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Humble Dome

Cross Creek Field • Harris County, Texas • Bahr Lease Portfolio

Property Details

Cross Creek Field — Humble Salt Dome

Birthplace of Exxon's predecessor, Humble Oil. 1,500 acres with 9 wells in the Bahr Lease portfolio.

Location

Field: Cross Creek Field

County: Harris County, Texas

Acreage: 1,500 acres

Address: 13930 Smith Road, Humble, TX 77396

Boundaries: Cross Creek (N), I-69/US59 (S), Deerbrook Mall (S)

Well Spacing: 1,200 ft / 40 acre units

Regulatory

Operator: Spectral Oil and Gas Corp

Operator #: 809042

Field Numbers: 21840475, 21840477

Formations: Wilcox A, B, C sands

Original Lessees: Chevron U.S.A. Inc.

Lessor: Bahr Interest et al

RRC Verified Data

32 Years of Production & Revenue

Official Texas Railroad Commission production data • Nov 1993 - Oct 2025

$63M
Lifetime Revenue
Gas: $56.6M • Oil: $6.4M
Combined gas + condensate revenue from all 7 producing wells over 32 years (Nov 1993 - Oct 2025). Revenue calculated using actual Henry Hub and WTI prices at time of production.
18.7 BCF
Gas Produced
Avg $3.03/MMBtu realized
18,691,500 MCF total natural gas from Cross Creek Field. Peak production 3.83 BCF in 1996. Current rate ~105K MCF/year. Wilcox formation at 7,800-16,400 ft depth.
237K BBL
Condensate
Avg $26.79/BBL realized
237,385 barrels of condensate (light oil) produced alongside gas. Gas-to-oil ratio ~79:1. Condensate sold at WTI-linked prices, averaging $26.79/BBL over field life.
288 MCFD
Current Rate
~$27K/month at $3.15
Current combined daily rate from all 7 active wells (Oct 2025). Wells producing at ~3% of peak capacity. Workovers on priority wells could restore 5,000+ MCFD.

Revenue by Well

Bahr #1 8.35 BCF
$28.6M
Peak 7,200 MCFD (Mar 1995). Declined due to salt plugs and tubing leaks. Proposed: 7-stage frac + HF acid job to restore 300 MCFD.
Bahr #7 ★ 4.28 BCF
$13.2M
PRIORITY: Peak 6,400 MCFD (Oct 1996). Multiple Wilcox lobes never fractured. Multi-stage frac target: 2,400 MCFD.
Bahr #3 ⚡ 2.56 BCF
$7.43M
SUBSALT: Pay zone at 16,350-16,450 ft NEVER COMPLETED. 14,000+ psi BHP. Target: 10 MMCFD + 400 BOPD after re-entry.
Bahr #2 1.16 BCF
$4.44M
Peak 2,660 MCFD (Jul 1995). Currently 18 MCFD. Under evaluation for workover potential.
Bahr #4 0.88 BCF
$4.33M
Main pad location - all flowlines connect here. Peak 1,295 MCFD. Tubing replacement proposed. Target: 300 MCFD.
Bahr #9 ★ 0.65 BCF
$2.73M
PRIORITY: Peak only 600 MCFD - multiple zones perforated but NEVER FRACTURED. Multi-stage frac target: 2,400 MCFD.
Bahr #6 0.81 BCF
$2.26M
Peak 1,260 MCFD (Sep 1996). Currently 6 MCFD. Under evaluation for workover potential.
Priority Target Subsalt Re-Entry Active Well Tap/hover for details

Peak Revenue Years

$10.75M 1996 3.83 BCF • Peak year
All 7 wells online and producing at peak rates. Bahr #7 hit 6,400 MCFD. Gas averaged $2.40/MMBtu. Best single year in field history.
$7.87M 1997 2.92 BCF
First full year with all wells. Natural decline begins but still strong production. Gas averaged $2.40/MMBtu. Bahr #9 came online June.
$4.67M 1995 2.36 BCF
Ramp-up year. Bahr #1 peaked at 7,200 MCFD (Mar). Wells #2-3 came online. Low gas prices ($1.55/MMBtu avg) but high volume offset.
$4.1M 1998 1.80 BCF
Production down 38% from peak as natural decline accelerates. Salt plugging and tubing issues emerging. Gas averaged $2.09/MMBtu.
$3.6M 2000 0.87 BCF • High prices
Lower volume (77% decline from peak) but gas prices spiked to $4.15/MMBtu average. Demonstrates price sensitivity of field economics.

Annual Production (MCF)

'93: 32K MCF • $69K
First production Nov
'94: No production
'95: 2.36M MCF • $4.67M
Wells #1-3 online. Bahr #1 peaked 7,200 MCFD
'96: 3.83M MCF • $10.75M
★ PEAK YEAR - All 7 wells producing
'97: 2.92M MCF • $7.87M
Bahr #9 online. Natural decline begins
'98: 1.80M MCF • $4.1M
38% decline. Salt plugging issues emerge
'99: 1.26M MCF • $2.98M
Continued decline
'00: 868K MCF • $3.6M
Gas price spike to $4.15 avg
'01: 501K MCF • $2.37M
Price volatility ($9 Jan → $2 Dec)
'02: 336K MCF • $1.13M
Low prices, continued decline
'03: 332K MCF • $1.8M
Prices recover to $5 avg
'04: 390K MCF • $2.37M
Production stabilizes
'05: 276K MCF • $2.4M
Hurricane season impacts. $8+ gas
'06: 344K MCF • $2.43M
Post-hurricane recovery
'07: 325K MCF • $2.34M
Steady state production
'08: 229K MCF • $2.21M
Gas peaked $12.69 (Jun) then crashed
'09: 367K MCF • $1.61M
Production up, prices down post-crash
'10: 384K MCF • $1.92M
Shale revolution begins
'11: 289K MCF • $1.4M
Shale gas floods market
'12: 215K MCF • $761K
Gas hits $1.95 low (Apr)
'13: 169K MCF • $760K
Prices recover slightly
'14: 148K MCF • $758K
Polar vortex spike (Feb $5.93)
'15: 131K MCF • $389K
Price collapse to $1.93
'16: 153K MCF • $458K
Prices bottom, slow recovery
'17: 175K MCF • $602K
Production bump, stable prices
'18: 142K MCF • $527K
Prices avg $3.15
'19: 139K MCF • $419K
Pre-COVID baseline
'20: 113K MCF • $260K
COVID demand crash. $1.63 low
'21: 105K MCF • $474K
Winter storm Uri ($5.35 Feb)
'22: 98K MCF • $705K
Ukraine war. Gas hit $8.81 (Aug)
'23: 96K MCF • $298K
Post-spike normalization
'24: 92K MCF • $259K
Low prices ($1.61 Apr)
'25 YTD: 80K MCF • $279K
Through Oct. Current 288 MCFD
'93 '00 '10 '20 '25

Hover/tap bars for details • Decline curve typical of mature wells without intervention

Gas Revenue
$56.6M
18.69 BCF @ avg $3.03/MMBtu
Natural gas sold at Henry Hub spot prices. Price range: $1.61 (Apr 2024) to $12.69 (Jun 2008). 90% of total field revenue from gas.
Condensate Revenue
$6.36M
237K BBL @ avg $26.79/BBL
Condensate (light oil) sold at WTI-linked prices. Gas-to-oil ratio ~79:1. 10% of total revenue. Current WTI ~$72 vs historical avg $27.
Technical Analysis

Interactive Well Map

Click any well marker to view detailed production history, engineering data, and revenue projections.

Open Full Screen Map ↗
2
Priority Targets
Bahr #7 & #9
1
Subsalt Re-Entry
Bahr #3 — 10 MMCFD Target
5
Secondary Wells
Workover Candidates
Asset Details

Bahr Well Portfolio

8 wells with 18.69 BCF cumulative production and $63M lifetime revenue. Priority wells targeted for immediate rework.

Bahr #7 Priority
Peak Rate6,400 MCFD
Cumulative4.28 BCF
Lifetime Revenue$13.2M
Target Rate2,400 MCFD

Wilcox A, C, B sands with multiple lobes unfractured. Multi-stage frac planned.

API: 42-201-32448 • Lease: 161313

Bahr #9 Priority
Peak Rate600 MCFD
Cumulative0.65 BCF
Lifetime Revenue$2.73M
Target Rate2,400 MCFD

Perforated but not fractured sands in Wilcox A & B. Significant upside.

API: 42-201-32475 • Lease: 165671

Bahr #3 Subsalt Upside
Peak Rate5,600 MCFD
Cumulative2.56 BCF
Lifetime Revenue$7.43M
Target Rate10 MMCFD + 400 BOPD

★ Subsalt zone NEVER COMPLETED. Pay sand at 16,350-16,450 ft. Bottom hole pressure 14,000+ psi. 7" casing + 4-stage frac planned.

API: 42-201-32417 • Lease: 157025

Bahr #1 Secondary
Peak Rate7,200 MCFD
Cumulative8.35 BCF
Lifetime Revenue$28.6M
Target Rate300 MCFD

Highest historical producer. Declined due to salt plugs and tubing leaks. 7-stage frac + HF acid proposed.

API: 42-201-32323 • Lease: 148210

Bahr #2 Secondary
Peak Rate2,660 MCFD
Cumulative1.16 BCF
Lifetime Revenue$4.44M
Current18 MCFD

Evaluation pending. Well data under review for workover potential.

API: 42-201-32365 • Lease: 155124

Bahr #4 Secondary
Peak Rate1,295 MCFD
Cumulative0.88 BCF
Lifetime Revenue$4.33M
Target Rate300 MCFD

Main pad location. All underground flowlines connect here. Tubing replacement proposed.

API: 42-201-32429 • Lease: 160513

Bahr #6 Secondary
Peak Rate1,260 MCFD
Cumulative0.81 BCF
Lifetime Revenue$2.26M
Current6 MCFD

Evaluation pending. Well data under review for workover potential.

API: 42-201-32447 • Lease: 161466

Cleveland Agent #1 Secondary
FormationWilcox
FieldCross Creek
CountyHarris
StatusEvaluation

Additional well in Cross Creek field. Part of full portfolio acquisition.

API: 42-201-32444

Leadership

Management Team

JD

Jason Dudney

Chief Executive Officer

Strategic leadership and investor relations.

727-623-2652

GT

Gustavo Taboada

Chief Operating Officer

Field operations, drilling, completions, production.

713-478-9464

TC

Tomme Claycomb

Chief Financial Officer

Financial strategy, capital allocation, distributions.

305-747-3779

SM

Steven McGuire

Technical Advisor

Former COO of Spectral Oil & Gas. Led 2016 White Oak acquisition.

Service Partners

Schlumberger

Oilfield Services

REDBIRD Energy

Current Operator

Newmarc Petroleum

Technical Advisory

Bruington Engineering

Engineering

C&J Energy Services

Completions

Kinder Morgan

Gas Offtake

Firebird / CDL Crude

Oil Trucking

Investment Structure

Terms & Projections

Phase 1: Two-Well Program

Target WellsBahr #7 & #9
Capital Required$783,000
Working Interest75%
Lease Burden25%
Payout Period9 Months
5-Year ROI9.9x
Reserves (Texadon)10.1 BCF + 114K bbl

Return Calculator

$250,000
$3.50
5 years
Annual Preferred (12%)$30,000
Est. Annual Cash Flow$74,000
Est. Total Return$520,000

Full Portfolio Program

Total Offering$5M - $7M
Minimum Investment$100,000
Preferred Return12% Annual
DistributionQuarterly
Investor Share (Pre-Pref)80%
Investor Share (Post-Pref)75%
Payout Period24-36 Months
Offering TypeReg D 506(c)
Execution

Project Timeline

Month 1

Capital Close & Mobilization

Final capital close, vendor contracts executed, equipment mobilized.

Month 2

Site Preparation

Wellhead inspections, surface equipment upgrades, pipeline verification.

Month 2-3

Well Rework Operations

Tubing replacement, HF acid, multi-stage fracturing on Bahr #7 & #9.

Month 4+

Production Online

Wells online. Production flows to Kinder Morgan. Daily monitoring.

Month 5

First Revenue

First sales revenue received. Investor distributions begin.

Data Room

Available Materials

Download investor documents and technical reports

Investment Documents

📄

Investor Teaser

Executive summary with $63M verified revenue, well portfolio, terms

PDF • 2 Pages
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📋

Investor One-Pager

Quick reference with key metrics, well table, investment thesis

PDF • 1 Page
↓
✍️

Subscription Agreement

Investment commitment documentation with terms and signatures

PDF • 2 Pages
↓
📝

Investor Suitability Questionnaire

Accreditation verification and financial qualification form

PDF • 1 Page
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Technical & Maps

🗺️

Interactive Well Map

Click wells for production data, engineering specs, revenue projections

Interactive • Web
↗

Financial Reports & Legal

📈

Historical Financials Report

32-year production & revenue history, well-by-well breakdown, price analysis

PDF • RRC Verified
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📊

5-Year Projections Post-Rebuild

Production forecast, revenue model, IRR/NPV analysis, investor returns

PDF • Financial Model
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📜

Private Placement Memorandum

Full PPM with terms, risk factors, and legal disclosures

PDF • Legal
↓
📦

Full Investor Package

Complete due diligence materials including engineering reports

Available upon request
📧
🔒

NDA / Confidentiality Agreement

Non-Disclosure and Non-Competition Agreement

Available upon request
📧

Need additional documents? Contact our team at info@cladutacorp.com or call (727) 623-2652 for PPM, business plan, or custom due diligence materials.

Ready to Proceed?

Contact our team to discuss investment participation and next steps.

Email Investment Team Call: (727) 623-2652

CONFIDENTIAL — RULE 506(c) PRIVATE PLACEMENT

This offering is conducted pursuant to Rule 506(c) of Regulation D and is open only to verified accredited investors. Investment involves significant risk and loss of capital is possible. Past performance does not guarantee future results. No securities will be sold until investor accreditation is independently verified. This is not an offer to sell securities in any jurisdiction where prohibited. This material contains confidential information subject to Non-Disclosure Agreement. Distribution prohibited.

Securities offered by CLADUTA CORPORATION. Consult your own legal, tax, and financial advisors before investing.