1 Rock Volatiles Stratigraphy of Meramec, Upper Osage, and Lower Osage carbonates in Fairway Resource’s NW STACK wells: logging horizontal STACK wells from PDC cuttings’ volatile chemistry Michael Smith* (Advanced Hydrocarbon Stratigraphy), Geoff Ice (Fairway Resources), Greg Anderson (Fairway Resources), Sarah Rittenhouse (Advanced Hydrocarbon Stratigraphy), David Eby (Eby Petrography & Consulting, Inc.) Eby Petrography & Consulting, Inc.
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Rock Volatiles Stratigraphy of Meramec, UpperOsage, and Lower Osage carbonates in FairwayResource’s NW STACK wells: logging horizontalSTACK wells from PDC cuttings’ volatile chemistryMichael Smith* (Advanced Hydrocarbon Stratigraphy), Geoff Ice (Fairway Resources), Greg Anderson (Fairway Resources),Sarah Rittenhouse (Advanced Hydrocarbon Stratigraphy), David Eby (Eby Petrography & Consulting, Inc.)
Eby Petrography & Consulting, Inc.
NW STACK – Cored Wells
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Type Log & Generalized Depositional Model
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(modified from Vanden Berg & Grammer, 2016, AAPG Mem. 112)
MOUNDS
THREE LIMESTONE RESERVOIR TYPES
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I. Mound (Bioherm) Facies (Diverse Skeletal Grainstone)• Large, open pores (and some bitumen)• Best Oil Production
II. Clean Crinoidal Grainstone Facies• Dissolution & mostly microporosity• Background (fair to good) Oil Production
III. Mixed Crinoid/Siliceous or Silty Facies• Mostly nanoporosity (& high Gas/Oil ratios)• Fair to Poor Oil Production w/ high gas content
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I. Mound (Bioherm) Facies (Diverse Skeletal Grainstone)• Large, open pores (and some bitumen)• Best Oil Production
RESERVOIR TYPE I
0.5 mmPl. Light
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RESERVOIR TYPE I – Mound Facies
0.5 mm10 mm
OSA
GE
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II. Clean Crinoidal Grainstone Facies• Dissolution & mostly microporosity• Background (fair to good) Oil Production
RESERVOIR TYPE II
Pl. Light
EF (Blue Light) UV
1.0 mm
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RESERVOIR TYPE II – Clean Crinoidal Facies
0.5 mm 0.5 mm
Pl. Light Pl. Light + W.C.O
SAG
E
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III. Mixed Crinoid/Siliceous or Silty Facies• Mostly nanoporosity (higher Gas/Oil ratios)• Fair to poor oil production with higher gas content
RESERVOIR TYPE III
Pl. Light
XN Light
1.0 mm
EF (Blue Light)
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RESERVOIR TYPE III – Mixed Crinoid/Siliceous Facies
0.2 mm
Pl. Light
Limestone
Chert
10 mm
Calcite
Chert
OSA
GE
ADVANCED
HYDROCARBON
STRATIGRAPHYStarting Material: PDC Cuttings
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PDC Cuttings
Sub-Millimeter in size
Gently Caught
Washed and Dried then Loaded
Or
Sealed at Well Immediately after Gently Caught, and Washed. Usually sealed less than a minute after the cuttings are caught.
WBM or OBMNew Wells and Old WellsRock Bit Cuttings and Core Also.
ADVANCED
HYDROCARBON
STRATIGRAPHYAHS’s Unique CT/MS Technology
1. Cuttings (or Mud) SamplesSealed or Bagged at Well Site
2. Older well cuttings washed or unwashed
3. Oil based mud and PDC bits have limited impact
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Sample Volatiles Analyzed Using Mass Spectrometry
MS Analysis
Quantitative Reservoir Contents
Well Cuttings
The 4th Log
LN2 Cryo Trap Separation
ADVANCED
HYDROCARBON
STRATIGRAPHYAHS Products and Interpretation
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Category Sample depth
C1-C10, Total Gas/Oil Frac & Perm
Prospect Evaluation
HC Analysis Well Tops
Interpretation HC Detection, ID: faults, fractures, rock types, etc.
AHSexclusive analysis
Proximity to Pay, Organic Acids, Oil Migration
Pay Zone Mapping, product quality
From Client
A
H
S
Fault May Feed Oil Into Reservoir
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High Toluene/Benzene ratio at fault =Zone of Active Oil Migration
AHS Predicted Preferred Reservoir Zones
High Porosity High Permeability Rocks Can Lose Oil During Drilling , Transport, and Sample Prep
Tighter Rocks Maintain Oil and Gas from Cuttings through Drilling and Transport to the Surface
A
H
S
Potential Rock Type 1CO2 Response
Potential
ROCK Type 1
CO2
Response
Possibly
Bioherms
Largest Grains
Largest Fluid Inclusions
Highest CO2 Release
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6800700072007400760078008000820084008600880090009200940096009800
100001020010400106001080011000112001140011600118001200012200
100000 1000000 10000000 100000000
A
H
S
Potential Rock Type 1CO2 Response
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6800700072007400760078008000820084008600880090009200940096009800
100001020010400106001080011000112001140011600118001200012200
100000 1000000 10000000 100000000
Type 1
78008000820084008600880090009200940096009800
100001020010400106001080011000112001140011600118001200012200124001260012800
100000 1000000 10000000 1000000008000820084008600880090009200940096009800
10000102001040010600108001100011200114001160011800120001220012400126001280013000
100000 1000000 10000000 100000000
Type 1
Type 1
A
H
S
775079508150835085508750895091509350955097509950
1015010350105501075010950111501135011550117501195012150123501255012750129501315013350
100000 1000000 10000000 100000000
Potential Rock Type 2CO2 Response
Potential
ROCK
Type 2
Crinoidal
Grainstones
Large Grains
Large Fluid Inclusions
2nd Highest CO2 Release
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Type 1
A
H
S
6800
7000
7200
7400
7600
7800
8000
8200
8400
8600
8800
9000
9200
9400
9600
9800
10000
10200
10400
10600
10800
11000
11200
100000 1000000 10000000100000000
Type 1
Type 2
Potential Rock Types 1 and 2
Potential ROCK
Types 1 and 2 CO2 Responses:
Bioherms and
Shelf Grainstones
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6900710073007500770079008100830085008700890091009300950097009900
10100103001050010700109001110011300115001170011900121001230012500
100000 1000000 10000000 100000000
Type 1
Type 2
A
H
S
Reservoirs May Show Low Cuttings Oil Response
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High Performing Well
Low Cuttings Oil Responses
High Porosity High Permeability Rocks Can Lose Oil During Drilling , Transport, and Sample Prep
AHS Predicted Preferred Reservoir Zones
A
H
S
Reservoirs May Be Filled by Nearby Fault
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High Performing Well
Lateral Drilled Along N-S Fault
AHS Predicted Preferred Reservoir Zones
Nearby Parallel Fault May be Filling Reservoirs theEntire Length of Lateral
High Porosity High Permeability Rocks Can Lose Oil During Drilling, Transport, and Sample Prep
A
H
S
Fault May Feed Oil Into Reservoir
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High Toluene/Benzene ratio at fault =Zone of Active Oil Migration
AHS Predicted Preferred Reservoir Zones
High Porosity High Permeability Rocks Can Lose Oil During Drilling , Transport, and Sample Prep
Tighter Rocks Maintain Oil and Gas from Cuttings through Drilling and Transport to the Surface
A
H
S
Faults Might Feed Reservoirs and Create Porosity
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Lateral Drilled through a Fault
High Toluene/Benzene = Oil Migration along Fault
AHS Predicted Preferred Reservoir Zones Surrounding Fault
High Acetic Acid Toe Side of Fault
Small Fault Feeding Small Reservoir
A
H
S
Faults Migrating Oil and Acetic Acid
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Lateral Drilled through 2 NE-SW Faults
• Very High Acetic Acid and Toluene/Benzene
• Oil and Acid Rich Oil Field Brines Migrating on NE-SW Faults
A
H
S
Faults Migrating Oil and Acetic Acid
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Lateral Drilled through 2 NE-SW Faults
• Very High Acetic Acid and Toluene/Benzene
• Oil and Acid Rich Oil Field Brines Migrating on NE-SW Faults
• High Response Scaling
Faults
ADVANCED
HYDROCARBON
STRATIGRAPHYConclusions
• Fairway Resources is successful in producing liquids in the NW STACK by applying a variety of innovative technologies• Rock typing identifies potentially producible facies
• AHS RVStrat attempts to map reservoir quality, oil and gas migration and pay zones• Combined with rock type facies for more predictive mapping
and results
• Faults can be chemically identified • Porosity creation may increase rock facies reserves• Oil migration pathways provide clarity for well placement and
potentially producible zones
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