Corva Alternatives for Real Time Drilling and Completions Data

Why drilling teams start looking for an alternative

Three things usually trigger the search. The first is the shape of the bill. Real time drilling platforms are priced against activity, per rig, per well or per active user, which means the cost moves with your programme rather than with your organisation. That works in your favour when activity drops and works against you in a busy year, exactly when nobody has spare attention for a procurement fight. Teams start asking what they would pay if the platform were a fixed asset rather than a meter.

The second is the data question. You are generating a continuous time series from every rig, and it is landing in a vendor platform. Sooner or later a reservoir engineer, a data science team or a new chief executive asks a reasonable question: where does the raw history live, can we join it to production and cost data in our own warehouse, and what happens to five years of drilling telemetry if we change vendors. Those are fair questions and they rarely have a comfortable answer when the platform is the store as well as the interface.

The third is workflow fit. Marketplace apps solve the problems that are common across many operators, which is exactly why they exist and exactly why they cannot solve the one you think you are better at. If your edge is a particular way of managing torque and drag in a specific formation, or a bespoke way of tying drilling parameters to per stand cost, you end up with the platform for the standard view and a spreadsheet or a Python notebook for the part that matters.

What Corva genuinely does well

Be honest about the plumbing before you dismiss it. Getting a reliable, low latency stream off a rig is not a solved problem you can wave at. Rig site connectivity is variable, the data comes through drilling data standards that are permissive enough to be inconsistent between contractors, channel names differ, units differ, and something has to buffer and reconcile when the link drops for forty minutes. A platform that has already absorbed hundreds of rig configurations has absorbed a lot of pain you would otherwise meet one contractor at a time.

The ready made application set is the second genuine strength. Having drilling engineers open a browser and immediately see hydraulics, mechanical specific energy, connection analysis and offset well comparison, on a phone at two in the morning, is real value delivered on day one. Building the equivalent set from nothing is months of work before anyone sees anything useful.

Where it actually strains

Activity based pricing is the first strain, and it is structural rather than unfair. Your unit economics change when a platform cost scales with wells drilled while your team size stays flat. The second strain is that you are working inside someone else's data model. Channel mappings, well identifiers and the definition of a stand or a connection are the platform's definitions. When you want to join drilling data to your own AFE and cost systems, those definitions have to be reconciled, and that reconciliation is your work regardless of who hosts the data.

The third is extension. Most platforms offer some way to build on top, through an SDK, an API or a custom app framework, and that is genuinely useful. It is still development inside a container someone else controls, on a release cadence someone else sets, with rate limits and scopes someone else defines. That is fine for an incremental view and awkward when the thing you want to build is central to how you operate.

The realistic options, including staying

The competing commercial options are the drilling data platforms from the large service companies and the specialist real time providers: the digital platforms from SLB and Halliburton Landmark, NOV's rig data offerings, Petrolink and similar real time aggregation specialists. Switching between them changes the vendor and the app catalogue. It does not change the underlying constraint that your operational history lives in a system you do not own.

The third option, and the one most teams underrate, is a hybrid. Keep a commercial platform for real time rig floor monitoring and alerting, because that is the part with the hardest reliability requirement and the least differentiation. Separately, stream a copy of the raw and cleaned time series into your own storage, and build your analysis, post well reporting and cost integration there. You pay for the plumbing you do not want to own and you own the asset you do not want to rent.

When a custom build pays back

Build when drilling performance is genuinely part of your commercial argument. A drilling contractor selling performance, a service company whose product is an optimisation method, or an operator with a large enough programme that a one percent improvement in days per well is a material number: all of those have a reason to own the analysis end to end. Build also when you need drilling data joined to things the platform will never hold, such as your AFE structure, your supply chain, your service company scorecards and your carbon reporting. That join is where most of the unrealised value sits, and it happens in your warehouse or not at all.

Do not build when your programme is small, when you have no data engineering capacity to keep an ingestion pipeline alive during a night shift, or when your engineers are actively using and trusting what they already have. A half maintained internal platform is worse than a subscription, because when the feed breaks at three in the morning there is no support number to call.

There is also a middle build that most teams overlook. Rather than replacing the real time platform, write your own well delivery record: the plan, the actual, non productive time coded the way your company codes it, service company performance, cost per foot, and the lessons captured while the crew still remembers them. That record is what your next well planning decision actually needs, it is specific to how you operate, and it is small enough to deliver in weeks. It reads from the real time platform instead of competing with it, so you can build it without touching anything on the rig floor.

Migration reality: history, channels and trust

Three parts of a migration are always underestimated. The first is historical data. Ask early and specifically what you can export, in what format, at what resolution, and whether derived channels come with it or only raw ones. Downsampled history is not the same asset as full resolution history, and you usually only discover the difference when you try to train something on it.

The second is channel mapping. Every rig and every contractor names things slightly differently, and your existing platform has been quietly normalising that for you. That normalisation is a real body of work, and rebuilding it is most of the effort in a custom ingestion layer. Do it well and document it, because it is also the piece that makes future rigs cheap to onboard.

The third is trust. Drilling engineers will not act on a new system's numbers until they have watched it agree with the old one on a live well. Plan to run both in parallel for at least two full wells, ideally including one where something goes wrong, because the value of a monitoring system is proven on a bad day rather than a good one.

Cost bands and the honest recommendation

Commercial platforms quote against activity: per rig, per well or per user, usually annually with a minimum commitment. That cost rises with your programme. A custom build is a fixed project plus cloud and storage costs, and time series storage at drilling volumes is affordable if you design retention deliberately rather than keeping everything at full resolution forever. From Digital Heroes delivery experience, a focused build covering ingestion into your own store, a normalised channel model and a core set of drilling dashboards runs roughly $60k to $140k over 12 to 18 weeks. A full platform with real time alerting, offset well comparison, mobile access, cost integration and post well reporting runs roughly $180k to $400k.

The honest recommendation: if you drill a handful of wells a year and want a live view, stay. If you drill enough that the meter is a line item people argue about, take the hybrid path first, because it is cheap, it is reversible and it settles the ownership question without betting a rig on new software. Go fully custom only when drilling analysis is part of what you sell, or when the join between drilling, cost and production data is the thing you are actually trying to build and no platform is going to hand it to you.