Predict hydrate formation, corrosion, wax, and scale in oil and gas operations.
npx skills add https://github.com/jpfielding/claude.pnge --skill flow-assurance
Please help me install this Agent Skill. Skill: flow-assurance Source: https://github.com/jpfielding/claude.pnge/tree/main/skills/flow-assurance Command: npx skills add https://github.com/jpfielding/claude.pnge --skill flow-assurance
This Skill helps predict and mitigate critical flow assurance problems in oil and gas production, preventing costly downtime and equipment damage.
Assess the hydrate risk for a well operating at 1500 psia with a flowing temperature of 50°F and a gas specific gravity of 0.65.
High-intent search queries and answers about installing and using this skill.
Hydrate prediction uses Katz and Hammerschmidt methods to estimate formation temperatures based on gas specific gravity and operating pressure, then sizes the required methanol or MEG injection rate to prevent blockage in oil and gas pipelines.
CO2 corrosion rates are calculated using the de Waard-Williams model, which evaluates partial pressures to predict metal loss, while H2S sour service thresholds are assessed per NACE MR0175 to determine material compatibility and inhibitor requirements.
Wax appearance temperature is estimated from fluid properties to predict deposition risks, while scale formation tendency is evaluated using the Langelier saturation index for CaCO3 to guide scale inhibitor selection and injection rate sizing.
Yes, flow assurance calculations can assess hydrate risks at specific conditions like 1500 psia and 50°F using the gas specific gravity, providing actionable methanol injection rates to mitigate blockage during cold weather operations.
The Hammerschmidt method provides a simpler inhibitor dosage estimate, while the Katz method offers detailed hydrate formation predictions based on gas specific gravity, making Katz more suitable for complex gas compositions and higher pressure conditions.
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