In offshore drilling, BOP testing is a critical component of well barrier assurance. However, inconsistent processes across rigs can lead to incorrect line-ups, missed tests, and operational risk. This case study examines how the IPT Global Service Delivery Team supported an operator to improve BOP testing performance across a five-rig fleet in the Gulf of Mexico using SureTec® PressureTesting.
Across a five-rig fleet operating in the Gulf of America, incorrect line-ups (sometimes known as misalignments) during BOP tests occurred up to 60% of the time. The potential of executing BOP pressure tests with these errors increased safety risk and decreased operational efficiencies. The difference across rigs wasn’t equipment or operator. It was the consistency of the application of the well barrier assurance testing process by rig crews. The operator requested IPT Global’s support across the fleet to ensure a common baseline performance level was maintained across the rigs.
In offshore drilling operations, performance gaps between similar rigs working together with the same operator are common. Crew experience, familiarity with procedures, and operational maturity all vary. What doesn’t vary, however, is the consequence of a missed well barrier test. Incorrect line-ups undetected during BOP testing can leave critical components untested, create regulatory and environmental exposure, and compound into costly rig downtime.
To help establish a standardized approach, the IPT Global Real-Time Operations Center (RTOC) conducted a fleet-wide analysis of all BOP pressure tests over the course of one year. The results illustrate both the scale of the problem and the value of a consistent, technology-backed assurance framework, regardless of individual rig performance.
A fleet-wide analysis of 76 BOP pressure tests highlights both the scale of incorrect line-ups and the impact on offshore drilling performance.
When results are broken down by rig, the variance is stark and highlights a critical point: performance is driven by the consistent application of robust processes and assurance.
| Rig | No. of BOP Tests | Tests with Incorrect Line-ups | Missed Incorrect Line-ups Detected by RTOC | Lost Time (min) |
| Rig A | 17 | 59% | 5 tests (29%) | 270 |
| Rig B | 18 | 56% | 3 tests (17%) | 165 |
| Rig C | 8 | 13% | — | 5 |
| Rig D | 20 | 5% | — | 8 |
| Rig E | 13 | 0% | — | 0 |
The rigs with the lowest incorrect line-up rates share a common thread: a standardized, familiar process developed or supported by the IPT Global Service Delivery Team. Rig C operates with a full-time IPT Global Field Advisor supporting BOP testing execution and well barrier assurance processes embedded with the crew. The one incorrect line-up it recorded during the year was caught immediately by that IPT Global team member. Rig D had IPT Global Field Advisors on location for an extended period who helped build simplified, consistent test plans; the crew became deeply familiar with those plans, and the data reflects it. Rig E recorded zero incorrect line-ups across all 13 tests.
Rigs A and B tell a different story. Rig A recorded a total of 15 incorrect line-ups during BOP testing operations. This was the highest in the fleet and impacted 59% of its BOP tests, with the frequency trending upward as the year progressed. Rig A’s crew had recently been blended from two different drilling contractors, introducing unfamiliarity. IPT Global Field Advisors were not present onboard for BOP testing, though the IPT Global Service Delivery Team remotely identified five incorrect line-ups that were undetected by rig personnel. This accounted for three and a half hours of intervention time that would otherwise have resulted in undetected deviations.
Rig B showed a persistent failure at a specific test step with incorrect line-ups occurring in 56% of all tests, traceable to an incorrect cementer line-up that went uncorrected over multiple test cycles.
This is not a story about which rigs have better crews or stronger safety cultures. It is a demonstration of what happens when a standardized well barrier assurance and BOP testing process is applied consistently across a fleet, and what happens when it isn’t.
Every rig has its own dynamics: crew experience, contractor mix, familiarity with test plans, and operational culture and tempo. IPT Global does not override these dynamics. Instead, the SureTec PressureTesting software provides a standardized well barrier assurance framework for BOP testing, combining real-time monitoring, structured verification processes, and field expertise that operates independently of them.
Where a rig is already performing well, this approach reinforces and documents the behavior. Where performance is inconsistent, it identifies deviations early, before they become compliance events, safety incidents, or compounding downtime.
The data makes this clear. The eight incorrect line-ups missed by onboard crew but detected through real-time monitoring and structured BOP testing verification via PressureTesting and the IPT Global RTOC were identified through a consistent, structured process combining volume benchmarking, step-by-step checklist verification, and direct communication protocols, applied consistently and independently of rig floor activity.
Operators managing multiple assets simultaneously in offshore drilling operations face these same challenges at a larger scale. Performance varies, crews turn over, and experience levels differ. While a fleet-wide assurance program like SureTec PressureTesting does not remove these variables, it does establish a consistent baseline, ensuring performance gaps do not go undetected.
The rigs that performed best were not immune to incorrect line-ups. They were simply better equipped through familiarity, simplified plans, and consistent oversight to prevent or catch them early. IPT Global’s role is to extend that level of performance across the entire fleet, not just to those that have benefited from time and continuity.
A standardized approach to well barrier assurance is not a substitute for good rig culture. It is the mechanism that ensures good practice is applied consistently, regardless of where any individual rig sits on the performance curve.
Looking to improve BOP testing performance or strengthen your well barrier assurance processes? Contact IPT Global to implement a standardized, pressure testing and real-time monitoring framework across your offshore drilling fleet.
During a routine offshore BOP stump test, standard validation indicated acceptable results with no clear signs of failure. Pressure readings were stable, no alarms were triggered, and the system met conventional pass criteria.
However, traditional BOP pressure testing is designed to detect leaks, not subtle emerging issues. In this case, the system would likely have been cleared for deployment with an undetected integrity risk.
SureTec® PressureTesting TestEngine utilizing advanced leak detection analysis. Rather than relying solely on pass/fail thresholds, this approach evaluates:
This deeper analysis identified a subtle but consistent degradation in pressure trend; behavior inconsistent with a fully sealed system and easily overlooked using conventional methods.
Following the analysis:
By shifting the focus from “Did the test pass?” to “Does the data behave like a truly sealed system?”, the TestEngine analysis uncovered a developing leak that would have otherwise gone unnoticed. Early leak detection enabled proactive intervention, delivering measurable value:
This case reinforces a critical insight into traditional well control operations: passing a BOP pressure test does not guarantee system integrity. Subtle leaks can evade standard validation methods, progress under real operating conditions, and lead to high-impact offshore failures if left undetected.
By moving beyond pass/fail testing and understanding how pressure behaves over time, operators can detect what others miss, protecting both operations and the bottom line.