Tracking a horizontal well from spud through to completion

A horizontal well moves through a predictable chain of milestones, and knowing what to look for at each stage helps investors, landholders and engineers understand what is happening on the ground. Australian readers will recognise many of the same cues from the coal seam gas fields of the Surat and Bowen basins in Queensland, or from tight-gas plays in the Cooper Basin straddling South Australia and the south-west of the state. The same milestones that apply to a Marcellus or Permian well in the United States translate quite directly to these southern hemisphere analogues, even though the regulators and the operators are different.

For land professionals working across assets in Brisbane, Adelaide or Perth, watching a well progress from a permitted location to a producing tie-in often means scanning dozens of state agency bulletins, operator releases and trade press updates. A dedicated well-tracking workflow, layered on top of a mapping platform, makes the same task repeatable and far less dependent on memory or who happened to read the morning email.

Reading the permit register before spud

The first practical cue is the issue of a drilling permit. In Queensland this is handled by the Department of Resources, in South Australia by the Department for Energy and Mining, and in New South Wales by the Division of Resources and Energy. Each regulator publishes a permit register that lists the well name, licence number, approved surface location, target formation and approved total depth. Watching the register is the earliest way to anticipate a rig mobilisation, because the rig is normally booked weeks in advance and the operator will have lodged the application long before the bit enters the ground.

For investors comparing multiple prospects, the register is also useful for cross-checking operator disclosures. Listed Australian companies issue quarterly updates, but the permit trail tells you what the regulator has actually been told. Operator press releases can include projected spud dates that slip; the permit register rarely does, because it is the formal approval. Tying your watchlist to the register, rather than to a single news feed, removes one source of false starts and helps analysts in Sydney and Melbourne quickly compare corporate guidance against the public record.

Confirming rig release and the spud call

Spud is the moment the surface hole is drilled, and it is reported within a short window of the event itself. Conventional Australian operators typically notify the state regulator within twenty-four hours, while coal seam gas projects under the various petroleum and gas frameworks follow slightly different timing rules. Tracking the spud date is mostly a matter of monitoring the operator's daily drilling report and the relevant state activity notice. Many larger operators also publish rig schedules on their investor portals, particularly around major campaigns in the Surat or Browse basins.

Useful references to keep open while waiting for spud include:

• Queensland Department of Resources Drilling Activity Register
• South Australia DEM Petroleum Wells Database
• New South Wales Division of Resources and Energy well logs portal
• Operator investor portals and Appendix 5B cashflow statements
• Trade press digests such as the APPEA quarterly briefings

Operators who commit to public rig-release announcements make spud tracking simpler, but a good backup is to subscribe to commercial activity trackers that aggregate state notices. For land professionals servicing properties around Chinchilla, Roma or the South Australian Cooper region, the spud date also triggers contractual clauses around compensation and access, so the information rarely stays theoretical for long.

Following the vertical section and the kick-off

After spud, the rig drills a surface hole, runs and cements conductor pipe, then continues with the surface casing string before kicking off towards the target formation. Directional drillers plot the build section using motors and rotary steerable tools, with surveys at regular intervals confirming the planned inclination and azimuth. Each of these milestones is captured in the daily drilling report and is mirrored in the rig's morning report to head office.

Watching the kick-off point complete is one of the most informative moments, because it tells you whether the operator is staying within the approved boundary or has applied for a revised path. The Queensland and South Australian regulators publish notifications of material deviation, and the same applies in New South Wales for any well that crosses a lease or licence boundary. Geologists reviewing the well alongside seismic and geological data often make their first confident calls on landing zone quality once this section is complete, which is also when decisions start to be made about completion design.

Lateral drilling and geosteering through the target

The lateral is the horizontal section inside the producing formation, and it is the section that justifies the cost of a horizontal well in the first place. In a Cooper Basin tight-gas play, the lateral may be only a few hundred metres long; in a Surat Basin CSG development, the lateral can stretch to more than a kilometre. In the United States, multi-kilometre laterals are common in the Permian and Haynesville, and the length of the lateral directly affects how many stages can be pumped during completion.

Geosteering is the practice of adjusting the well path in real time to stay within the sweetest part of the rock. While-drilling logs provide gamma, resistivity and density curves, and the directional driller uses these to nudge the bit up or down. For anyone tracking the well from the outside, this is the stage where patience is required: until the lateral reaches total depth and the drill string is tripped out, almost nothing is publicly disclosed. Watching for the rig release that signals lateral TD is a useful interim milestone, and it is usually the point at which market sentiment shifts from "drilled but uncertain" to "drilled and worth completing".

Running logs, casing and stimulation

Key milestones to capture between spud and first gas include:

• Surface hole drilled and surface casing cemented
• Intermediate casing run, kick-off point reached at planned azimuth
• Lateral reaches total depth, drill string pulled out of hole
• Production casing cemented, stimulation or dewatering stages complete
• Wellhead installed, flowback and cleanup finished
• Tie-in to gathering line, first sustained gas to sales recorded

Once the drill string is out, the rig runs production casing across the lateral, then either completes the well immediately or moves to the next hole on the pad. Multi-well pads are standard practice in Australian CSG developments around Chinchilla, Miles and Dalby, where a single pad can host half a dozen or more wells. The completion phase includes perforating the casing at regular intervals, pumping stimulation fluids and isolating each stage with packers or plug-and-perf systems. For CSG this step is replaced by dewatering and cavity completions that connect the well to the coal seams.

Regulators in both Queensland and New South Wales have tightened stimulation reporting in recent years, particularly around chemical disclosure and baseline water testing. Following completion reports from the operator, combined with state environment registers, gives a clear picture of what was actually pumped and where, which is also useful data for water-bore owners downstream of the lease.

Flowback, production testing and tie-in

The final engineering stage is flowback and production testing, followed by tie-in to a gathering line or a centralised facility. In Australian CSG projects, gas is normally moved to one of the three large LNG trains at Gladstone or to the domestic market through the Wallumbilla hub. In the Cooper Basin, production flows to Moomba for processing before being piped to either Sydney or Adelaide. The first sustained gas to sales is the milestone that most investors care about, because it confirms the well is commercial rather than merely drilled.

Production figures are released in the operator's quarterly report and, for listed companies, in the Appendix 5B cashflow statement. State regulators also publish aggregate production data, which can be cross-referenced against the operator's own numbers. Anyone modelling a project should treat the first three months of flowback as the most variable, with rates settling once the well has cleaned up and stabilised against the backpressure of the gathering network.

Watching all of this from a mapping dashboard

Pulling these milestones together by hand is workable for one or two wells, but quickly falls apart across a portfolio of dozens or hundreds. A platform like Shale Navigator draws permit data, drilling activity and completion reports onto a single map, with overlays for shale plays, lease offers and pipeline routes. For a buyer checking whether a block has any pending regulatory action before settlement, the available mineral rights listings provide a useful starting point, while an insight on pending unitization application review explains how to interpret the state register when a well sits across multiple titles.

For Australian professionals working between Perth, Adelaide, Brisbane and the field, that single screen replaces several days of chasing PDFs and email alerts, and turns well progress into a routine check rather than a research project. Build a watchlist around the operator, the licence number or the basin, set alerts for spud, lateral TD, first gas and final report, and the rest of the workflow will largely look after itself.