Research on Calculation Method of Density and Rheology of High-Temperature High-Pressure Drilling Fluid

2021 ◽  
Author(s):  
Lei Wang ◽  
Jin Yang ◽  
Zhengkang Li ◽  
Xinyue He ◽  
Lei Li ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Absolute Error ◽  
Rheological Parameters ◽  
Fluid Density ◽  
Maximum Absolute Error ◽  
Deep Well ◽  
High Temperature High Pressure

Abstract With the strengthening of exploration and development of deep strata and offshore oil and gas resources, more and more deep wells and deep-water wells have put forward higher requirements for drilling fluid performance. The high-temperature high-pressure of deep well and the low temperature environment of deep well have important influence on the rheology and density of drilling fluid. A new method for calculating the rheology and density of high -temperature high-pressure (HTHP) drilling fluid is proposed and studied in this paper. In this paper, the HTHP rheological data are used to predict the shear stress under different shear rates, and then the wellbore rheological parameters are predicted and analyzed. For the calculation of drilling fluid density, the classical component method static density calculation model established by Hoberock model based on drilling fluid components is analyzed and improved in this paper. The obtained model predicts that the maximum absolute error of drilling fluid density under different temperature and pressure is 0.02 g/cm3, and the absolute error is controlled within 2 %.

The Feasibility for Potassium-Based Phosphate Brines To Serve as High-Density Solid-Free Well-Completion Fluids in High-Temperature/High-Pressure Formations

SPE Journal ◽  
2018 ◽  
Vol 24 (05) ◽  
pp. 2033-2046 ◽  
Author(s):  
Hu Jia ◽  
Yao–Xi Hu ◽  
Shan–Jie Zhao ◽  
Jin–Zhou Zhao
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Oil And Gas ◽  
Pressure Coefficient ◽  
High Density ◽  
Well Drilling ◽  
Well Completion ◽  
Oil And Gas Resources ◽  
Completion Fluids ◽  
High Temperature High Pressure

Summary Many oil and gas resources in deep–sea environments worldwide are often located in high–temperature/high–pressure (HT/HP) and low–permeability reservoirs. The reservoir–pressure coefficient usually exceeds 1.6, with formation temperature greater than 180°C. Challenges are faced for well drilling and completion in these HT/HP reservoirs. A solid–free well–completion fluid with safety density greater than 1.8 g/cm3 and excellent thermal endurance is strongly needed in the industry. Because of high cost and/or corrosion and toxicity problems, the application of available solid–free well–completion fluids such as cesium formate brines, bromine brines, and zinc brines is limited in some cases. In this paper, novel potassium–based phosphate well–completion fluids were developed. Results show that the fluid can reach the maximum density of 1.815 g/cm3 at room temperature, which makes a breakthrough on the density limit of normal potassium–based phosphate brine. The corrosion rate of N80 steel after the interaction with the target phosphate brine at a high temperature of 180°C is approximately 0.1853 mm/a, and the regained–permeability recovery of the treated sand core can reach up to 86.51%. Scanning–electron–microscope (SEM) pictures also support the corrosion–evaluation results. The phosphate brine shows favorable compatibility with the formation water. The biological toxicity–determination result reveals that it is only slightly toxic and is environmentally acceptable. In addition, phosphate brine is highly effective in inhibiting the performance of clay minerals. The cost of phosphate brine is approximately 44 to 66% less than that of conventional cesium formate, bromine brine, and zinc brine. This study suggests that the phosphate brine can serve as an alternative high–density solid–free well–completion fluid during well drilling and completion in HT/HP reservoirs.

Study on Multi-Functional Experimental Apparatus for the Performance Evaluation of HTHP Drilling Fluid

2011 ◽  
Vol 422 ◽  
pp. 10-16
Author(s):  
Fu Hua Wang ◽  
Rui He Wang ◽  
Xue Chao Tan
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Drilling Fluid ◽  
Dynamic State ◽  
Mechanical Transmission ◽  
Well Drilling ◽  
New Device ◽  
Deep Well ◽  
Experimental Apparatus ◽  
New Apparatus

With the development of deep well drilling technology, a new HTHP (High Temperature High Pressure) experimental apparatus LH-1 was developed to meet the need of research and evaluation of deep well drilling fluid. With the advanced dynamic seal technology, mechanical transmission and data sensing technology, this new apparatus has many kinds of HTHP testing functions in a body and could evaluate manifold performances at the dynamic state of high temperature and high pressure including HTHP dynamic or static filtration test, high temperature dynamic scattering test of drilling cuttings, HTHP dynamic sealing and plugging tests, ultra HTHP aging test and so on. The lab tests show that the new apparatus gains such advantages as novelty of the design, stability of the performance, accuracy and reliability of the experimental data and facility of the operation. Having overcome the defections of the old apparatuses, the new device can provide a new means of experimental researches for the evaluation of HTHP comprehensive performance of deep well drilling fluid.

Corrosion Behavior of Novel Cr2MoNbTi Pipeline Steel in CO2 Environment

2012 ◽  
Author(s):  
Wenliang Zhang ◽  
Lining Xu ◽  
Shaoqiang Guo ◽  
Lei Zhang ◽  
Minxu Lu ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Corrosion Behavior ◽  
Oil And Gas ◽  
Pipeline Steel ◽  
Oil And Gas Industry ◽  
Carbon Steels ◽  
Co2 Corrosion ◽  
Uniform Corrosion ◽  
High Temperature High Pressure

CO2 corrosion is frequently encountered in oil and gas industry. The search for new sources of oil and gas has pushed the operational activities to harsher environment and this requires new tubing and pipeline materials which can endure tough circumstances. Low alloy steel containing Chromium, which fills the gap between carbon steels and corrosion resistant alloys in terms of cost and corrosion resistance, has aroused significant interest from steel enterprises and scholars. At present, these studies mainly focus on 3%–5%Cr steel, and little study concerns the 2%Cr steel, which is more economic and weldable. In this paper, novel Cr2MoNbTi steel was developed and the microstructure and mechanical properties were studied. Corrosion behavior of the Cr2MoNbTi steel immersed in the CO2-containing solutions, which corresponded to the environment of bottom-of-line corrosion (BLC), was studied using high temperature-high pressure autoclave. In addition, dynamic high temperature-high pressure condensation autoclave was employed to simulate the top-of-line corrosion (TLC) environment and the corrosion behavior of the Cr2MoNbTi steel under wet gas environment was investigated. The composition and morphology of the corrosion scale were characterized by energy dispersive spectroscopy and scanning electron microscopy analyses. The results show that the Cr2MoNbTi steel exhibited uniform corrosion and presented good resistance to CO2 corrosion compared with X65 pipeline steel.

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