Drelmont Petroleum
Upstream production, drilling, gathering, and hydrocarbon sales
About Drelmont Petroleum
Industry
Oil & Gas (Upstream Exploration & Production)
Company size
Fictional large independent E&P operator with 40 producing fields, 450 operated leases (246 producing, 127 held by production, 54 in development, 23 shut in), 2,500 wells (2,237 producing, 189 shut-in, 74 temporarily abandoned), 30 drilling rigs, 3,500 equipment units, 35 gathering and processing facilities, 5 hydrocarbon product streams, and 50 midstream and refinery purchasers.
Packaged scale
About 2.5 million rows across 20 Enterprise-tier tables, including 1,825,000 well-day production rows, 400,000 shipment rows, 90,000 well tests, 60,000 monthly production rollups, 45,000 equipment maintenance work orders, and 3,500 workovers.
Commercial range
The two-year synthetic commercial facts carry about $7.25B in modeled hydrocarbon sales revenue from 91.4 MMbbl of oil and 311 Bcf of gas, realized through fictional crude oil, natural gas, NGL, condensate, and produced-water sales to fictional purchasers.
Planning note
The packaged data helps BI buyers analyze production performance, downtime, drilling and completion cost, equipment reliability, intervention economics, gathering utilization, hydrocarbon sales, and HSE while keeping barrels produced reconciled to barrels shipped and sold.
Operating footprint
Multi-basin fictional onshore footprint with fields grouped into practical BI reporting regions.
Customer mix
Fictional midstream gatherers, refineries, crude marketers, gas processors, and NGL traders represented with screenshot-safe labels, each taking the hydrocarbon streams its business is set up to handle.
Drelmont Petroleum is a fictional large independent upstream oil and gas (E&P) operator used for synthetic BI analysis. The company story is built around producing fields and basins, operated leases, producing wells, daily production, drilling and completion programs, surface and downhole equipment, well interventions, gathering and processing facilities, hydrocarbon sales and shipments, and a health-safety-environmental program. Every field, basin, well, rig, facility, and purchaser name in this kit is fictional.
Operating Profile
- Produces and sells fictional crude oil, natural gas, NGL, condensate, and produced water from operated leases across several onshore basins.
- Daily well production rolls up to a monthly view and reconciles to lifting and shipments, so barrels produced track barrels sold.
- Every well publishes its productivity index, gas-oil ratio, water-oil ratio, and base decline, and its history follows those numbers.
- Connects drilling and completion programs, equipment reliability, interventions, well tests, gathering throughput, and HSE incidents.
- Excludes well logs, seismic, reservoir simulation, partner accounting, title detail, trading and hedging books, and full ledgers.
Recent Business Events
- 1A maturing core field is the executive focus because base decline and rising water cut are pressuring per-barrel operating cost even as production stays steady.
- 2A recently expanded gathering area is gaining throughput unevenly across facilities, raising questions about utilization, shrinkage, and capacity headroom.
- 3Newly completed wells sit shut in on leases waiting for gathering capacity, keeping the shut-in list an active operational question.
- 4Leadership wants one view connecting production, sales, drilling cost, equipment reliability, and HSE without subsurface complexity.
These are the operating questions this kit is optimized to answer first.
Oil, gas, and water production, downtime, and decline by basin, field, and well
Shipped volume, realized price, and sales revenue by product, purchaser, and contract
Lease operating expense and per-BOE cost split into lifting, maintenance, and other
Drilling and completion AFE cost, drilling days, and total depth by rig class
Equipment maintenance cost and downtime, workover incremental oil per dollar
Gathering utilization against design targets and HSE incident concentration
Embedded Analytical Stories
Value chain holds
Monthly rollups follow daily production and shipments lift approximately the barrels produced, end to end.
Lateral length wins
Wells past 11,500 feet of lateral average about 73 barrels a day against 44 for the shortest laterals.
Condition predicts cost
A Needs Attention unit takes about 27 work orders at an average $8,597 against 5 at $1,614 for a New unit.
Cost per barrel
Per-BOE operating cost varies by basin, lease, and maintenance burden, so high-volume fields are not automatically cheapest.
Workover economics
The most expensive workover is not always the best incremental oil per dollar, and worked-over wells make the most water.
Growing campaign
A 300-well drilling campaign grows the producing count month over month, and bigger rigs drill the same hole faster and cheaper.