Where the business stands
Jul 26 closed · month-to-date running at 69,282 BOE/d
Production
71,048BOE/d
-0.9% vs prior month
Revenue
$63.5M
+14.1% vs prior month
Cash netback
$19.03/BOE
+3.58 vs prior month
Operating cost
$8.26/BOE
+0.10 vs prior month
Uptime
92.0%
140,823 bbl deferred
Liquidity
$632.8M
1.12x net leverage
Production, last 12 months
Gross barrels of oil equivalent per day, all fields. Gas is
converted at 6 Mcf to the barrel.
Where it comes from
Antelope Draw
32%
Sagebrush Flats
24%
Cottonwood Bend
19%
Rimrock North
16%
Mesquite Ridge
10%
Rate by field
Revenue, last 12 months
Realised oil $53.58 against WTI
$56.85 — a -3.27 differential, weighted
by each field's share of the month's volume.
The fields
| Field | Basin | Wells | BOE/d | vs prior | Uptime | Water cut | Op cost /BOE | Netback /BOE | Revenue |
|---|---|---|---|---|---|---|---|---|---|
| Antelope Draw | Delaware Basin, TX | 60 | 22,879 | +0.9% | 95.1% | 74% | $8.30 | $19.19 | $21.3M |
| Sagebrush Flats | Midland Basin, TX | 45 | 16,733 | -1.0% | 95.3% | 75% | $8.23 | $19.63 | $16.3M |
| Cottonwood Bend | Powder River, WY | 31 | 13,430 | +19.0% | 95.9% | 69% | $7.85 | $19.17 | $11.4M |
| Rimrock North | Uinta Basin, UT | 17 | 11,021 | -2.8% | 92.8% | 63% | $7.43 | $16.91 | $7.5M |
| Mesquite Ridge | Eagle Ford, TX | 25 | 6,985 | -2.6% | 96.0% | 79% | $9.85 | $19.01 | $7.2M |
Needs a decision this week
| Well | Field | Why | BOE/d | Uptime | Cost /BOE |
|---|---|---|---|---|---|
| Mesquite 2-7H 42-143-30469 |
Mesquite Ridge | Workover this month | 101 | 77% | $50.11 |
| Cottonwood 1-2H 49-413-30174 |
Cottonwood Bend | Workover this month | 152 | 59% | $25.78 |
| Cottonwood 1-3H 49-335-30181 |
Cottonwood Bend | Workover this month | 148 | 64% | $28.27 |
| Sagebrush 8-32H 42-140-30384 |
Sagebrush Flats | Workover this month | 298 | 55% | $16.39 |
| Rimrock 2-8H 43-352-30437 |
Rimrock North | Workover this month | 491 | 50% | $12.88 |
| Sagebrush 3-11H 42-286-30237 |
Sagebrush Flats | Workover this month | 248 | 67% | $15.08 |
Ranked by operating cost per barrel, lost uptime and whether a
workover ran this month. 8 workovers across the portfolio.
Safety
0.93TRIR
industry benchmark 0.98 · 64
days since a lost-time incident
2 recordable
incidents in twelve months.
16.5 bbl reportable spill volume.
Wells
| Producing | 173 |
| Shut in | 5 |
| Drilling | 1 |
| Waiting on completion | 8 |
| Total | 187 |
What is loaded right now
| Source | Grain | Feeds | Last load | State |
|---|---|---|---|---|
| SCADA historian | Per well, every 15 minutes | Production, uptime, deferred volume, flare meters | 3 min ago | Live |
| Production accounting | Per well, per month, allocated | Allocated volumes, run tickets, royalty base | 13 hr ago | Current |
| ERP general ledger | Per invoice, per cost centre | Operating cost, G&A, capital spend, AFE actuals | 10 hr ago | Current |
| Land & lease | Per tract, per owner | Working interest, net revenue interest, lease obligations | 2 d ago | Month-end |
| HR & payroll | Per person, per pay period | Headcount, labour cost, overtime, hours worked | 2 d ago | Month-end |
| HSE incident log | Per event | Recordables, spills, near misses | 5 hr ago | Current |
| Marketing & settlements | Per delivery point, per month | Realised price, differentials, transport | 2 d ago | Month-end |
A number without a load time is a number you cannot act on, so
every panel above is dated. Month-end sources settle a week or two after the
month closes — which is exactly why the closed month and the month-to-date
figure are shown separately rather than blended.
See how the seven systems join →