Drilling

Drilling rigs—these resilient pillars of human ingenuity—have been serving the extraction of hydrocarbon resources for over a century. The advancement of oil and gas drilling, which is intrinsically linked to improving our quality of life, owes much to these vital machines. From the scorching heat of Iran’s Khuzestan plains to the freezing extremes of Alaska, these rigs operate under the harshest conditions. In the upcoming series of posts, drawing on my personal experience in drilling rig commerce, I intend to explore the engineering, R&D, and commercial aspects of this industry. I hope that delving into these details will foster greater creativity and drive further innovation in drilling technology.

➡️ Sinopec rig 🎥 Dian Ahmad Kartanegara

A directional plan is just a line on a screen until it hits the rig floor. Hitting a 5-meter target window at 15,000 feet requires more than geometry—it requires a kinematic digital twin. After months of continuous development and rigorous physics optimization, I am incredibly proud to showcase the latest major update to T.H.E.O.S.—my proprietary rig-floor kinematic engine v.1.3a_1. To stress-test the new architecture, I ran a complex 3D Delaware Basin J-profile through the system to evaluate exactly how a ZJ-50 rig retrofitted with a TDS-11 Top Drive (37,500 ft-lbs capacity) and an 8-1/2" Push-the-Bit RSS handles dynamic rock boundaries in real-time. Here is how T.H.E.O.S. is bridging the gap between the engineering office and the brake handle: ○ Dynamic Waypoint Digestion: The engine does not just plot a curve; it actively hunts a sequence of spatial targets. In this run, T.H.E.O.S. executes a 3D evasive turn through the Bone Spring, validates the trajectory millisecond-by-millisecond, and acquires the horizontal landing in the Wolfcamp A dead-center. ○ Top Drive Kinematics & Geomechanics: The simulation mathematically models continuous 120 RPM string rotation, calculating true Capstan friction and top-drive torsional wind-up. Watch the telemetry feed as the bit crosses the Massive Dolomite boundary at 2,835m TVD: the engine maps the geomechanical transition instantly, accurately triggering the resulting torque spike and dynamic stick-slip smear. ○ True RSS Integration: By accurately bifurcating surface RPM from bit RPM, the simulation recognizes the complete absence of sliding drag on the 5-7/8" ERD pipe. The RSS natively bypasses the torsional lag, toolface fanning, and yield-dilution penalties that would normally cripple a PDM mud motor in this section. Bridging the gap requires applied physics, not just geometry. T.H.E.O.S doesn't just plan a well. It simulates the physics, locks in the waypoints, and drills it digitally before you ever rig up. ✍ Credits

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I agree with your point. if it still works reliably, why replace it completely? What surprised me at university was learning about advanced directional drilling—gyroscopes, MWD, real-time bit tracking—while still using a Marsh Funnel for mud checks. But I think the Marsh Funnel survives for one reason: practicality. It needs no electricity, no calibration, no maintenance. It works in dust, heat, and vibration. You get a reading in seconds, anywhere on the rig, at zero cost. Modern automated rheometers are great for labs and real-time monitoring, but on many rigs—especially remote ones—simple and fast still beats complex and fragile. So yes, it's outdated. But it's not gone because we're nostalgic—it's not gone because in the field, practical often wins over perfect.

Of course, in my opinion, if something works, its age doesn't matter! What do you think is the 21st-century replacement for the Marsh funnel?

Probably an unpopular opinion (judging from recent LinkedIn posts by young drilling engineers still expounding its virtues), but the Marsh Funnel needs to be phased out of modern drilling (fluid) practice. Dr. Marsh introduced his funnel for viscosity characterization at surface conditions in the early 1930's and it has served the drilling community well, but its time is up. Continuing to use it now almost 100 years later is like going to a Ford car dealership and asking for a model T, routing global communications through wire and radio rather than satellites, having no antibiotics and vaccines to treat infectious diseases (we seem to be getting back to this situation for various reasons, unfortunately), etc. Show me other completely unaltered 1930's technology that we still use on today's drilling rigs that has not been fundamentally changed and significantly improved over the last century, and you will see that the Marsh Funnel stands on its own in this regard. I know you were probably taught how to use the Marsh Funnel in mud / drilling school or petroleum engineering program at your university and have nostalgic feelings about it. However, we can these days monitor mud properties (in proper rheology units, not seconds to empty out a funnel) in a fully automated, real-time fashion, at more representative downhole conditions. This is what we should be doing to take mud monitoring and maintenance finally into the 21st century. My message to the late Dr. Marsh: thank you very much for your valuable contribution which has served the drilling community very well over many years, but your funnel now needs to go! ✍ Credits

Mexican offshore!!

Success overshot fishing 🫡✅ 📍TX, USA

⚠️⚓ Jack-Up Platform Capsize During Rig Move Operation In offshore operations, risk is always present but few events are as sudden and severe as the capsize of a jack-up platform. This footage captures the exact moment stability was lost during a rig move, turning a routine operation into a critical incident within seconds. Such incidents highlight the importance of professional training, operational discipline, and strict adherence to safety procedures across the offshore industry. Key Lessons for Offshore Professionals 🔹 Comprehensive planning and risk assessment are mandatory for every rig move 🔹 Soil investigation and leg penetration analysis must be accurate and fully validated 🔹 Weather windows must be strictly respected small changes can have major consequences 🔹 Clear coordination between towing vessels, rig crew, and marine control is essential 🔹 Emergency preparedness and drills are vital they save lives Incidents like this reinforce why procedures, standards, and continuous training must never be compromised. Behind every offshore structure are people relying on safe decision-making and disciplined execution. Carditis

Field Experience: Diagnosing a BHA Washout During a drilling operation, a gradual reduction in SPP was observed, eventually reaching 500 psi. After monitoring the trend and evaluating possible causes, the decision was made to POOH and inspect the drill string and BHA for signs of a washout. Upon inspection, a significant washout was found at the connection between the string stabilizer pin (upper component) and the float sub box (lower component), as shown in the attached photos. Based on the washout geometry visible on both components, which failure mechanism do you believe occurred first? Scenario 1: The float sub box developed a crack or defect first, initiating the washout and subsequently damaging the stabilizer pin connection. Scenario 2: The stabilizer pin developed a crack or defect first, initiating the washout and subsequently damaging the float sub box connection. I am interested to hear the opinions of drilling, L/MWD, directional drilling, and drilling tool specialists. Which scenario would you support, and what evidence from the washout pattern leads you to that conclusion? ✍ Credit

Field Perspective Note #1 Practical Wellsite Checks Before Casing Operations ✍ Ali Al Naimi

Field Perspective Note #1 Practical Wellsite Checks Before Casing Operations Casing operations are routine, but many avoidable issues originate from missed basic checks rather than complex technical failures. In my experience, disciplined preparation is often the biggest risk reducer at the wellsite. Below are practical checks that consistently add value before running casing: 1. Program and Design Alignment Ensure the casing program, tally, and accessories are fully aligned with the latest approved well program. Any last-minute changes must be clearly communicated to the rig crew and service providers to avoid assumptions on site. 2. Equipment Readiness and Compatibility Confirm casing, threads, centralizers, float equipment, and handling tools are correct, inspected, and compatible. Early verification reduces delays and prevents rushed decisions once operations begin. 3. Hole Condition and Well Control Readiness Review hole condition data, circulation parameters, and displacement volumes. Verify well control barriers, checklists, and monitoring responsibilities are clearly assigned in line with well control requirements. 4. Roles, Responsibilities, and Communication Clear definition of responsibilities between company, contractor, and service personnel is critical. Pre-job safety meetings and JSA discussions should address not only hazards, but also decision-making and escalation pathways. 5. Post-Run Verification and Documentation After reaching target depth, verify casing depth and tally accuracy before moving to the next phase. Record key parameters and any anomalies clearly to support proper handover and operational continuity. Final thought: Strong casing operations are rarely about doing something extraordinary. They are usually the result of consistent preparation, clear communication, and disciplined execution. #DrillingOperations #WellDelivery