Drilling cost transformation: strategy decides the outcome
The mandate was blunt: a contract strategy to support cutting well costs by half. The instinctive answer — chase lower rig rates — was available, and it was the wrong one.
Quick answer
In drilling, contract strategy — not market rates — is where a fifty-percent cost transformation comes from. At a major onshore field, the cost impact exceeded 60% — beyond the 50% target — with wells delivered 50% faster. Non-productive time dropped substantially. The market conditions were identical for every operator in the region; the difference was the strategy the contracts were built on.
Wells dominate upstream capex. When low oil prices made drilling and workover unaffordable at a major onshore field, the asset needed drastically shorter well delivery times at assured quality to support a 35% production expansion. Market rig rates had already fallen — the easy discount had already been taken — and the economics still did not work. Drilling cost transformation through contract strategy became the only viable path. The answer was not to squeeze rates further. It was to redesign the deal so that contractor success and asset success were the same thing.
How does contract strategy drive drilling cost transformation?
Contract strategy drives drilling cost transformation by designing the commercial framework so that the contractor's financial incentive is to deliver wells faster, at higher quality, and at lower total cost — not to maximise days on site. The rig day rate is a visible number, but it is not the dominant cost driver. Delivery time, non-productive time, learning-curve efficiency across a multi-well campaign, and the cost consequence of quality — rework, remedial operations, delayed production — each has a larger impact on total well cost than the difference between two competitive day rates.
A contract strategy that addresses these drivers directly — through the remuneration model, performance criteria, and incentive structure — can deliver cost reductions that rate negotiation alone cannot approach.
Why rate was not the deciding variable
Market rates had already fallen when the engagement began, so the discount had already been taken — and the economics still did not work. What the asset needed was a structural reduction in cost per well, driven by shorter delivery times at assured quality. That required addressing waste, alignment, and learning — not squeezing the day rate further.
The strategy explicitly treated rate as subordinate to three other variables: total cost of ownership, delivery time as a benefit, and quality as a cost driver. The contract was shaped so that contractor success and asset success were aligned — the contractor made more money by delivering wells faster and better, not by spending more days on location.
How the strategy was built around total cost
The contracts were designed around total cost and total value of ownership rather than price per day. Three design principles underpinned the approach:
- Aligned incentives. The remuneration model rewarded delivery speed and quality, not time on site. Contractor and operator objectives were made the same.
- Evidence-based cost targets. An aggressive but achievable cost target was grounded in operational data — what was technically possible based on the best-performing wells — not negotiated from a spreadsheet.
- Collaborative cost removal. When initial bids came in above the target, the response was not to squeeze the numbers but to work with the best-value bidder to remove inefficiencies between the parties until the target was reached — attacking waste, not margin.
These principles are grounded in the same cost and value intelligence framework that powerabode applies across energy assets.
A process for designing a cost-transformation contract strategy
- Map total well cost, not just day rates. Break down the cost structure: delivery time, non-productive time, materials, services, logistics, and the cost of quality failures. Identify which levers carry the most weight.
- Benchmark against the best-performing wells in the portfolio or basin. What cost and delivery time is technically achievable? This becomes the evidence base for the target.
- Design the remuneration model to reward the outcomes you want. If speed and quality matter most, the contractor must be paid for achieving them — not for spending days on site.
- Set the cost target based on evidence, not aspiration. The target must be ambitious but credible. A target no bidder believes is achievable will not attract quality bids.
- Use the tender process collaboratively. Work with the best-value bidder to close the gap between their bid and the target by removing inefficiencies — not margin. This requires commercial maturity from both parties.
- Carry the strategy into execution. The contract strategy must inform how the extended team manages the campaign. The extended contract management team — planners, engineers, logistics — must operate within the same logic.
Rate-based vs total-cost drilling contracts compared
| Dimension | Rate-based strategy | Total-cost strategy |
|---|---|---|
| Primary metric | Day rate | Cost per well delivered to quality |
| Contractor incentive | Maximise days on site | Minimise time; maximise quality and learning |
| Cost target basis | Negotiated from last rate | Grounded in best demonstrated performance |
| Tender dynamic | Price competition | Collaborative cost removal with best-value bidder |
| Non-productive time | Treated as contractor risk | Jointly managed; incentivised reduction |
| Sustainable cost reduction | Low — rates drift back | Higher — embedded in contract structure and learning |
What the results tell us about contract strategy
The outcome exceeded the brief: cost reduction above 60%, wells delivered 50% faster, non-productive time down substantially, and consistent quality achieved from the third well onward. The market conditions — rig availability, service costs, supply-chain dynamics — were identical for every operator in the region. The only variable that differed was the contract strategy.
This engagement confirms a principle that applies beyond drilling: the outcome of a capital programme is largely decided before work begins. Contract strategy — the shape of the deal, the alignment of incentives, the evidence base for targets — is where cost transformation happens for energy procurement and commercial architecture. Rates are a component. They are not the strategy.
Frequently asked questions
How much did contract strategy reduce drilling costs in this engagement?
The cost impact exceeded 60% — beyond the 50% asked for — with wells delivered 50% faster and non-productive time dropping substantially. The market conditions were identical for every operator in the region; the difference was the contract strategy.
Why is rate negotiation not the answer for drilling cost reduction?
Rate negotiation addresses unit prices, but drilling cost is dominated by delivery time, non-productive time, and operational efficiency. Shortening well delivery time at assured quality creates far greater savings than cutting the day rate.
What is total cost of ownership in drilling contracts?
Total cost of ownership in drilling considers not just the rig day rate but delivery time, non-productive time, learning-curve benefits across multiple wells, and the cost impact of quality — good wells versus wells that require rework.
How does contract strategy align contractor and operator incentives?
Contract strategy aligns incentives by designing the remuneration model so that contractor success and operator success are the same thing — for example, rewarding faster delivery and higher quality rather than more days on site.
What is the first step in reducing drilling costs through contract strategy?
The first step is to map total cost, not just day rates — identifying where cost is driven by delivery time, non-productive time, specification, and efficiency. This reveals the levers that contract strategy must address.
Summary
- In drilling, contract strategy — not rate negotiation — is where cost transformation happens. The engagement delivered over 60% cost reduction with wells 50% faster.
- The strategy was built on total cost of ownership, aligned incentives, evidence-based targets, and collaborative cost removal — not on squeezing day rates.
- The principle applies beyond drilling: the outcome of a capital programme is largely decided by the commercial architecture designed before work begins.
See it working — book a demonstration
Continue reading: Procurement Architecture — deals designed, not inherited.
Related service: drilling contract tendering and outsourcing. Overview: oil and gas procurement.
To discuss contract strategy for drilling or other capital programmes, book a demonstration or contact powerabode.
References
- Cost & Value Intelligence — the philosophy behind cost and value decisions. powerabode. Accessed 20 July 2026.
- The Extended Contract Management Team. powerabode Insights. Published 2026.