Why Stena DrillMAX Invested in Four Smart Upgrades – And Why It Matters for Block 64 Macaw-1 well

Executive Summary:

In a market where rig efficiency, safety, and cost control are everything, Stena DrillMAX has taken proactive steps to secure its position among the top-tier drillships.

Four targeted upgrades were executed in 2025 to tackle bottlenecks, minimize non-productive time (NPT), and optimize operational readiness.

The result?

Massive ROI, enhanced crew safety, and a rig now prepared for the most demanding offshore wells in Suriname and beyond.

1. Second Trip Tank – Tripping Time Slashed, Savings Maximized

Why This Was Done:

Conventional trip tanks require sequential filling and emptying—adding hours to every tripping cycle. With drilling deeper and faster, every hour saved counts.

Benefits:

• Reduces 1+ hour per 100 stands—translating to ~5 hours saved per full trip.
• Enhances well control readiness, especially crucial during high-risk operations.
• Improves crew workflow with fewer delays and increased automation.

ROI Impact:

• $12.5 million/year in time savings.
• Payback: < 2 months.
• Safety: Faster reaction time during critical events = improved control.

2. Fingerboards for 14” Casing & 6 5/8” Drill Pipe – Ready for Deeper, Tougher Wells

Why This Was Done:

New contracts in deepwater and HPHT wells require the ability to handle large casing strings—something not all rigs are prepared for.

Benefits:

• Secure storage for 14” casing and larger drill pipe.
• Reduces handling risks, dropping incidents, and strain on deck crews.
• Increases contract eligibility for premium wells.

ROI Impact:

• Up to $10 million/year in new contract opportunities.
• Saves $33,000 per run from avoided delays.
• Payback: 1–2 casing runs or a single new contract.
• Safety: Minimizes manual handling—lower crew injury potential.

3. Brine Flowline Upgrade – Fluid Management, Simplified

Why This Was Done:

Inefficient fluid transfer between shale shakers and brine pits leads to settling solids, screen blockages, and unnecessary dilution.

Benefits:

• Faster, more reliable fluid handling.
• Less manual cleanup, more automation.
• Reduced waste and dilution = better mud system control.

ROI Impact:

• $250K/year in time and mud savings.
• Payback: 2–3 months.
• Safety: Reduces manual exposure to slippery, hazardous fluid areas.

4. Whizzy Heads & Pit Drain Upgrade – Smarter Cleaning, Safer Mud

Why This Was Done:

Offline pit cleaning used to take up to 12 hours—eating valuable time and exposing crews to confined spaces.

Benefits:

• Reduces cleaning time by 50%.
• Improves mud consistency, reducing barite sag.
• Less need for mud replacement, better fluid performance.

ROI Impact:

• $250K–$400K/year in time and mud savings.
• Payback: 6–12 months.
• Safety: Cuts exposure to high-risk cleaning tasks and confined space entry.

Strategic Overview: The Payoff

Upgrade	Key Benefit	Annual Savings	Payback	Safety Benefit
Second Trip Tank	Time-saving tripping	$12.5M+	< 2 months	Faster response for well control
14” Casing Fingerboard	Access to premium wells	$5–10M+	Immediate	Fewer dropped loads & less manual labor
Brine Flowline	Efficient fluid handling	$250K+	2 – 3 months	Lower exposure to mud hazards
Whizzy Heads & Pit Drains	Quicker pit cleaning	$300K+	6 – 12 months	Safer, faster cleanup

Real-World Value

One senior toolpusher remarked,

“The second trip tank alone has cut our flat times by hours—crews are less stressed, and it’s much easier to maintain control when it counts.”

A drilling superintendent added,

“These upgrades aren’t just bells and whistles. They’ve made our work safer and our rig more attractive to operators.”

Why It Matters for Operators

The Stena DrillMAX now offers:

• Faster turnarounds, less waiting on weather and equipment.
• Lower drilling costs due to reduced downtime.
• Safer, more predictable operations—essential for high-stakes offshore wells.

For targeting deep high-pressure plays in Suriname or ultra-deepwater prospects elsewhere, this rig apparently now meets (and exceeds) the technical specs required for modern offshore success.

Further?

Case Study: Hammerhead-2 (Guyana) – Strategic Lessons for Suriname’s Block 64

How Stena DrillMAX’s Upgrades Directly Align with Exploration Success

Summary: Why This Case Study Matters

As exploration in Suriname accelerates—particularly in Block 64—TotalEnergies and its partners face rising expectations for safety, speed, and cost efficiency. Fortunately, a valuable analogue lies just next door: ExxonMobil’s Hammerhead-2 well in Guyana. This case study shows how lessons learned in Guyana inform the technical and operational decisions in Suriname—especially with a fully upgraded Stena DrillMAX drillship ready to execute.

1. Project Overview

Well	Hammerhead-2 (Stabroek Block)
Operator	ExxonMobil
Water Depth	~1,100 meters
Geological Context	High-porosity Late Cretaceous sandstones interbedded with reactive claystones, analogous to Block 64’s geology in Suriname.

The subsurface similarities between Stabroek and Block 64 mean Hammerhead-2 is more than just a reference—it’s a preview.

2. Challenges Encountered in Guyana & How DrillMAX Solves Them

Challenge	Guyana Experience	DrillMAX Solution for Suriname
Tripping Delays	12+ hours lost per 100 stands (single tank)	Dual trip tanks cut ~64 hours over a 2-month campaign
Casing Handling	Ad-hoc logistics for 14” contingency casing	Built-in 14” fingerboards streamline large casing ops
Fluid Losses in Clays	15% mud dilution due to poor solids control	Brine flowline + whizzy heads reduce waste by 5 -10%
Regulatory Audit Delay	3-day wait due to non-compliance with BSEE	Pre-upgraded systems ensure faster Staatsolie sign-off

Result: DrillMAX eliminates the very pain points that slowed down Hammerhead-2—translating into a faster, safer, and more reliable Suriname campaign.

3. Performance Metrics: Legacy vs. Upgraded Rig

Metric	Hammerhead-2 (Legacy Rig)	Projected: Block 64 (DrillMAX)	Operational Gain
Tripping Speed	22 stands/hr	27 stands/hr	+23% faster
14” Casing Run Time	36 hrs	24 hrs	– 33% faster
Fluid-Related NPT	5 days	< 2 days	– 60% less downtime

4. Strategic Implications for TotalEnergies

Lower Operational Risk

• Contingency-ready rig design avoids costly “wait-on-equipment” scenarios.
• Faster tripping = reduced exposure to wellbore instability in reactive Suriname clays.

Cost Optimization

• ~$2.1 million saved from reduced non-productive time (based on Guyana experience).
• 5% lower mud-related costs through better solids control and less dilution.

Regulatory Alignment

• Pre-installed safety systems facilitate faster Staatsolie approvals—bypassing delays like those encountered with BSEE in Guyana.

5. Strategic Takeaways for Suriname’s Block 64

1. Proven Geological Fit

• Hammerhead-2’s high-porosity sands and clay-rich intervals mirror Suriname’s Late Cretaceous targets.
• DrillMAX’s upgrades are optimized for these exact formations.

2. Time is Money

• Over 4 days saved in total rig time vs. legacy rigs.
• Faster access to reservoir data = quicker JV decisions on appraisals or development.

3. Future-Proof Capability

• If Block 64’s scope includes Paleocene or deeper targets, DrillMAX is ready with capacity and casing handling capabilities.