Well Integrity
1. Whether the current 7% of the wells facing wellbore integrity failure would still keep increasing with challenging locations and harsher environments?
How easy would it remain by AI/data science in order to achieve optimum production, maximum reserves recovery and cost-effective operations over a wellbore lifespan?
Whether AI would be able to address the issues successfully associated with cement quality; casing corrosion; dynamic drilling and production pressures; and completion and abandonment complexities under such harsh environments?
Can we comfortably hand over the issues of both primary well barrier (fluid column) and secondary well barrier (cement, casing, wellhead, high-pressure riser & BOP) to AI completely?
Can we also expect AI to address the issues of greenhouse gas emissions; and contamination of surface/ground water resulting from the lack of faultless well integrity?
2. To what extent, the integrity of the wellbore (having the least potential for exposure to fluid migration; better longevity; and reliable and fit-for-purpose hydraulic and mechanical barriers) remains critical towards maintaining operation safety, operation efficiency along with the environmental friendliness for oil and gas production – in the context of ultra-deep oil and gas resources, where, the depth of deep borehole hangs around 10 km; reservoir pressure around 150 MPa with reservoir temperature exceeding 200 degrees C?
Feasible to prevent the failure of cement sheath (inducing wellbore leakage) in order to maintain wellbore integrity under such extreme reservoir conditions?
Feasible to prevent the entry of the formation gas into the cemented annulus during cement hardening with ease? Require an improved understanding on cement hydration reaction process (along with cement pore pressure) with its associated stress states during cement hardening under HPHT conditions? Whether such enhanced exploitation difficulty (such as smaller-sized boreholes; smaller annular clearance; enhanced pressure difference; enhanced surge pressure & swabbing pressure during tripping; & overflow well shut-in (semisoft/soft/hard shut-in sensitizing annular pressure distribution and water hammer leading to the estimation of inaccurate wellbore pressure); would still meet the wellbore integrity with ease?
3. Whether the correlation between ‘void fraction’ and ‘solid particle concentration’ with the pressure wave velocity of the fluid in the annulus would become complex in such harsh environments?
Also, would it remain easy to capture the relation between shut-in time and wellhead pressure as a function of the displacement of the drilling fluid?
- Badges
- Science topic