Every well control procedure, every BOP, every piece of choke-and-kill equipment on a rig exists because of one event: the kick. Understanding what a kick actually is, and how it gets caught early, is the foundation everything else in well control is built on. What a kick is A kick is an unplanned influx of
What Is a Kick in Well Control, and How Is It Detected? Read More »
“Is this sour service?” is one of the first questions that should get asked on any wellhead or valve job — because the answer changes what materials are allowed, and getting it wrong isn’t a cosmetic mistake. It’s the difference between equipment that lasts its design life and equipment that cracks in service. What makes
What Is NACE MR0175 and When Do You Need Sour Service Materials? Read More »
A wellhead or tree component stamped “10M” or “15,000 psi” isn’t giving you a suggestion — it’s stating, per API 6A, the exact maximum pressure that component is qualified to hold, at a specified temperature, tested to a defined procedure. Understanding what those numbers actually mean (and don’t mean) matters for anyone specifying or reviewing
API 6A Pressure Classes Explained: What Do 2,000–20,000 PSI Ratings Mean? Read More »
A blowout preventer that hasn’t been tested recently is, for well-control purposes, a blowout preventer you can’t fully trust. API RP 53 sets out how often BOP components actually need to be function- and pressure-tested — and the honest answer is “more often than most people outside drilling operations would guess.” The two kinds of
How Often Should a BOP Be Tested? API 53 Testing Intervals Explained Read More »
“Christmas tree” is one of those oilfield terms that confuses more people outside the industry than it should — there’s no decoration involved. It’s the stack of valves and fittings sitting on top of a well that controls everything flowing in or out of it, and the name comes simply from how the branching arrangement
What Is a Christmas Tree in Oil and Gas? Surface vs. Subsea Explained Read More »
A wellhead stack is a set of stacked pressure-containing spools and hangers, and the names of the main components — casing head, tubing head, hanger — get used constantly without always being explained. Here’s what each one actually does, and how they fit together. The basic idea: a wellhead is stacked, not built as one
Wellhead Equipment 101: Casing Heads, Tubing Heads, and Hangers Explained Read More »
API 6A and API 6D both cover valves used in oil and gas service, and it’s a common point of confusion which one applies to a given piece of equipment. The short version: it comes down to where the valve sits. API 6A governs wellhead and tree equipment; API 6D governs pipeline valves. Same broad
API 6A vs. API 6D: What’s the Difference Between Wellhead and Pipeline Valve Standards? Read More »
A choke and kill manifold looks like a dense cluster of valves, chokes, and pipe spools, and sizing one properly means working through several interlocking decisions at once — pressure rating, choke sizing, redundancy, and line routing — each of which constrains the others. Here’s what actually goes into that. Start with the pressure rating
Choke and Kill Manifold Design: What Actually Goes Into Sizing One Read More »
Wellhead equipment often outlives the paperwork that qualified it. A stack installed fifteen or twenty years ago can still be structurally sound while the code edition it was designed to, the field’s production plan, or the equipment’s own service history have all moved on since. The question isn’t whether the equipment still works — it’s
When Does Legacy Wellhead Equipment Need Design Re-Qualification? Read More »
A subsea tree does the same fundamental job as a surface tree — controlling flow from the wellbore — but almost everything about how it’s designed to do that job is different, driven by one basic constraint: nobody can walk out and manually operate it. That single difference cascades into how it’s actuated, monitored, sealed,
Subsea Tree vs. Surface Tree: Key Design Differences Engineers Should Know Read More »