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Good morning. Yesterday's print: 14,218 MCF, running +4.7% above the 7-day trend. That's a clean number — but the trend is hiding real production slippage because 28% of our devices (48 of 172) are dark 14d+.
Today's must-do: resolve the Stanhope/Ashcroft gathering event — a cluster of meters are moving together, which is one compressor or one line, not several wells. Recovery on the fix is ~$17k/mo. Plus a multi-site I&E sweep to recover ~$33k/mo of invisible gas. Five decisions below, ordered by cost-of-delay.
A cluster of meters on the Stanhope/Ashcroft/Kirby/Westbrook/Markham Heirs CTB network show simultaneous 150-400% static-pressure creep over the last 5-7 days. Signature is one gathering bottleneck, not a fleet of well failures. Bayou So Comp Disch & Bayou South Sales Chk both classify LOADING in the same window — that's a failing compressor station fingerprint.
Recommended: approve midstream outreach + freeze well-level spend on those 10 wells until the upstream is resolved. Alternative: defer 48h for more data — but we lose ~$1,400/day in the meantime.
Spot battery reading 8.2V. Totalflow will stop writing below ~10.8V. We have days before this RTU goes dark and we lose all diagnostics on the well. Roundtable Discharge is at 11.5V — not critical but on the watch list for next week's route.
Four wells went dark mid-window with real recent production: Gallatin-West Sales Chk (91 MCF/D pre-dark), Lamar #1H (163 MCF/D), BRADFORD ECHO 006H (53 MCF/D), WESLEY 002 (56 MCF/D). These are $300/site truck rolls with modem or telecom as most-likely cause. ~$40k/month of gas is invisible on our dashboards right now.
Recommended: dispatch I&E tech tomorrow 05:00 route, start with Lamar (largest signal). Parker can pull stop-and-restart while tech is on deck.
Five wells show classic paraffin signatures (temp floor < 52°F, intermittent DP pulses): Henry R Shaw #2, VINTON 005H, Kincaid Marsh C/M, Bancroft #2H Alloc, Cypress Landing Sales. Recommended program: hot-oil + solvent batch ($2-3k per well, one-time) followed by continuous inhibitor ($300-400/well/mo). Projected incremental: ~18 MCF/D portfolio-wide, or ~$1,900/mo revenue at $3.50/MCF.
Three wells show clean plunger signatures independent of the gathering event: Henry R Shaw #2 Alloc, Bancroft #1 Alloc, Dewsbury 1. Flow-time < 75%, slug-ratio > 5×, latest MCF 15-42/D. Recommended: request quotes from two vendors, target install window mid-May post-gathering-resolution.
| Well | Intervention | Started | Status | DP response | ETA | Owner |
|---|---|---|---|---|---|---|
| Holloway #1 | Soap-stick trial, 1/D × 7d | 04-20 | Day 3 of 7 | +8.1% | 04-27 eval | Parker |
| Henry R Shaw #2 | Hot-oil + solvent batch | — | Scheduled 04-25 | — | 04-25 | Mitchell / Foamer vendor |
| Bancroft #2H Alloc | Waiting gathering-event resolution | blocked | Hold | — | post-Decision 1 | Foreman |
| Ramsey Fields 3H | Workover scope drafting | 04-18 | Scope phase | — | 05-01 target | Engineering |
| Time | Well | Alarm | Severity | Acked | Status |
|---|---|---|---|---|---|
| 03:14 | Bancroft #2H Alloc | Flow rate low (MCF/D) | HIGH | — | Open · awaiting triage |
| 04:58 | Lyman 3 | Battery low (spot) | HIGH | — | Open · see Decision 3 |
| 05:42 | Wolford 2-4-5 CK | Static pressure high | HIGH | — | Open · route-check |
| 07:22 | Holloway #1 | Loading score spike | MEDIUM | Parker 07:30 | Cleared — soap dose active |
| 14:11 | Halsey Sales Chk | No data 7d | MEDIUM | I&E 16:20 | Cleared — modem reboot |
| 22:08 | Ramsey Fields Sales Check | Volume ≤ threshold | HIGH | — | Open · gathering event |
| Well | Δ MCF/D | Revenue impact |
|---|---|---|
| Markham Heirs #2 GL | +42 MCF/D DoD | $4,410/mo |
| Salado Creek 8,9 & 15 | +28 MCF/D DoD | $2,940/mo |
| Rockwell Meadows GU #7 | +19 MCF/D DoD | $1,995/mo |
| Halstead Mercer 15H | +17 MCF/D DoD | $1,785/mo |
| Lockhart #1 Alloc | +15 MCF/D DoD | $1,575/mo |
| Well | Observed | At-risk $ |
|---|---|---|
| Ramsey Fields Sales Check | 7d 87 vs 30d 295 MCF/D (-70%, ~-208 MCF/D lost) | $10,920/mo |
| Bancroft #2H Alloc | 7d 106 vs 30d 300 MCF/D (-65%, ~-194 MCF/D lost) | $10,185/mo |
| Bancroft Sales Chk | 7d 207 vs 30d 378 MCF/D (-45%, ~-170 MCF/D lost) | $8,925/mo |
| Ramsey Fields 3H | 7d 0 vs 30d 157 MCF/D (-100%, ~-157 MCF/D lost) | $8,190/mo |
| Cypress Landing Sales | 7d 378 vs 30d 485 MCF/D (-22%, ~-107 MCF/D lost) | $5,565/mo |
| Program | Wells on treatment | Candidates pending | Response rate (30d) | Incremental MCF/D | $ / mo | ROI |
|---|---|---|---|---|---|---|
| FSC 600 Foamer Continuous · loading wells |
8 | 4 | 74% | +26 | $3,200 | +$6,000/mo |
| Paraffin Solvent + Continuous Batch + continuous · cold-flow wells |
3 | 15 | 58% | +8 | $1,400 | +$440/mo |
| Scale Inhibitor Continuous · bridging candidates |
0 | 3 | — | — | — | Pending water panel |
| Corrosion Inhibitor Pending CO₂/H₂S analysis |
0 | — | — | — | — | Gas panel request open |
| Well / Scope | Activity | Status | Scheduled | Est cost | Est gain | Payback |
|---|---|---|---|---|---|---|
| Gallatin-West / Lamar / BRADFORD ECHO / WESLEY 002 | RTU / modem replacement (4 sites) | Awaiting Decision 3 | This week | ~$3,600 | +360 MCF/D (visibility) | <2 weeks |
| 54-device ground-truth sweep | Pumper field audit (long-dark) | Route-plan in prep | 30-day plan | ~$5k labor | Decommission vs recover triage | Structural |
| WEATHERSBY 1H | Plunger install | Quote requested | May wk 2 | $8-12k | +58 MCF/D | 2.0 mo |
| Henry R Shaw #2 Alloc | Plunger install | Quote requested | May wk 2 | $8-12k | +49 MCF/D | 2.3 mo |
| Lamar #1H | Plunger install | Quote requested | May wk 2 | $8-12k | +49 MCF/D | 2.3 mo |
| Kincaid Marsh C/M | Plunger install | Quote requested | May wk 2 | $8-12k | +33 MCF/D | 3.5 mo |
| Wolford 2-4-5 CK | Plunger install | Quote requested | May wk 2 | $8-12k | +28 MCF/D | 4.1 mo |
| BEAUFORT GU 3H | Decommission / P&A eval | Confirm intent | Q2 review | — | — | — |
| Echo Bradford 2-1H | Decommission / P&A eval | Confirm intent | Q2 review | — | — | — |
| HARMON PIERCE GU 001 | Decommission / P&A eval | Confirm intent | Q2 review | — | — | — |