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.

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 %.

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.

Scale Prediction and Inhibition for Oil and Gas Production at High Temperature/High Pressure

SPE Journal ◽  
2012 ◽  
Vol 17 (02) ◽  
pp. 379-392 ◽  
Author(s):  
Chunfang Fan ◽  
Amy T. Kan ◽  
Ping Zhang ◽  
Haiping Lu ◽  
Sarah Work ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
High Temperatures ◽  
Oil And Gas ◽  
Gas Production ◽  
Scale Formation ◽  
Oil And Gas Production ◽  
Scale Inhibition ◽  
Kinetics Of ◽  
High Temperature High Pressure

Summary With the advance of new exploration and production technologies, oil and gas production has gone to deeper and tighter formations than ever before. These developments have also brought challenges in scale prediction and inhibition, such as the prevention of scale formation at high temperatures (150–200°C), pressures (1,000–1,500 bar), and total dissolved solids (TDS) (>300,000 mg/L) commonly experienced at these depths. This paper will discuss (1) the challenges of scale prediction at high temperatures, pressures, and TDS; (2) an efficient method to study the nucleation kinetics of scale formation and inhibition at these conditions; and (3) the kinetics of barite-crystal nucleation and precipitation in the presence of various scale inhibitors and the effectiveness of those inhibitors. In this study, nine scale inhibitors have been evaluated at 70–200°C to determine if they can successfully prevent barite precipitation. The results show that only a few inhibitors can effectively inhibit barite formation at 200°C. Although it is commonly believed that phosphonate scale inhibitors may not work for high-temperature inhibition applications, the results from this study suggest that barite-scale inhibition by phosphonate inhibitors was not impaired at 200°C under strictly anoxic condition in NaCl brine. However, phosphonate inhibitors can precipitate with Ca2+ at high temperatures and, hence, can reduce efficiency. In addition, the relationships of scale inhibition to types of inhibitors and temperature are explored in this study. This paper addresses the limits of the current predition of mineral solubility at high-temperature/high-pressure (HT/HP) conditions and sheds light on inhibitior selection for HT/HP application. The findings from this paper can be used as guidelines for applications in an HT/HP oilfield environment.

Homogeneous carbon doping of magnesium diboride by high-temperature, high-pressure synthesis

2014 ◽  
Vol 104 (16) ◽  
pp. 162603 ◽  
Author(s):  
M. A. Susner ◽  
S. D. Bohnenstiehl ◽  
S. A. Dregia ◽  
M. D. Sumption ◽  
Y. Yang ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Magnesium Diboride ◽  
Carbon Doping ◽  
High Pressure Synthesis ◽  
Pressure Synthesis ◽  
High Temperature High Pressure

High temperature-high pressure synthesis of a new phase of LaCuO3

1989 ◽  
Vol 137 (4-5) ◽  
pp. 205-206 ◽  
Author(s):  
A.W. Webb ◽  
E.F. Skelton ◽  
S.B. Qadri ◽  
E.R. Carpenter ◽  
M.S. Osofsky ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
High Pressure Synthesis ◽  
Pressure Synthesis ◽  
New Phase ◽  
High Temperature High Pressure
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