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What is the Frac Load Fluid
Recovery?
Robert Sage March 3, 2014
2
100%
90%
80%
70%
60%
50%
40%
30%
20%
10%
0%
0.1 1 10 100 1000
What is the Frac Load Fluid Recovery?
% O
F LO
AD F
LUID
PRODUCING DAYS Source: Don Leblanc, Eastex Petroleum Consultants Inc.
WATER
LPG Ideal
Fluid BlockEffective Fracture Length
Created Fracture Length
GAS FLOW NO GAS FLOW
Fluid BlockEffective Fracture Length
Created Fracture Length
GAS FLOW NO GAS FLOW
Current Fracturing
Hydrocarbon Flow NO Hydrocarbon Flow
Poor Frac Load Recovery
What Causes Poor Frac Load Recovery and the Resulting Short Effective Fracture Length - Water block due to Imbibition – A Function of Surface Tension - Water interaction with clays and formation minerals - Water is immiscible with Hydrocarbons ( 2 phases) - Flooding of the reservoir with water - Hydrocarbon break thru prior to total clean up
Fluid BlockEffective Fracture Length
Created Fracture Length
GAS FLOW NO GAS FLOW
Fluid BlockEffective Fracture Length
Created Fracture Length
GAS FLOW NO GAS FLOW
Effective Fracture Length
Created Fracture Length
GAS FLOW
Effective Fracture Length
Created Fracture Length
GAS FLOW
Current Fracturing Method
Ideal Fracturing Method
Hydrocarbon Flow NO Hydrocarbon Flow
Hydrocarbon Flow
Industry Issues
Case Study San Miguel Formation
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• Depth 3,750 ft
• Bottom-hole pressure of 1650 psig (.44 psi/ft)
• Bottom-hole temperature 140 degree F
• Tight oil sand gross pay of 90 ft, high porosity pay section of 27 ft.
• Perm of .05 - .10 md
• Water saturation of 45%
• Oil gravity 45 degree API, Gas is over 8 gpm
• Field has over 200 vertical wells. Average IP of 15 bpd and EUR of 15 Mbbl.
San Miguel: Comparison of Water & NGL Fracs
Water NGL
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• 4,797 bbls per stage
• 85,569 lbs. per stage
• Frac gradient .94 psi/ft
• Treating Rate 66 BPM • 9 stages per well
• 1,675 bbls per stage
• 90,924 lbs. per stage
• Frac gradient .96 psi/ft
• Treating Rate 40 BPM • 10 stages per well
San Miguel: Cumulative BOE vs Time
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0
10000
20000
30000
40000
50000
60000
0 20 40 60 80 100 120 140 160 180
BOE
Days
Gas Frac Average Water Frac Average
San Miguel: Rate vs Time
9
0
100
200
300
400
500
600
700
1 31 61 91 121 151 181 211 241 271 301 331
Avg. Rate water frac BPDe Avg. Rate NGL frac BPDe
San Miguel: Flowing Tubing Pressure
10
0
50
100
150
200
250
300
350
400
450
500
550
600
650
700
750
800
1 31 61 91 121 151 181 211 241 271 301 331
Avg. FTP Water frac psig Avg. FTP NGL frac psig
On gas lift
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Ideal Fracture Fluid: Hydrocarbons • Impact of LPG’s and Hybrid Fluids Low Viscosity, Lower Surface Tension,
Solubility/Miscibility, Lower Density (Higher Drawdowns) Leading to Higher % and Quicker Load Recovery
Advantage of LPG’s and Hybrid Hydrocarbon Fluids Properties: Leading to Higher % Recovery of in Place Hydrocarbons, Immediate Load Recovery time, production and Enhanced Oil Recovery (EOR) Low Viscosity
• Lower Surface Tension • Solubility/Miscibility in formation hydrocarbons • Lower density (Higher Drawdowns) • No interaction with formation clays or minerals
Hydrocarbons fluids can be recovered and sold for cost recovery These hydrocarbon properties can be engineered to enhance production, and facilitate recycling / cost recovery of the fracturing fluid
12
How do I make a business case for using hydrocarbon fluids as
a fracturing fluid ?
when: Water cost pennies per gallon
Hydrocarbon fluids cost dollars per gallon
A Compelling Question
San Miguel: 90,000 lb/stage Frac Economics
Water Frac NGL Frac
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Pump: $110 K Frac Fluid: $18 K H2O Transfer: $7 K Disposal: $5 K Total: $140 K/stage
Pump: $120 K Frac Fluid: $196 K Total: $316 K Recovery: ($148 K) Net Cost: $168 K/stage
San Miguel: Cost per 180 Cumulative BOE
15
$42/Cum BOE
$30/Cum BOE
$23/Cum BOE
$0
$5
$10
$15
$20
$25
$30
$35
$40
$45
$50
Water Frac NGL Frac Future NGL
San Miquel: Average IP Rate
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0
200
400
600
800
1000
1200
1400
Water Frac Propane Frac C4 + Frac Small Hybrid frac Large Hybrid Frac
Aver
age
IP (B
OE/
d) 90,000 lbs
1 well
90,000 lbs 2 wells
90,000 lbs 4 wells
90,000 lbs 4 Wells
183,000 lbs 4 wells
Is it Scalable ?
GASFRAC Experience
As of Dec 2013 : 2314 Fracs on 722 Locations Largest job to date: 2.6 MM lb, 10 + stage Highest pressure treatment to 13,050 psi (Lowest: 362 psi) Treating rates to 50 bbl/min & proppant concentrations to 8 lb/gal Oil, Gas, and Condensate wells Deepest Treatment to over 13,000 ft TVD Formation Temperatures from 54 °F to 300 °F
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Gasfrac: Focused on Safety, Engineered Hydrocarbon Fracture Fluids &
Fit for Purpose Equipment
LPG Bulkers – 500 bbl capacity Nitrogen Support
2250 HHP LPG Frac Pumpers
1 - 206,000# Proppant Blender
Typical LPG Equipment Spread
Fluid LPG 4,000 bbl (170,000 gal)
Proppant 20/40 mesh sand 200,000 lb
Pumping 11,500 HHP, 30 bpm 26
Gelled 100% LPG Fracturing Process
27
Hybrid LPG Fracturing Process LPG
Hybrid Fluid Sand
This Is Done with the Knowledge Gained from 100 % LPG Fracturing
Two Streams Commingled at the Wellhead
- LPG - Hybrid Fluid and Sand
A Scalable LPG Fracturing Process – Increase Proppant Delivery
Typical Hybrid LPG Equipment Spread
Fluid Plus 11,000 BBLs
Proppant Plus 720,000 lb
Pumping 60 bpm
Pros and Cons
More Productive Wells Provide energy to help lift frac fluid and
reservoir fluids. It does this while also remaining in liquid phase while treating the well.
Higher initial IP’s. Increased long term production. Enhanced recovery rates. Minimized flaring - immediate to gas sales. Does not cause clay swelling. Maintains higher relative permeability to oil.
Flowback Turn a liability into an asset. Engineered hydrocarbon frac per facilities. Quicker for wells to clean up. Low surface tension help during flowback.
Lower Life Cycle of Well Costs Chemical Costs – no water and no resulting
introduction of SRB’s. Pigging. Facility upsets. No investment in water handling
infrastructure, as with water fracs.
Potentially Fewer Wells Larger effective drainage area.
Low Environmental and Ecological Impact
Pros
Costs Higher AFE number for completions. Flowback – integration of flowback equipment for recovery.
Safety Concerns Built for purpose equipment. Compartmentalize and flare any problems. More redundancy and backups than with water fracs. Maintenance process to maintain equipment specifications. LEL monitors. Thermal cameras in the hot zone.
Logistics Availability of NGL frac fluids. Wellbore Configuration - open hole vs plug and perf packers. Job size.
Pros and Cons
Cons
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