in the CBM field in the south of Qinshui basin, Shanxi Province, China, shows that the gas production of a single vertical well is more than twice that of an old well in the same area, reaching 2500~3000 m3/d and the average gas production per horizontal well is over 10000 m3/d, indicating a good application prospect. The innovation of this paper lies in that a new concept of "methane-leading" reservoir stimulation technology and the corresponding technology method with CBM characteristics are put forward. It provides new ideas and methods for effectively improving the gas production capacity of CBM single well, realizing efficient development of high-rank CBM and promoting the healthy development of CBM industry.
Wang, Xin (Key Laboratory of Reservoir Stimulation, CNPC Fracturing&Acidizing Technical Service Center, RIPED, CNPC) | Zhu, Qingzhong (PetroChina Huabei Oilfield Company) | Zheng, Wei (Key Laboratory of Reservoir Stimulation, CNPC Fracturing&Acidizing Technical Service Center, RIPED, CNPC) | Lu, Haibing (Key Laboratory of Reservoir Stimulation, CNPC Fracturing&Acidizing Technical Service Center, RIPED, CNPC)
China has abundant low-rank coalbed methane resources. The research object is the low rank lignite seams in Jiergalangtu Sag in Erlian Basin. The reservoir has low porosity and low permeability, and it has no natural productivity. The coal seams have a burial depth of 200-600 meters, thickness of 40-60 meters, and Ro of 0.32% to 0.47%. Borrowing the idea of well completion experience for the conventional low rank coal seams in the region, open hole cavity completion techniques were adopted in two wells, obtaining an output of only about 150 m3/d. The conventional active water fracturing was also tested in another well, and the output after fracturing was 200-300 m3/d. The effect of stimulation was very poor, which limited commercial exploitation activities in the region. This paper introduces two techniques to improve the effect of stimulation by improving induced fracture extension and supporting capacity in the coal seams, including the hydraulic blasting & grouting caving fracturing technique and the reverse compound fracturing technique, which were applied in two wells. A constant rate of production after fracturing reached 1,500-2,000m3/d, which was well above the lower limit output of economic exploitation in the region of 600m3/d. Exciting results were obtained. The exploration of these techniques is of great significance for low rank coalbed methane stimulation, which can help us to implement effective fracturing stimulation operation in low rank coal seams to obtain the best production effect.
Sun, Hehui (No.1 Mudlogging Company, BHDC, CNPC) | Lao, Liyun (SWEE school, Cranfield University) | Li, Dengyue (No.1 Mudlogging Company, BHDC, CNPC) | Tao, Qinglong (No.1 Mudlogging Company, BHDC, CNPC) | Ma, Hong (No.1 Mudlogging Company, BHDC, CNPC) | Li, Huaiyu (No.1 Mudlogging Company, BHDC, CNPC) | Song, Changhong (No.1 Mudlogging Company, BHDC, CNPC)
More and more early kick/loss detection (EKLD) devices are being used in drilling operations, whether in the field of onshore or offshore drilling. In the field of deepwater and offshore drilling, high-precision electromagnetic flowmeters and Coriolis flowmeters was used to measure the inlet and outlet flow rates of drilling fluids. Good effect was achieved, but are affected by drilling fluids, space limitation of the wellsite and production costs when in the field of shore drilling, engineers usually use the paddle- flowmeter and ultrasonic liquid level meter to measure the inlet and outlet flow. It exists the problem of low measurement accuracy and prolonged warning time. In order to improve the accuracy of measurement and the accuracy of early warning, the electromagnetic flowmeter has been studied in terms of flow measurement at the outlet of on-shore drilling. The study found that the installation position of the electromagnetic flowmeter in the V-shaped test pipeline is a key factor that determines the accuracy of measurements. The influence of different fluid types on the measurement was studied by fluid dynamics. The fluid model was established using Ansys fluent software, and the boundary conditions were set in conjunction with the relevant parameters of the drilling fluid. It was found that the descending segment of the V-shaped pipeline was suitable in the state of laminar and dispersed flow. It is an appropriate mounting position for the electric flow meter; for the slug flow, the rising section is a suitable installation position. The theoretical conclusion is verified by laboratory simulation and field tests. The results of theoretical research were used to optimize the design of the test pipeline, and the problems of transient large flow passage and solid-phase debris deposition in the field were solved, and good results were achieved. An automatic grouting module was developed based on the accurate measured outlet flow data. The automatic grouting operation is very helpful for the construction process of drilling and triping, improved the safety level of well control, and laid a good foundation for the large-scale application of EKLD devices in the field of shore drilling.
Zhou, Chao (SINOPEC Research Institute of Petroleum Engineering, China University of Petroleum-Beijing) | Zhang, Tongyi (SINOPEC Research Institute of Petroleum Engineering) | Wu, Xiaodong (China University of Petroleum-Beijing) | Zhao, Fei (Engineering Technology Research Institute of Huabei Oilfield Company) | Xiong, Xiaofei (China University of Petroleum-Beijing)
Vortex drainage gas recovery is a new drainage gas recovery technology. However, its operating mechanism has not been figured out. Theoretical analysis of force condition of the liquid film in the wellbore vortex flow field is still lacking, and dynamic analysis method of the liquid film is not established. The objective of the proposed paper is to establish the liquid film dynamic analysis model and calculate the optimal helical angle of the vortex tool. Dynamic analysis of the liquid film in the wellbore vortex flow field is carried out on the basis of the flow pattern and force condition of the liquid film. Expression of each acting force is determined and the force equilibrium equation is obtained. Referring to the annular flow theory, friction coefficient and average thickness of the liquid film are calculated. Through derivation of the vertical resultant force equation of the liquid film, the optimal helical angle of the vortex tool is obtained. Then, vortex tools were designed and deployed in the wellbore of a gas well in field. Field study shows that the relative difference of the optimal helical angle obtained by liquid film dynamic analysis relative to that obtained by numerical simulation is less than 4%. The optimal helical angle calculated by the liquid film dynamic analysis model is reliable and provides guidance for the structure optimization of vortex tools. Optimal helical angle would increase with well depth decreases because of enhancement of fluid-carrying capability of the gas. The liquid film dynamic analysis model can reasonably explain the motion and force condition of the liquid phase in the wellbore vortex flow. Compared with the conventional annular flow field, vortex flow filed includes additional centrifugal force on the liquid film, which may benefit the upward motion of the liquid film. The liquid film dynamic analysis model in the wellbore vortex flow field and the formula for calculating the optimal helical angle of the vortex tool are established for the first time, whose results fill the gap in existing studies and have a guiding significance for optimization design and field application of vortex tools.
Is Surfactant Environmentally Safe for Offshore Use and Discharge? The current presentation date and time shown is a TENTATIVE schedule. The final/confirm presentation schedule will be notified/available in February 2019. Designing Cement Jobs for Success - Get It Right the First Time! Connected Reservoir Regions Map Created From Time-Lapse Pressure Data Shows Similarity to Other Reservoir Quality Maps in a Heterogeneous Carbonate Reservoir. X. Du, Y. Jin, X. Wu, U. of Houston; Y. Liu, X. Wu, O. Awan, J. Roth, K.C. See, N. Tognini, Shell Intl.
By International Petroleum Technology Conference (IPTC) Monday, 25 March 0900-1600 hours Instructors: Olivier Dubrule and Lukas Mosser, Imperial College London Deep Learning (DL) is already bringing game-changing applications to the petroleum industry, and this is certainly the beginning of an enduring trend. Many petroleum engineers and geoscientists are interested to know more about DL but are not sure where to start. This one-day course aims to provide this introduction. The first half of the course presents the formalism of Logistic Regression, Neural Networks and Convolutional Neural Networks and some of their applications. Much of the standard terminology used in DL applications is also presented. In the afternoon, the online environment associated with DL is discussed, from Python libraries to software repositories, including useful websites and big datasets. The last part of the course is spent discussing the most promising subsurface applications of DL.