Jidong Oilfield Company
Jidong Oilfield Company
Guo X.,Dagang Oilfield Company |
Qiang H.,Dagang Oilfield Company |
Weng B.,Dagang Oilfield Company |
Qin X.,4th Oil Recovery Plant in Dagang Oilfield |
Wang G.,Jidong Oilfield Company
Well Testing | Year: 2015
With the development of gas reservoir in dagang oilfield, water content gradually increased, and big water rate is much prone to bottom water. In order to improve the effect of gas drainage gas recovery, maximize gas recovery factor, vortex drainage gas recovery technology is developed. It uses the wire to lower down one or more downhole vortex tools without moving parts, changing fluid flow movement way by downhole hydrocyclone tool, increasing the gas with water. The technology has features of low cost for once time of investment, no need for daily management and later into, good abrasion resistance, long used cycle, effective extension of the gas extraction cycles and simple operation. ©, 2015, Well Testing. All right reserved.
Li Q.,Drilling Research Institute |
Tao X.,Jidong Oilfield Company |
Hou W.,Detection Supervision and Evaluation Center |
He Y.,Petrochina |
Well Testing | Year: 2014
Technologies of eccentric separated injection with seal inspection and pressure test to separated layer, can test and acquire pressure drop of the separated nozzle and result of flowing change to eccentric separated layer of injection wells under normal condition of injection status. By analyzing the pressure drop curves from stratified water volume, changes in water absorption capacity of each interval are determined accurately, and that of stratified injection, layered testing is achieved to adjust layer contradictory of the injection wells. Through analysis of situations and existing problems of the cast, fishing, measured and dispensing for eccentric separated injection well, the technology is improved which lets the eccentric dispensing strings to be promoted and applied widely in the oilfield.
Wu Y.,CAS Institute of Electronics |
Wu Y.,University of Chinese Academy of Sciences |
Song H.-J.,CAS Institute of Electronics |
Huang X.-N.,Jidong Oilfield Company
Xitong Fangzhen Xuebao / Journal of System Simulation | Year: 2010
To eliminate the serious coupling between azimuth and range for SAR in large squint mode, an improved RD imaging algorithm based on nonlinear chirp scaling was proposed, which made full use of the characteristic of SAR echo signal in large squint mode, which featured large range walk and small range curvature. First, range walk was corrected. Second, nonlinear chirp scaling operation was adopted to compensate the azimuth-dependent chirp rate. Finally, geometry correction was used to correct geometric distortion. Meanwhile the raw echo signal of the scene and the improved algorithm was simulated. Simulation results illustrate that it efficiently compensates the azimuth-dependent chirp rate, possesses high precision and satisfies the imaging quality of SAR in large squint mode.
Wei F.,Petrochina |
Liu Y.,Petrochina |
Xiong C.,Petrochina |
Liu H.,Petrochina |
And 4 more authors.
Society of Petroleum Engineers - SPE Asia Pacific Oil and Gas Conference and Exhibition, APOGCE 2014 - Changing the Game: Opportunities, Challenges and Solutions | Year: 2014
This paper describes the applications of annular chemical packer (ACP) with highly tailored thixotropic characteristics in horizontal wells completed with slotted liners. The purpose of the applications was to provide a cost effective annular isolation method for water control in horizontal sections. The rheological properties of ACP, the placement techniques of ACP, the subsequent treatment procedures, and the uncertainties involved were provided. The oil rate of the candidate onshore horizontal well M28-P7 was only 0.5m3/d, with 99% water cut. Production logging identified that about 86% of liquid rate was produced from the toe section. The ACP was placed across the shale between the two different liquid-producing zones, and a mechanical plug was dropped at middle of the ACP site. Then effective acidizing was performed for the heel section in order to gain higher permeability. After the treatments, the water cut decreased to 83% while the corresponding oil gain reached up to 5.3m3/d, 20 times that of the pre-treatment scenario. The other similar treatment was performed in offshore horizontal well A2h after production logging. Two ACP plugs were designed and an optimized recompletion string was put into the well. The water control operation went smoothly, which significantly decreased the water cut to 3% from 74% and the oil rate was increased to 187m3/d, with the net oil increased by about 100m3/d over the pre-treatment scenario. This is the first ever successful water control operation with water diagnosis in an offshore well with a tough completion in the South China Sea. Case histories indicate that using ACPs was the right choice for blocking water in the sand screen liner completion with high level technical success and economic feasibility. Also a comprehensive and detailed water control design based on production logging results, completion, and reservoir permeability distribution is the key for successful water shutoff. Copyright 2014, Society of Petroleum Engineers.
Chen P.,Yangtze University |
Wang X.,China University of Petroleum - Beijing |
Liu H.,Jidong Oilfield Company |
Huang Y.,Sinopec |
And 2 more authors.
Geosystem Engineering | Year: 2016
In the development process of fractured-vuggy carbonate reservoir with large-scale caves, the location and size of cave affect the development program. This paper takes the large-scale cave as equipotential body, treats matrix and fracture as double porous media, and establishes the flow model. Laplace transform is used to simplify the model, and then the model is solved using boundary element method. Considering the wellbore storage effect and skin effect, the bottomhole pressure-transient curve is obtained using Stefest numerical inversion method. Comparing the results of analytical solution and boundary element method in the dual porosity medium illustrate the accuracy of this model. The sensitivity of cave parameters is analyzed. It shows that the larger the cave radius is, the stronger the convex and concave of curve is. The convex is earlier and concave is sooner when cave is closer to the well. The segment of convex keeps longer and the concave margin is greater with the larger compressibility ratio. Finally, as an application example, actual test data from a large-scale cave reservoir is analyzed using this model, and the location and size of cave are obtained. It has a certain significance for the reserve evaluation and well test in this reservoir. © 2015 The Korean Society of Mineral and Energy Resources Engineers (KSMER).
Yang X.,Jidong Oilfield Company |
Zhang Z.,Sino Geophysical Co. |
Sun M.,Jidong Oilfield Company |
Shi W.,Jidong Oilfield Company |
Li R.,Sino Geophysical Co.
Oil and Gas Geology | Year: 2014
Temporal-spatial differences of syndepositional tectonics have profound impact on accommodation space, sedimentation rate, types and distributional characteristics of provenance systems of a basin. Episodic tectonic movement of the Nanpu Sag is a major contributor to accommodation space. Several NE-SW-trending contemporaneous faults that were developed in the period of Es in the southern provenance enhanced the compartmentalization of lake basin. A series of echelon growth faults extending toward the basin controlled the distribution of the Shahejie Formation. The linear subsags with the same strike as the growth faults formed in the downthrown blocks are the main unloading areas for sediments. The main depositional system is the combination of braided river delta, infralittoral subaqueous fans, beach bar and lake system in the southern provenance. On this basis, a model of contemporaneous fault controlling sandstone distribution is established in southern Nanpu Sag. The contemporaneous faults stretching into the lake basin controlled the sandstone distribution of braid river delta, with lobate deposits occurring laterally along strikes on the downthrown blocks of faults and superimposing vertically in the shape of wedges. The favorable objectives for future exploration are braided river delta, infralittoral subaqueous fans at the distal end of these deltas, and the beach bars developed on the tilted blocks.
Ren S.-S.,China University of Petroleum - Beijing |
Yang S.-L.,China University of Petroleum - Beijing |
Hang D.-Z.,Jidong Oilfield Company
Zhongguo Kuangye Daxue Xuebao/Journal of China University of Mining and Technology | Year: 2010
Based on the well-produced gas, a mixture gas dominated by carbon dioxide, a slim-tube experiment was employed to obtain the minimum miscibility pressure(MMP) and displacement efficiency. The effects of gas component on the MMP and displacement efficiency were studied under larger component changes. Through a great quantity of experimental observations and analysis, the process of displacement was divided into three phases. The oil displacement mechanism and the effects of composition on recovery were also analyzed. The relationship quantitatively and change tendency of displacement efficiency with the mole fraction of carbon dioxide and pressure were determined. The result shows that the MMP increased with the decreasing of mole fraction of carbon dioxide. In the processes of immiscible state, the displacement efficiency was increased by 3.0%-5.4% with an average value of 4.4% while mole fraction of carbon dioxide was increased by 10%. Injection pressure has distinct influence on displacement efficiency. The displacement efficiency was improved by 1.2%-3.0% while the injection pressure was increased by 1 MPa with an average value of 1.8%.
Li L.C.,China University of Petroleum - Beijing |
Li L.C.,Jidong Oilfield Company |
Yang S.L.,China University of Petroleum - Beijing |
Chen H.,China University of Petroleum - Beijing
Energy Sources, Part A: Recovery, Utilization and Environmental Effects | Year: 2013
In order to solve the growing water production problem of screen pipe completed horizontal wells in unconsolidated sandstone reservoirs, water and sand control screen pipe was developed. By combining swellable packers, installing different sized nozzles, and assorting corollary tools, a water and sand control completion string was formed and then field tests were carried out. The field application shows that water cut of water and sand control screen pipe completed horizontal wells raises much slower compared to conventional screen pipe completed horizontal wells. Copyright © Taylor & Francis Group, LLC.
Han L.,Jidong Oilfield Company |
Zhang J.,Jidong Oilfield Company |
Cui H.,Jidong Oilfield Company |
Ma J.,Jidong Oilfield Company |
And 3 more authors.
Drilling Fluid and Completion Fluid | Year: 2011
As a horizontal well, NP23-P2002 is aimed at efficient development of one fault block oil reservoir of No. 2 Nanpu structure buried hill reservoir. The bottom hole temperature of target stratum exceeds 150 °C and the formation pressure coefficient is between 0.99 to 1.01, well leakage or overflow occurs even with a slight fluctuation, so carrying sand is the key to horizontal section of the construction. 0.94-0.96 g/cm 3 density of the oil-in-water drilling fluid is used in this well. Through preferred treating-agent and oil-water ratio adjustment, the final formulation of the oil-in-water drilling fluid is determined. The site application shows that the system completely meets the requirements of underground construction, and the high temperature resistance and sand-carrying problems have been successfully resolved. Nanpu Oilfield exploration and development purposes are successfully achieved under the under-balanced operation, 3-4 MPa under pressure, and remaining 2 m above the flame height.