Interim CFO for oil & gas services during a six-month commodity downturn.

01 Why services is different from upstream — the lead-lag

Upstream operators have a price-deck conversation. Services operators have a utilisation-and-day-rate conversation, and the two move on different timetables. In the 2025 trough, US active rig count and frac-spread count flattened in late 2024 — roughly two quarters before the WTI bottom. Day rates compressed over two to three quarters once utilisation rolled. The order book recovered four to six months after WTI itself recovered. The CFO needs to plan for the trough being 90 days deeper than the price chart suggests and the recovery being 90 days slower than the chart suggests.

The Liberty Energy financials tell the asymmetry cleanly. Revenue tracked the cycle with a 16% peak-to-trough compression across fiscal 2023 to 2025 — $4.75B → $4.32B → $4.01B. Operating margin tracked it disproportionately — 16.0% → 9.0% → 1.8%. The take-rate cracked because the first 5-10 percentage points of utilisation decline are absorbed by overtime cuts and crew scheduling, but past 10-15 points of utilisation drop the discount-per-additional-point steepens fast. Frac and completions price compression typically runs 15-25% off peak in a 10-15 point utilisation move; wireline is often a couple of points worse on rate elasticity. The mid-cap services groups I work with do not have Liberty's $610M of operating cash flow to absorb that compression. The interim-CFO seat exists because they need it absorbed without a covenant breach, without losing the senior bench, and without the order book disappearing in the recovery.

02 Days 1–30: the working-capital line and the AR conversation

The first work is a working-capital rebuild. Services groups in a downturn carry receivables that age faster than in stable markets — operators slow-pay, dispute small-dollar items, and renegotiate terms mid-contract. Field tickets that closed in seven days in the upcycle now close in fourteen. PO mismatches that the operator absorbed in 2023 get returned to the services group in 2025. The interim CFO's first 30 days are spent rebuilding the AR aging by counterparty and by business line — completions vs wireline vs pumpdown — identifying the three or four counterparties whose slow-pay can compound into a liquidity event, and getting an explicit conversation with each on payment terms. None of this is dramatic. It is the conversation that the seated CFO would have lost relationships over.

A canonical Day 1-30 deliverable list looks like this. A 13-week cash flow built from bank balances and borrowing-base availability — not from the P&L. Weekly buckets for receipts (AR collections, mob prepayments) and disbursements (payroll, fuel, sand, chemicals, HP, leases, interest). Covenant test dates mapped, with explicit red-zone flagging for the months where a breach is plausible under both a base case and a downside case anchored to externally observable activity data. AR aging by counterparty, with the top 20 accounts flagged by >60-day, >90-day, and disputed exposure. Inventory snapshot by category (chemicals, proppant, spare parts, MRO) by turns and age. And a daily or twice-weekly cash huddle — CFO, controller, AR lead, AP lead, ops rep — with no non-essential capex without CFO sign-off and an explicit prioritisation of payroll, insurance, fuel, critical vendor continuity, and interest/fee discipline to protect against technical default.

The three-or-four counterparty conversation

On a typical mid-cap NAM services group, three or four customers carry 50-60% of AR exposure. The first 30 days has to surface which of them are slow-paying because of their own cycle pressure (and will normalise on recovery) versus which are using the downturn to permanently renegotiate terms. Both are legitimate, but the responses differ. For the first, the answer is a structured payment plan or partial prepayment on new jobs that preserves the relationship. For the second, the answer is a tightened mob policy and a credit-hold trigger that the sales team is informed about before the next bid window. Both conversations are CFO-level, neither can wait until month two.

Underneath the named-account work, the unsexy ledger work matters more than any of it. Many slow-pays in oilfield services are self-inflicted — mismatched POs, unapproved time, field-ticket errors. Standardising the field ticket, getting customer sign-off before demobilisation, and tightening the gap between job completion and invoice issue can pull 5-10 days out of DSO on the top 10 accounts inside 30 days. That is the early-wins line. It is also the line that proves to the CEO and the board that the interim seat is solving operational problems, not just managing the financial numbers.

03 Day 21: the lender pre-call, before you need a waiver

Within 21 days of starting, the interim CFO should have had a pre-emptive conversation with the senior lender. Not a covenant call. A pre-call. The pre-call is what buys the room to renegotiate covenants when the trough surfaces them in month three, instead of finding out about the breach the day the lender does. Post-2020, lenders to oilfield services became materially less tolerant of soft compliance, pro-forma EBITDA addbacks, and surprise covenant resets. They are tolerant of management teams that come in early with a coherent story, a defensible 13-week cash flow, base and downside cases tied to externally observable activity, and a clear list of self-help actions already underway.

The mechanics of the pre-call matter as much as the content. The interim CFO does the call alongside the CEO, not on behalf of the CEO — the lender is reading the room for management depth, not just for the numbers. The package shared in advance includes recent monthly financials with reconciliations, detailed covenant calculations with headroom under three scenarios (base, downside, stress), the 13-week cash flow, a 12 to 18-month forward view, and a one-page summary of working capital initiatives and cost actions with named owners and dates. The ask, framed as an option rather than a request, is for a reporting cadence enhancement that ties the lender into the same view of the business that the board has — same package, same time, no surprises.

Why this works

Lenders extend room to management teams they trust. The pre-call is the cheapest way to build that trust before the trough surfaces a covenant problem. ABL borrowing bases depend on eligible AR and inventory, and the eligibility criteria — typically AR >90 days ineligible, with bespoke concentration limits on top counterparties — need to be understood across both finance and sales before the next mix shift toward weaker credits triggers a borrowing-base haircut. The pre-call is also where the interim CFO learns what informal early warnings the lender has already given the seated CFO. That information almost always changes the priority order of the first 60 days.

04 Days 31–60: the fleet-by-fleet utilisation conversation

Most services groups carry equipment fleets sized for the peak of the last cycle. The honest utilisation conversation — fleet-by-fleet, region-by-region — is the one the operators have been avoiding because it leads to stack-and-store, sale-leaseback, or outright disposal decisions on iron that has emotional and historical weight inside the company. The interim CFO is positioned to drive that conversation because the seat is temporary. The decision quality is almost always better when made in the first 60 days of the trough than in the last 60.

The industry rules of thumb on stacking thresholds are tighter than most operators remember in the moment. Above 85-90% utilisation, every available unit works. Between 70-85%, fleets rotate normally with minimal stacking and modest price cuts. Between 60-70%, contractors start stacking marginal fleets — small-horsepower spreads, older diesels, weaker-basin units. Below 60%, aggressive stacking is the right answer; units get cannibalised for parts, capex drops to maintenance-only, and sale-leasebacks or asset sales come into the discussion for liquidity if leverage is elevated. In the 2020 shock, active US frac fleets dropped from over 300 to 45-50 mid-year — roughly 85% of marketed fleets stacked at the bottom. The 2025 trough was nowhere near as deep, but for mid-cap groups operating at the wrong edge of the utilisation curve, the same logic applies on a smaller scale.

The numbers above come from two completed mandates, completions and wireline, in North America. They are not industry averages and should not be read as such. They are the order of magnitude that an interim CFO at a similar group should be sizing against — and a useful sanity check on the work the management team is bringing forward in month two. The 23% headcount line is overwhelmingly junior and contractor positions, with the senior bench (covered in section five) treated separately and protected on principle.

The capex conversation runs alongside

Across 2016, 2018-19, 2020, and 2024 cycles, the capex deferral playbook is almost identical. Immediate cuts to maintenance-only — typically 50-80% reduction versus the prior year's plan. Cancel or defer OEM orders, negotiate delivery delays, reduce pump/engine/rig volumes. Use stacked assets to meet any recovery in demand rather than ordering new units — refurbish stacked equipment first, cannibalise other stacked units to minimise the incremental capex per reactivated fleet. Tie any new-build program to firm multi-year, high-return contracts. Tier 4, dual-fuel, and electric conversions only where returns clear an ROIC hurdle that holds in a flat-price environment. The interim CFO is the seat in the room that says the contract is not yet firm enough. The CEO and head of operations are the seats that build the contract before the build commits.

05 Days 61–90: protecting the bench

The bench is the senior technical workforce that the group spent the upcycle building — crew supervisors, frac engineers, wireline crew chiefs, field superintendents, lead pump and pumpdown specialists. In a downturn, the easy answer is to cut it. The full-cycle answer is to model what cutting it actually costs, and the math has been documented across every NAM oilfield services cycle since 2014. After the 2020 shock, providers rebuilt senior field labour at 15-30% higher cash cost than pre-COVID for equivalent roles, plus sign-on and retention sweeteners. The 2021-22 ramp was demand-constrained by crew availability, not by iron — capacity sat idle on people. Operators noticed which providers held their bench and which did not, and the bidding edge on critical pads went to the ones who had.

The interim CFO's third 30 days are about identifying the bench positions the group needs back in 12 months and engineering retention that is cheaper than rebuilding the bench post-recovery. The mechanisms are well-documented but rarely implemented as a coherent package. Bench-rate or reduced-schedule pay — lower daily rate plus guaranteed minimum days per month, or salary plus reduced field premium, replacing 100% variable on-job comp. Deferred cash retention bonuses tied to a specific recovery trigger — "stay continuously employed until [date] or until frac fleets exceed [threshold] and receive [amount]." Reduced-duty roles into fleet maintenance and refurb, safety and training, new-technology field-test crews. Sabbaticals — three to six months away with benefits maintained and a defined return date or price/rig trigger. None of these mechanisms are standard playbook moves in oil and gas. All of them are negotiable in a trough.

The full-cycle math

A retained senior crew supervisor on bench-rate pay at 60-70% of upcycle daily costs roughly $60-90k over a six-month trough versus the alternative cost of rebuilding the position post-recovery at $100-150k in recruitment, sign-on, training, and competency-verification time, plus the productivity drag of running a green crew through the first six months back. The full-cycle math favours retention by a factor of two-to-three on the cash line and meaningfully more once the operational and safety drag is included. For mid-cap services groups where 8-12 senior crew supervisors are the difference between bidding a critical multi-pad program and watching a competitor take it, the bench-retention math is the single highest-ROI decision in the entire interim mandate.

The handover conversation

By day 90, the recovery handover should be visible. The named successor — permanent CFO, finance director, or operations-finance executive — sits in the room for every major decision from day 90 onward. The handover document, written from day 60 and refined through day 90, becomes the operating plan for the next four quarters. It includes the 13-week cash forecast and its update cadence, the lender reporting package and its calendar, the AR collections framework with named owners and escalation procedures, the fleet utilisation review with decision rules at each utilisation threshold, the bench retention schedule with trigger dates, and the covenant model with early-warning thresholds and the pre-agreed lever set.

06 What the 2025 trough looked like in the data

WTI monthly averages from FRED tell the trough shape cleanly. From an April 2024 peak of $85.35, prices stepped down through 2024 ($70.24 in September, $70.12 in December) and into 2025 ($63.54 in April, $62.17 in May, $64.86 in August). The sub-$60 window was five months — October 2025 ($60.89), November ($60.06), December ($57.97 — trough), January 2026 ($60.04), with February at $64.51. Then a supply-side event reset the curve: March 2026 monthly average $91.38, April $100.32. Henry Hub natural gas ran a different cycle in the same window — weak through 2024 (March 2024 low at $1.49/mmBtu) and then strong through 2025-26, with a January 2026 cold-snap spike to $7.72. Gas-directed completions in the Marcellus and Haynesville cushioned through the WTI trough; oil-directed Permian and Bakken completions felt the full compression.

The Liberty Energy financial cadence through the same window is the cleanest public read on the trough's services-side impact. Revenue $4.75B (2023) → $4.32B (2024) → $4.01B (2025). Operating cash flow $1.01B → $829M → $610M. Operating margin 16.0% → 9.0% → 1.8%. Liberty held the dividend, moderated buybacks ($203M → $129M → $25M), and continued investing through the trough ($643M → $435M of net investing outflow). The pattern is the textbook upper-quartile response to a sub-$60 WTI window: protect the senior cash returns, moderate growth capex without zeroing it, hold the bench, and let operating leverage do its work in reverse without panic.

For an interim CFO at a smaller services group, Liberty is not a comparable in the strict sense — the operating cash flow cushion is two orders of magnitude different — but it is the right read on the discipline. A mid-cap group going through the same trough is more leverage-sensitive (covenant breaches surface faster when operating margin compresses from the mid-teens to the low single digits on similar revenue), more AR-exposed (fewer counterparties, less ability to absorb a slow-pay from a top-three E&P customer), and more bench-fragile (losing two or three senior supervisors at a four-spread operator is a quarter of the senior bench). The job is to get the smaller group through the compression with the same discipline Liberty showed at scale, on a budget that is two orders of magnitude tighter.

07 Three questions for the next trough

WTI snapped back from $58 in December 2025 to over $100 by April 2026. The next trough may be three months away or three years away, but the questions an interim CFO walks into are the same every time. Three of them sit above everything else.

1. Which three counterparties on the AR aging can compound into a liquidity event if they slow-pay by 60 days, and have you had the payment-terms conversation with each before the next covenant test date?
2. When was the last honest fleet-by-fleet utilisation conversation, and is anyone in the room with the political room to call stack-and-store on iron that has emotional and historical weight inside the company?
3. Which 8-12 bench positions do you need back in 12 months, and what is the retention model — bench-rate pay, deferred cash bonus tied to a recovery trigger, sabbatical, reduced-duty role — that holds them through the trough at a fraction of the post-recovery rebuild cost?