Study on ESP String for Super Heavy Oil Exploitation in Tahe Oil Field

2012 ◽  
Vol 524-527 ◽  
pp. 1577-1580
Author(s):  
Zhi Qiang Huang ◽  
Cheng Song Qiu ◽  
Qin Li ◽  
Ya Chao Ma ◽  
Li Yan Liu
Keyword(s):  
Heavy Oil ◽  
Water Injection ◽  
Sieve Tube ◽  
Oil Field ◽  
Production Costs ◽  
Electrical Cable ◽  
Oil Exploitation ◽  
Light Oil ◽  
New Type ◽  
Tahe Oil Field

During the process of super heavy oil exploitation in Tahe oil field, when mixing light oil, due to heavy oil and light oil entering into pump from separator directly, the existing ESP string leads to poor mixing and heavy oil coming into the pump, as a result, the pump detection period is greatly shorten; when water injection-production, the injected water can contact with electrical cable and motor directly, causing serious damage to the cable and motor, and the pump detection period is also greatly shorten. This paper designs a new type of ESP string, adding a ESP dome, a sieve tube, a mixing device, an intelligent switch and a direct flushing valve, which can improve the mixing effect of heavy oil and light oil, avoid the injected water directly contacting with electrical cable and motor, in order to protect the electrical cable and motor, improve their service life, extend the pump detection period and reduce production costs. Field test showed that the pump detection period has been prolonged after using the new ESP string, it is recommended to promote the use.

Challenges, Opportunities and Threats of Deep Bottoms-Up Water Injection in Heavy Oil Reservoir: Lessons Learnt from the G Field, South Oman

2021 ◽  
Author(s):  
Chaitanya Behera ◽  
Sandip Mahajan ◽  
Carlos Annia ◽  
Mahmood Harthi ◽  
Jane-Frances Obilaja ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Water Injection ◽  
Field Performance ◽  
Oil Field ◽  
Oil Fields ◽  
Reservoir Pressure ◽  
Light Oil ◽  
Alternative Water ◽  
Variable Water

Abstract This paper presents the results of a comprehensive study carried out to improve the understanding of deep bottom-up water injection, which enabled optimizing the recovery of a heavy oil field in South Oman. Understanding the variable water injection response and the scale of impact on oil recovery due to reservoir heterogeneity, operating reservoir pressure and liquid offtake management are the main challenges of deep bottoms-up water injection in heavy oil fields. The offtake and throughput management philosophy for heavy oil waterflood is not same as classical light oil. Due to unclear understanding of water injection response, sometimes the operators are tempted to implement alternative water injection trials leading to increase in the risk of losing reserves and unwarranted CAPEX sink. There are several examples of waterflood in heavy oil fields; however, very few examples of deep bottom water injection cases are available globally. The field G is one of the large heavy oil fields in South Oman; the oil viscosity varies between 250cp to 1500cp. The field came on-stream in 1989, but bottoms-up water-injection started in 2015, mainly to supplement the aquifer influx after 40% decline of reservoir pressure. After three years of water injection, the field liquid production was substantially lower than predicted, which implied risk on the incremental reserves. Alternative water injection concepts were tested by implementing multiple water injection trials apprehending the effectiveness of the bottoms-up water injection concept. A comprehensive integrated study including update of geocellular model, full field dynamic simulation, produced water re-injection (PWRI) model and conventional field performance analysis was undertaken for optimizing the field recovery. The Root Cause Analysis (RCA) revealed many reasons for suboptimal field performance including water injection management, productivity impairment due to near wellbore damage, well completion issues, and more importantly the variable water injection response in the field. The dynamic simulation study indicated negligible oil bank development due to frontal displacement and no water cut reversal as initial response to the water injection. Nevertheless, the significance of operating reservoir pressure, liquid offtake and throughput management impact on oil recovery cann't be precluded. The work concludes that the well reservoir management (WRM) strategy for heavy oil field is not same as the classical light oil waterflood. Nevertheless, the reservoir heterogeneity, oil column thickness and saturation history are also important influencing factors for variable water injection response in heavy oil field.

Study for Optimization of Pump Setting Depth in Tahe Heavy Oil Field

2012 ◽  
Vol 487 ◽  
pp. 864-868
Author(s):  
Zhi Qiang Huang ◽  
Ya Chao Ma ◽  
Qin Li ◽  
Li Yan Liu ◽  
Cheng Song Qiu ◽  
...  
Keyword(s):  
Energy Consumption ◽  
Heavy Oil ◽  
Point Load ◽  
Oil Field ◽  
Unit Load ◽  
Wellbore Pressure ◽  
Single Well ◽  
New Type ◽  
Pumping Unit ◽  
The Cost

At present, the pump setting depth of machine wells in Tahe Oilfield is universally too deep as the reservoir is buried deep, viscosity of heavy oil is high, and the producing energy weakened. This will increase the input of sucker rod, oil tube material and lead to enlarge suspension point load of pumping unit mule head and energy consumption. According to the problems, on the basis of the regularity of distribution of wellbore pressure field, viscosity field, temperature field, this paper puts forward a new matching lifting technology: moving down the point of blending and picking up the pump setting depth. Moving down the point of blending can reduce the producing energy loss and enforce the crude oil’s fluidity in the wellbore ,and picking up the pump depth can reduce the cost and energy consumption, Field test shows that after the new type matching lifting technology implement, test wells are normal in operation. The pump setting depth is partly picked up and pumping unit load decreases. The single well saves thin oil by more than 10%.

scholarly journals Research and test on anti-corrosion and anti-scaling technology of downhole injection tools of Dagang Southern Oil Field

2020 ◽  
Vol 213 ◽  
pp. 03030
Author(s):  
Nan Hu ◽  
Haichao Yang ◽  
Haitao Wei ◽  
Wenjuan Li
Keyword(s):  
Mechanical Performance ◽  
Oil Field ◽  
Production Costs ◽  
Test Results ◽  
Effective Period ◽  
Industry Standard ◽  
Steel Material ◽  
Water Well ◽  
New Type ◽  
Average Corrosion Rate

Every year, water well inspection operations accounted for 27.3% of the total water well operations due to corrosion and scaling of downhole injection tools in the Dagang Southern Oil Field, which seriously affects the validity period of the injection string and the effect of the injection, greatly increasing the production cost. Therefore, through the research and experiment of anti-corrosion and anti-scaling technologies such as 00Cr25Ni7Mo3N dual-phase steel material, TiN coating, Ni-W-P coating and Ni-W-P-nSiO2 composite coating, a new type of anti-corrosion and anti-scaling technology for downhole injectiong tools has been developed. The field test results show that under the premise of ensuring the mechanical performance of the tools, the average corrosion rate of the supporting tools using the new anti-corrosion and anti-scaling technology is 0.0048mm/a, which is far lower than the industry standard 0.076mm/a. The successful test of this technology is of great significance to increase the effective period of the southern oilfield split injection and reduce production costs.

scholarly journals Modeling of Heavy-Oil Flow with Regard to Their Rheological Properties

Energies ◽  
2021 ◽  
Vol 14 (2) ◽  
pp. 359
Author(s):  
Ilia Beloglazov ◽  
Valentin Morenov ◽  
Ekaterina Leusheva ◽  
Ove T. Gudmestad
Keyword(s):  
Rheological Properties ◽  
Heavy Oil ◽  
Computational Models ◽  
Oil Field ◽  
Pipeline System ◽  
Natural Bitumen ◽  
Treatment Techniques ◽  
Oil Flow ◽  
Light Oil ◽  
Pumping Mode

With the depletion of traditional energy resources, the share of heavy-oil production has been increasing recently. According to some estimates, their reserves account for 80% of the world’s oil resources. Costs for extraction of heavy oil and natural bitumen are 3–4 times higher than the costs of extracting light oil, which is due not only to higher density and viscosity indicators but also to insufficient development of equipment and technologies for the extraction, transportation, and processing of such oils. Currently, a single pipeline system is used to pump both light and heavy oil. Therefore, it is necessary to take into account the features of the heavy-oil pumping mode. This paper presents mathematical models of heavy-oil flow in oil-field pipelines. The rheological properties of several heavy-oil samples were determined by experiments. The dependencies obtained were used as input data for a simulation model using computational fluid dynamics (CFD) methods. The modeling condition investigates the range of shear rates up to 300 s−1. At the same time, results up to 30 s−1 are considered in the developed computational models. The methodology of the research is, thus, based on a CFD approach with experimental confirmation of the results obtained. The proposed rheological flow model for heavy oil reflects the dynamics of the internal structural transformation during petroleum transportation. The validity of the model is confirmed by a comparison between the theoretical and the obtained experimental results. The results of the conducted research can be considered during the selection of heavy-oil treatment techniques for its efficient transportation.

Expierence of development of the Liael area of Yaregskoye heavy oil field using different technologies

2019 ◽  
Vol 10 ◽  
pp. 62-67
Author(s):  
S.M. Durkin ◽  
◽  
I.N. Menshikova ◽  
L.M. Rusin ◽  
A.A. Terentiev ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Oil Field
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