Down Hole Operation Company

Deyang, China

Down Hole Operation Company

Deyang, China
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Ma S.,China National Offshore Oil Corporation | Shen W.,Down Hole Operation Company
Well Testing | Year: 2015

All test methods of determine the productivity of gas well, a point deliverability testing method is more simple and quickly than others, and this method has been widely used in oilfield, especially suitable for offshore gas well test. But the traditional method of production experience formula to solve the specific gas reservoir has certain limitation, the calculation results is deviated with binomial result. At the same time, in order to simplify the gas well productivity calculation process, generally pseudo pressure will be simplified for pressure square. However, the simplify gas well productivity calculation process for abnormal high pressure gas reservoirs is not reasonable. Taking an abnormal pressure gas field (Jinzhou M gas field) as an example, starting from theoretical analysis, the first study of pseudo pressure in different pressure regions of different simplified forms on computing open-flow capacity of gas well; then based on Jinzhou gas field M abundant test data is established for the gas producing characteristics of a point deliverability calculation empirical formula. The example shows that, this research approach is feasible, and research results are reliable, which can be guidance to the relevant gas field production capacity study. ©, 2015, Well Testing. All right reserved.


Hou J.,China University of Petroleum - East China | Luo F.,Downhole Operation Company | Wang C.,Shengli Oilfield Company | Zhang Y.,China University of Petroleum - East China | And 2 more authors.
Energy and Fuels | Year: 2011

The water-oil relative permeability curve has a great effect on the rules of water cut increase and production variation. It is one of the most important data in reservoir development. With regard to a reservoir with a high degree of heterogeneity, the flow properties are various in different positions of the reservoir. Therefore, neither a single average relative permeability curve for the whole reservoir nor different curves for different sedimentary facies can precisely describe the reservoir flow characteristics, which will cause great difficulties for the remaining oil prediction and potential tapping. Therefore, it is of great importance to build a prediction model for the water-oil relative permeability curve, which can provide a calculation theory of the relative permeability curve for reservoir simulation using different relative permeability curves in different grid cells. The existing prediction models for the relative permeability curve have established the correlations between petrophysical properties and end-point values of the relative permeability curve and between end-point values of the relative permeability curve and the relative permeability curve independently. However, the relationship between petrophysical properties and the relative permeability curve has not been developed. For this reason, it is impossible to achieve the spatial distribution of the relative permeability curve according to petrophysical properties. Furthermore, the end-point values of the relative permeability curve are usually calculated directly by petrophysical properties, which may result in all predicted relative permeability curves shifting to the left or right unrealistically compared to the reservoir average relative permeability curve. As a result of the above-mentioned problems, taking into consideration the correction effect of the average relative permeability curve on predicting relative permeability curves in different positions of the reservoir, this paper obtains a correlation between petrophysical properties and the relative permeability curve on the basis of the statistical analysis technique and normalization method of the reservoir average relative permeability curve. Finally, a prediction model for the water-oil relative permeability curve is established. A test based on the basic data of the relative permeability curve is performed to verify the effect of this model. The test result shows that the prediction procedure of this model is quick, easy, and reliable. It also indicates that the spatial distribution of the relative permeability curve satisfying the migration rule can be generated from petrophysical properties, which provides a basic calculation theory of the water-oil relative permeability curve for reservoir simulation using different relative permeability curves in different grid cells. © 2011 American Chemical Society.


Hou J.,China University of Petroleum - East China | Luo F.,China University of Petroleum - East China | Wang D.,Downhole Operation Company | Li Z.,Shengli Oilfield Company | Bing S.,Shengli Oilfield Company
Energy and Fuels | Year: 2012

The capillary pressure is the key parameter to affect the inversion accuracy of the water-oil relative permeability curve. The existing analytical inversion methods have neglected the influence of capillary pressure, which may cause low precision for the estimated relative permeability curve in some cases. On the basis of the numerical inversion method for the water-oil relative permeability curve established in part 1 (10.1021/ef300018w), taking the one-dimensional radial numerical experiment for example, the rules of relative permeability variation and influence of different displacement conditions on relative permeability deviation when neglecting the capillary pressure are investigated. With regard to water-wet cases whose oil-water viscosity ratio is greater than 1.5, it indicates that the estimated water-phase relative permeability curve is higher and the estimated oil-phase relative permeability curve is lower compared to the true relative permeability curve when the capillary pressure is neglected. The main displacement conditions influencing the inversion accuracy of the relative permeability curve include the injection rate, average permeability, and shape factor of the core sample. As the injection rate increases, the degree of relative permeability deviation caused by neglecting the capillary pressure becomes smaller. Moreover, the deviation trends of the water-oil relative permeability curve are the same as those of the increasing injection rate when average permeability decreases or the shape factor of the core sample increases. Finally, the orthogonal experimental design technique is used to establish the experimental conditions considering the combined effect of multiple factors, and then the water-oil relative permeability curve under every experimental condition is estimated implicitly. On this basis, the multivariate analysis is performed to obtain the threshold value charts of radial displacement experimental parameters, such as the injection rate, average permeability, and shape factor of the core sample, and their corresponding rational value domains are also achieved, which can be used to reduce the influence of neglecting capillary pressure data as much as possible and provide a calculation theory for estimation of the water-oil relative permeability curve accurately. © 2012 American Chemical Society.


Yuan C.,Down Hole Operation Company
Well Testing | Year: 2012

New found blocks in Qinghai oilfield have the characteristics of the low pressure and low permeability, and more than 60% reservoirs of that need reform after perforating operation. While, the integration of oil testing technology can realize continuous operations of perforating, treatment and liquid discharging processes, which shortens testing cycle, improves oil testing efficiency, and prevents the second reservoir pollution, and can satisfy the practice needs of the "three low" reservoirs, has a positive effect on the evaluation of reservoir.


Li J.,Down Hole Operation Company
Well Testing | Year: 2012

Aiming at reservoir with the poor physical properties, tight rock, low permeability, pore and fissure development, through the compound perforating technique to combine perforating with high energy gas fracturing of acid fracturing, reservoir transformation yield increasing effect is formed. Combined technology of compound perforation and testing, conducting of perforating, high energy gas fracturing, down-hole test at the same time, simplifies the operating procedure, improves the work progress, accelerates exploration and development result evaluation and prediction.


Shengli oilfield shale reservoir has the follow properties such as deeply buried, high reservoir pressure, complex well structure, and long horizontal section. Some risks are existed such as difficulty in set and unset of the packer, big friction at hoisting and lowering string in long horizontal section and the gun easily detonated in oil testing operation. Aim at operation difficulties in Shengli oilfield shale horizontal oil well, optimization of the testing string, combined operation of perforation and test, small scale of fracturing test, fracturing, optimal and fast liquid discharge technology have been carried out to adapt to the level of shale oil well technology system and the technology was in successfully applied in Boyeping1 well which can gain oil production up to 7.46t daily with a cumulative oil production of 116t.


According to problems of packer collusion failure, gas influx of killing fluid, stuck and buried of testing string existing at three combination operation of perforation, acid fracture and DST in the high pressure gas well of Yuanba area, analysis and study has been conducted. Through improving the packer structure, controlling the testing pressure difference, changing the manner of killing well, optimizing testing string and operation process, the down hole complicated conditions occurs in the operation process are reduced to improve the test success rate and safety. Field applied in 49 well times of 31 wells, success rate is 98%, and good results are achieved. ©, 2014, Well Testing. All right reserved.


Lu Y.,Down Hole Operation Company | Guo J.,Southwest Petroleum University
Well Testing | Year: 2014

The expansion and extension mechanism of the shale reservoir's fracture is different from conventional reservoirs and micro-fractures are developed to cause fracturing fluid loss volume to be big, and conventional continuous stepped sand fracturing process does not apply to development of shale gas. Slug-style tech uses discontinuous sand model of plug + bunt middle + slug, which has functions of decreasing friction near-wellbore, improving fracture network complexity to achieve seam fracturing, increasing the success rate of operation and so on. This technique has been applied in a domestic shale gas well fracturing, whose successful rate is 100%, and achieves a good production capacity.


Zhu M.,Down Hole Operation Company
Well Testing | Year: 2013

Reservoir in Daniudi gas field has features of being low pressure, low permeability, low porosity and thin layer, so that the horizontal well is a more effective technical measure to raise single well production, improve the development effect, upgrade the recovery rate. In recent years, the quantity of horizontal wells increases year by year, but their completion methods, liquid discharging methods, and seepage rules and test methods are different from the vertical wells. Through the research, gas test technology for horizontal well in Daniudi gas field is optimized, which can develop Daniudi gas field effectively.


Li B.,Down Hole Operation Company
Well Testing | Year: 2013

With the production time prolonged of oil and water well in Qinghai oilfield, continuous adjustment and implementation of development plan, many production wells appear the phenomenon of casing damage, and the forms of damage are complex and diverse. Combining the fact of Qinghai oilfield, using the technology of the expansion tube, the production problems are effectively solved, which reduces the work-over time, and reduces the production cost.

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