Research Article
Experimental Study on Sealing Failure Mechanism of Injection-Production String in Underground Gas Storage under Cyclic Loading
Table 2
Working parameters of an injection-production tubular string of gas storage.
| The parameter name | The parameter value | The parameter name | The parameter value |
| Tubing outside diameter | 114.3 mm | Packer anchor timing wellhead pressure | 11 MPa | Tubing wall thickness | 7.37 mm | Packer set timing wellhead pressure | 20.5 MPa | Tubing steel grade | P110 | Wellhead pressure when shear ball seat | 35 MPa | Tubing running depth | 3580 m | Wellhead pressure during annulus pressure test | 10 MPa | Mass per unit length of tubing | 20.09 kg/m | Annuli liquid density | 0.9 g/cm3 | Tubing mass density | 7.85 g/cm3 | Gas dynamic viscosity | 0.011 m·Pa·s | Poisson's ratio of tubing | 2.06 × 105 MPa | Injected gas specific gravity | 0.6 | Linear expansion coefficient | 1.25 × 10−51/°C | Injected gas temperature | 15°C | Friction coefficients | 0.24 | Injected gas density | 0.7236 g/cm3 | Tubing wall equivalent roughness | 0.03 mm | Daily gas injection volume | 150 × 104 m3 | Packer setting depth | 3200 m | Daily gas production volume | 120 × 104 m3 | Minimum inner diameter of packer | 97.79 mm | Upper limit operating pressure | 36 MPa | Maximum outside diameter of packer | 146.05 mm | Lower limit operating pressure | 16 MPa | Completion fluid density | 1.05 g/cm3 | Rated tensile strength | 1877 MPa | Ambient temperature | 15°C | Rated internal pressure strength | 85.53 MPa | Formation temperature | 92.7°C | Rated collapse strength | 73.74 MPa | Temperature gradient | 2.2°C/100 m | Tensile efficiency of a certain thread | 100% | Tubing temperature before entering the well | 15°C | Compression efficiency of a certain thread | 60% |
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