WELLHEAD
28°42′N · 98°31′W
Permian Basin · Wolfcamp A
We Find WhatOthers Walk Over.
Wellhead drills through kilometers of rock and salt to locate the reservoirs that keep refineries running and turbines spinning. Audited reserves. Proven operators. Basin-ready from day one.
Regional Geology & Acreage Position
Operated Acreage
406,000net acres
Permian — Wolfcamp
Unconventional / Tight Oil
312,000 net acres
820 MBOE / well
218 operated wells
Gulf of Mexico
Deepwater / HPHT
8 operated blocks
12–48 MMBOE / field
4 subsea tiebacks
Eagle Ford — Karnes
Liquids-Rich Shale
94,000 net acres
410 MBOE / well
147 operated wells
Technical Capabilities
Independent Reserve Audit — Ryder Scott Co., February 2026: "Wellhead's proved reserve estimates are prepared in accordance with SEC definitions and guidelines. Finding and development costs, decline modelling, and EUR assignments are consistent with the highest standards of professional practice."
Production Growth & Reserve Replacement
Gross Production
122 MBOE/d
Q2 2025 average
Reserve Replacement
218%
3-year average, 3P
3P Reserves
847 MMBOE
Ryder Scott audited
Exploration Success
73%
Wildcat drill success
Fig. 1 — Production Growth Curve
Gross production MBOE/d · Q1 2022 – Q2 2025
"Wellhead's finding and development cost of $4.12 per BOE represents a top-decile position among North American independents we have evaluated over the past five years."
Ryder Scott Co. — Independent Reserve Engineers, 2026 Annual Audit
"The company's first-year production decline of 28% compares favourably with a peer-group median of 41%, reflecting superior completion design and reservoir management practices."
Wood Mackenzie — Operator Benchmarking Report, 2025
Wellhead vs. Industry Average
Metrics sourced from Ryder Scott Co. independent audit (2026), Wood Mackenzie Operator Benchmarking (2025), and IADC Safety Statistics. Industry averages represent the North American independent operator peer group (n = 47).
USD / BOE
Finding Cost
56% below peer-group median — top-decile F&D efficiency
%
First-Year Decline Rate
Superior completion design reduces revenue erosion in year one
days
Spud-to-First-Oil
24 days faster — translates to measurable NPV improvement per well
per 200k hrs
Recordable Incident Rate
Zero LTIs in 36 consecutive months. IADC safety award 2024.
%
Reserve Replacement Ratio
Consistent organic replacement — no reliance on acquisitions
% wildcats
Exploration Success Rate
Proprietary basin model reduces dry-hole risk materially
Primary Action
The full dataset is available under NDA.
Our Reserve Report includes 3P reserve schedules, production decline models, type-curve libraries, and full HSE statistics by basin.
From Seismic to First Oil
Full-Tensor 3D / 4D Seismic
Proprietary PSDM processing with anisotropy correction. Time-lapse 4D deployed on three active GOM fields for real-time reservoir monitoring.
HPHT Drilling Architecture
Rated to 350°F / 25,000 psi. ERD capability to 12 km measured depth. MPD standard on all deepwater operations.
SRV-Optimised Completions
Stimulated rock volume modelling reduces perforation clusters from median 48 to 22 — same EUR, 30% less sand and water.
Real-Time Fibre DTS
Distributed temperature sensing on 100% of operated horizontal wells. Production allocation resolved to individual stage level.
HSE Management System
API Q2 certified. Zero LTIs in 36 consecutive months. TRIR 0.18 vs industry 0.74. IADC Safety Award — North America 2024.
Open the Door. The data does the rest.
What you receive
Reserve Report (NDA)
3P schedules · decline models · type-curve library · full HSE stats
Exploration Summary PDF
Basin overview · acreage position · key metrics · operator profile
Response time
Qualified requests reviewed within 2 business days
Data shared under mutual NDA. Wellhead does not sell or share contact information with third parties.
Also Available
Download Exploration Summary (PDF)