scholarly journals Effect of Titanium and Boron Microalloying on Sulfide Stress Cracking in C110 Casing Steel

Materials ◽  
2020 ◽  
Vol 13 (24) ◽  
pp. 5713
Author(s):  
Ming Luo ◽  
Zhong-Hua Zhang ◽  
Yao-Heng Liu ◽  
Mou-Cheng Li
Keyword(s):  
Optical Microscope ◽  
Austenite Grain Size ◽  
Medium Carbon ◽  
Stress Cracking ◽  
Threshold Stress Intensity Factor ◽  
Sulfide Stress ◽  
Static Tensile ◽  
Prior Austenite Grain Size ◽  
Sulfide Stress Cracking ◽  
Grade Steel

The effect of Ti and B microalloying on the hardenability, prior austenite grain size (PAGS), mechanical properties, and sulfide stress cracking (SSC) of C110 grade steel was studied by Jominy testing, static tensile testing, an optical microscope (OM), scanning electron microscopy (SEM) and double cantilever beam (DCB) testing. The results show that the addition of 0.015% Ti and 0.002% B into a medium-carbon Fe-Cr-Mo-Nb-V steel increased the hardenability and refined the PAGS and quenched martensite packets, and the size of carbides was reduced. It is believed that these behaviors are responsible for the improvement in the threshold stress intensity factor KISSC.

scholarly journals Sulfide Stress Cracking of C-110 Steel in a Sour Environment

2021 ◽  
Vol 2 (3) ◽  
pp. 376-396
Author(s):  
Sagar Tale ◽  
Ramadan Ahmed ◽  
Rida Elgaddafi ◽  
Catalin Teodoriu
Keyword(s):  
Partial Pressure ◽  
Hydrogen Permeation ◽  
Pressure Ratio ◽  
Optical Microscope ◽  
Mixed Gas ◽  
Stress Cracking ◽  
Sulfide Stress ◽  
Sulfide Stress Cracking ◽  
Partial Pressure Ratio ◽  
Grade Steel

The scope of this study includes modeling and experimental investigation of sulfide stress cracking (SSC) of high-strength carbon steel. A model has been developed to predict hydrogen permeation in steel for a given pressure and temperature condition. The model is validated with existing and new laboratory measurements. The experiments were performed using C-110 grade steel specimens. The specimens were aged in 2% (wt.) brine saturated with mixed gas containing CH4, CO2, and H2S. The concentration H2S was maintained constant (280 ppm) while varying the partial pressure ratio of CO2 (i.e., the ratio of partial pressure of CO2 to the total pressure) from 0 to 15%. The changes occurring in the mechanical properties of the specimens were evaluated after exposure to assess material embrittlement and SSC corrosion. Besides this, the cracks developed on the surface of the specimens were examined using an optical microscope. Results show that the hydrogen permeation, and subsequently SSC resistance, of C-110 grade steel were strongly influenced by the Partial Pressure Ratio (PPR) of CO2 when the PPR was between 0 and 5%. The PPR of CO2 had a limited impact on the SSC process when it was between 10 and 15 percent.

scholarly journals Comparison of 2507 Duplex and 28 % Cr- Austenitic Stainless Steel Corrosion Behavior for High Pressure and High Temperature (HPHT) in Sour Service Condition with C-ring Experiment

2021 ◽  
Author(s):  
Harris Prabowo ◽  
Badrul Munir ◽  
Yudha Pratesa ◽  
Johny W. Soedarsono
Keyword(s):  
High Pressure ◽  
Stainless Steel ◽  
High Temperature ◽  
Austenitic Stainless Steel ◽  
Corrosion Behavior ◽  
Material Selection ◽  
Stress Cracking ◽  
Sulfide Stress ◽  
Sulfide Stress Cracking ◽  
Sour Service

The scarcity of oil and gas resources made High Pressure and High Temperature (HPHT) reservoir attractive to be developed. The sour service environment gives an additional factor in material selection for HPHT reservoir. Austenitic 28 Cr and super duplex stainless steel 2507 (SS 2507) are proposed to be a potential materials candidate for such conditions. C-ring tests were performed to investigate their corrosion behavior, specifically sulfide stress cracking (SSC) and sulfide stress cracking susceptibility. The C-ring tests were done under 2.55 % H2S (31.48 psia) and 50 % CO2 (617.25 psia). The testing was done in static environment conditions. Regardless of good SSC resistance for both materials, different pitting resistance is seen in both materials. The pitting resistance did not follow the general Pitting Resistance Equivalent Number (PREN), since SS 2507 super duplex (PREN > 40) has more pitting density than 28 Cr austenitic stainless steel (PREN < 40). SS 2507 super duplex pit shape tends to be larger but shallower than 28 Cr austenitic stainless steel. 28 Cr austenitic stainless steel has a smaller pit density, yet deeper and isolated.

Fit For Service Qualification for Sour Service High Strength Production Casing For High Temperature

2021 ◽  
Author(s):  
Luciana I. L Lima ◽  
Christelle Gomes ◽  
Carine Landier ◽  
Marilia Lima ◽  
Kevin Schleiss ◽  
...  
Keyword(s):  
Carbon Steel ◽  
Yield Strength ◽  
High Strength ◽  
Materials Selection ◽  
Well Production ◽  
Stress Cracking ◽  
Sulfide Stress ◽  
Sulfide Stress Cracking ◽  
Sour Service ◽  
Minimum Yield

Abstract In recent years the application of high strength carbon steel with 125ksi specified minimum yield strength as a production casing in deepwater and high-pressure reservoirs has increased. Sulfide stress cracking (SSC) can develop when high strength carbon steel is exposed to a sour environment. The H2S partial pressure in these sour reservoirs is above the 0.03 bar limit for this material at room temperature. Materials SSC performance evaluation requires an accurate simulation of field conditions in the laboratory. To evaluate the production casing SSC behavior, some fit for service (FFS) tests were carried out considering the well geothermic temperature profile for the materials selection. This paper presents a fit for service qualification carried out on Casing 125 ksi SMYS (Specified Minimum Yield Strength) materials. Two products with 125ksi SMYS were considered: one that has existed for several years and one developed more recently with a better SSC resistance – above the pH2S limit considered for the standard 125ksi SMYS material. The results obtained in this test program allowed casing 125 ksi SMYS materials selection for temperature above 65°C and environment more severe in terms of pH2S than the domain previously established for this grade. This allowed a new well production design, which saves one casing phase and avoids the necessity to use intermediate liners to prevent collapse.

Sign in / Sign up

Export Citation Format

Share Document