Hydraulic Proppant Fracturing
Hydraulic Proppant Fracturing Klaas van Gijtenbeek Sr Tech Professional Leader Halliburton
Technical Advisory Team Presentation
Introduction
Will T Louviere quote: “To effectively and economically drain a reservoir in 5 years time the propped frac length needs to cover 50 to 70% of the drainage radius” © 2011 Halliburton. All Rights Reserved.
2
20 Rules for Gas Fracturing by Steve Holditch
Rule#9. The optimum fracture length will be a function of the (optimum) drainage area (xe). The following can be used to estimate the optimum fracture length as a function of gas permeability.
© 2011 Halliburton. All Rights Reserved.
3
20 Rules for Gas Fracturing by Steve Holditch Rule#16. The pad volume of a treatment should be • In most reservoirs 25 – 30% • In tight reservoirs 10 – 20% • In high permeability reservoirs 50 – 70% If the pad volume is too small, the treatment may screen out. If the pad volume is too large, you will waste money, the propped fracture length will be shorter, and the fracture will not close as rapidly as it would with a smaller pad volume. © 2011 Halliburton. All Rights Reserved.
4
20 Rules for Gas Fracturing by Steve Holditch
Rule#18. No well is straight and no well is vertical. As such, the chances that multiple fractures will occur increase with the length of the perforated interval. A perforation interval of 20 ft. or less, located in the most porous and permeable zone, should be sufficient for most cases. A properly packed fracture will connect the entire pay interval to the well bore assuming the treatment is pumped correctly and is not over flushed.
© 2011 Halliburton. All Rights Reserved.
5
FC vs Prop Concentration
© 2011 Halliburton. All Rights Reserved.
6
Prop Concentration
2000 lb/ per 1000 sq ft or 2 lb/ft^2 what does it mean? w
Bulk volume of sand is 100 lbs/ft^3 so 2lb/ft^2 gives 0.02 ft width or w = 0.24 in.
1 ft
How many proppant layers is that? 1 ft
© 2011 Halliburton. All Rights Reserved.
7
Prop Concentration
Properties for Various Size Proppants Proppants Size Mesh 4/8 6/12** 8/12 8/16** 10/20 10/30 12/20* 16/20** 16/30** 18/20** 18/35 20/40* 20/50 30/50** 30/60 40/60 40/70* 70/140**(100 mesh)
Maximum Diameter - Maximum Diameter - Average Proppant Diameter - Average Proppant Diameter in. mm in. mm 0.187 4.75 0.173 4.39 0.132 3.35 0.099 2.51 0.093 2.36 0.087 2.21 0.093 2.36 0.082 2.08 0.079 2.01 0.061 1.55 0.079 2.01 0.056 1.42 0.067 1.70 0.054 1.37 0.047 1.19 0.041 1.04 0.047 1.19 0.039 0.99 0.039 0.99 0.036 0.91 0.039 0.99 0.032 0.81 0.0336 0.85 0.0272 0.69 0.0336 0.85 0.0218 0.55 0.0237 0.60 0.0185 0.47 0.0237 0.60 0.018 0.46 0.0168 0.43 0.014 0.36 0.0168 0.43 0.013 0.33 0.0099 0.25 0.0084 0.21
*Recognized by API as a primary proppant size **Recognized by API as an alternate proppant
© 2011 Halliburton. All Rights Reserved.
8
Prop Concentration Bulk volume of sand is 100 lbs/ft^3 so 2lb/ft^2 gives 0.02 ft width or w = 0.24 in.
2 lb/ft^2 what does it mean? w
How many proppant layers is that? 0.24 / 0.0272 = 8.8 ! 1 ft
1 ft
© 2011 Halliburton. All Rights Reserved.
That is equivalent to 1.712.802 proppant grains, or 1.88 million grains in a kilo.....so next time that you go to the beach..... 9
FC vs Prop Concentration
0.5 partial mono layer 8.8 layer
© 2011 Halliburton. All Rights Reserved.
10
Perforation Diameter based on Max Proppant Diameter (6:1 ratio)
© 2011 Halliburton. All Rights Reserved.
11
Perforation Diameter based on Max Proppant Diameter (6:1 ratio)
© 2011 Halliburton. All Rights Reserved.
12
Frac Geometry Example 2 lb/ft^2
S = 80 acres
50 ft
500 ft Area = 2 wings * 50’ * 500’ = 50,000 ft^2
500 ft
Proppant Amount Required: 50,000 ft^2 * 2 lb/ft^2 = 100,000 lbs © 2011 Halliburton. All Rights Reserved.
13
Well Spacing and Drainage Radius
Square Well Spacing (S) in Acres Drainage Length (Re) in ft 40 80 160 320 640
© 2011 Halliburton. All Rights Reserved.
Circular Drainage Radius (Re) in ft
Re = 104.4*S^0.5
Re = 117.8*S^0.5
660 933 1,320 1,867 2,641
745 1,053 1,490 2,107 2,980
14
Frac Schedule 100,000 lbs of proppant required Assume 4 lbs/gal average concentration 25,000 gal fluid required for proppant Pad volume: 10,000 gal S-shape proppant addition curve (to reduce NWB and avoid proppant convection) 10,000 gal w/ 1 ppg-10,000 lbs stage 2,000 gal w/ 2 pgg-4,000 lbs stage 1,500 gal w/ 3 ppg-4,500 lbs stage 1,000 gal w/ 4 ppg-4,000 lbs stage 1,000 gal w/ 5 ppg-5,000 lbs stage 2,000 gal w/ 6 ppg-12,000 lbs stage 3,000 gal w/ 7 ppg-21,000 lbs stage 5,000 gal w/ 8 ppg-40,000 lbs stage
© 2011 Halliburton. All Rights Reserved.
15
Frac Schedule Pump Rate Pump rate depends on: 1) Completion. Check minimum ID’s in wellbore and try to keep velocity below 44 ft/sec. This is based on yardtests. We are using 20 ft/sec when pumping proppant on the outside of coil. In general 35/ft/sec is ok. 2) Available equipment. Maximum rate through surface lines is 2*ID^2. So, 3” is 18 bpm, 4” is 32 bpm etc. 3) Pressure rating. WHTP = BHTP-Hydrostatic+Friction Hydraulic Horsepower: (Max WHTP*Design rate)/40.8 = 4411hhp for 10,000 psi and 18 bpm
© 2011 Halliburton. All Rights Reserved.
16
Frac Schedule Pump Rate There are some velocity guidelines for Wellhead Isolation Tools/Tree Savers. To minimize the risk of excessive tubing wear, restrict velocity through the tool to the rates listed below for each material. Sand-laden fluids ................................... 125 ft/sec Clean fluids ........................................... 200 ft/sec High-strength proppant .......................... 100 ft/sec Foamed fluid with sand ........................... 100 ft/sec Foamed fluid with high-strength proppant ... 80 ft/sec These values are for reference only if proppant concentration does not exceed 8 lb/gal or 6 lb/gal with foam.
© 2011 Halliburton. All Rights Reserved.
17
Frac Schedule Pump rate
V=(17.157* Q)/ID^2, where V velocity (ft/sec) Q pump rate (bbl/min) ID internal diameter of inner mandrel (in.) Sand Laden Fluid through 2.922 in tubing: Q =(2.922^2 * 125)/17.157 = 62.2 bpm With 35 ft/sec this would be: 17.4 bpm, so a design rate of 17 to 18 bpm for 3.5” tubing is ok.
© 2011 Halliburton. All Rights Reserved.
18
Production Increase Curves
Flow capacity: 2800 md-ft Ki =0.1 mD Cr = 17.8 ->Y-axis: 4.2 Jfs/Ji = (4.2 * ln(1053/.375))/6.215 = 5.36 © 2011 Halliburton. All Rights Reserved.
19
Frac Schedule other Considerations 1) DFIT: Diagnostic Fluid Injection test 2) Minifrac using linear gel and Stepdown Rate test 3) Minifrac using gel for mainfrac and proppant slug
© 2011 Halliburton. All Rights Reserved.
20
Layout – All Water in Tanks prior to job start
© 2011 Halliburton. All Rights Reserved.
21
Production Enhancement Equipment Available out of Celle Base Description
Quantity
2000 HHP Grizzly Pump Trailer 2000 HHP HQ Twin Pump Trailer 100 bpm ARC Blender 50 bpm ARC Blender 100 bpm ARC Pre Gel Blender 50 bpm ARC Pre Gel Blender Technical Command Center with RTO & Field Lab 80 m³ Fluid Storage Tank 60 m³ Liquid KCL Storage Tank 60 m³ Proppant Silo 34 m³ Proppant Silo 1000 HHP Annulus Truck ( HT 400 ) 600 HHP Annulus Truck ( HT 400 ) 60 / 80 k Coiled Tubing Unit 1 3/4”-2 3/8” 38 k Coiled Tubing Unit 2000 scf/min N2 Unit 3000 scf/min N2 Unit 6000 scf/min N2 Unit 2500 kw Mobile Fluid Heating Unit
© 2011 Halliburton. All Rights Reserved.
22
10 2 1 1 1 1 2 12 2 2 2 2 2 3 1 2 1 2 1
2000 HHP Grizzly Pump Trailer
© 2011 Halliburton. All Rights Reserved.
23
Pumprate vs pressure, 4" FE, HQ-Pump Gear
Minimum bpm
Maximum bpm
P Rating psi
Minimum m³/min
Maximum m³/min
P Rating bar
1 2 3 4 5
2,6 4,8 6,6 8,5 11,2
3,6 6,6 9 11,7 15,3
14200 7201 5294 4066 3086
0,41 0,76 1,05 1,35 1,78
0,57 1,05 1,43 1,86 2,43
979,3 496,6 365,1 280,4 212,8
Pumprate vs pressure, 4" FE, Grizzley-Pump
© 2011 Halliburton. All Rights Reserved.
Gang
Minimum bpm
Maximum bpm
P Rating psi
Minimum m³/min
Maximum m³/min
P Rating bar
1 2 3 4 5 6 7
3,1 4,7 5,7 7 8 9,8 12,3
4,3 5,9 7,3 9,1 10,1 12,6 16
14200 14200 11917 9572 8403 6803 5476
0,48 0,75 0,9 1,11 1,27 1,55 1,95
0,68 0,94 1,15 1,44 1,6 2 2,54
979,3 979,3 821,9 660,1 579,5 469,2 377,7
24
100 bpm ARC Pre Gel Blender Mixing system: Two Gorman/Rupp 12 x 12 centrifugal pumps, hydraulically driven. The mixing system is capable of mixing at rates up to 100 bbl/min (15.9 m3/min). Engine: CAT C11 diesel engine (420 HP at 2100 rpm) or equivalent driving four hydraulic pumps through a four-pump drive gearbox Dimensions: Length: 13.39 mtr Width: 2.44 mtr Height: 4.11 mtr Weight: 22 200 kg
© 2011 Halliburton. All Rights Reserved.
25
100 bpm ARC Blender
© 2011 Halliburton. All Rights Reserved.
26
Frac Van
© 2011 Halliburton. All Rights Reserved.
27
Fluid Storage Description: Tank Trailer
Capabilities Manifold:
Capacity: Volume:
80m³
Mixline: 4” Size: 10” with 4 each outlets with 4” fig 206 weco unions Jeager air connection: to connect multiple tanks in one common manifold
Dimensions: Weight: Height: Width: Length:
12,300 Kg 4,00 mtr 2,50 mtr 13,10 mtr
© 2011 Halliburton. All Rights Reserved.
28
Proppant Silo Description: 34 m3 Sand Silo 60 m³ Sand Silo
© 2011 Halliburton. All Rights Reserved.
Dimensions: 34 m3 Weight: Height: Width: Length:
6.500 Kg 9,00 mtr 2,44 mtr 2,80 mtr
29
60 m³ 7.500 Kg 13,12 mtr 2,50 mtr 2,56 mtr
Mounted Equipment Description: 15,000 psi Manifold Trailer ( Connects 16 Pumps )
Capacity: 50,000 lb (22 676 kg) lift for positioning trailer for hookup and/or disconnect from tractor Stroke: 36 in. (914 mm)
© 2011 Halliburton. All Rights Reserved.
30
60 – 100K Coiled Tubing Unit 1 1/4”-2 3/8” Capacity: Tubing OD Range: Hydr. Pressure: Max. Pull Max. Push
1.25” – 2 3/8” 5000 psi 60 000 lbs 30 000 lbs
Dimensions: 60k Weight: 48,000 Kg Height: 4,10 mtr Width: 2,55 mtr Length: 13,30 mtr
© 2011 Halliburton. All Rights Reserved.
1.50” – 2 3/8” 5000 psi 100,000 lbs 45,000 lbs
100k 48,000 Kg 4,10 mtr 2,55 mtr 13,30 mtr
31
Transverse CT Reel 2 3/8” CT Total length 7200 mtr
© 2011 Halliburton. All Rights Reserved.
32
2500KW Heating Unit Capable to heat 80m3 water from 5C to 50C in 1hour 15min Diesel usage ca 200ltr/hour
© 2011 Halliburton. All Rights Reserved.
34
Multi Purpose Twin Pump Unit
© 2011 Halliburton. All Rights Reserved.
35
Skandi Fjord – Stimulation Vessel
© 2011 Halliburton. All Rights Reserved.
36
Frac Schedule 100,000 lbs of proppant required Assume 4 lbs/gal average concentration 25,000 gal fluid required for proppant Pad volume: 10,000 gal S-shape proppant addition curve (to reduce NWB and avoid proppant convection) 10,000 gal w/ 1 ppg-10,000 lbs stage 2,000 gal w/ 2 pgg-4,000 lbs stage 1,500 gal w/ 3 ppg-4,500 lbs stage 1,000 gal w/ 4 ppg-4,000 lbs stage 1,000 gal w/ 5 ppg-5,000 lbs stage 2,000 gal w/ 6 ppg-12,000 lbs stage 3,000 gal w/ 7 ppg-21,000 lbs stage 5,000 gal w/ 8 ppg-40,000 lbs stage
© 2011 Halliburton. All Rights Reserved.
37
Model Input
© 2011 Halliburton. All Rights Reserved.
38
Model Output Fracture Half-Length (ft) Total Fracture Height (ft) Depth to Fracture Top (ft) Depth to Fracture Bottom (ft) Equivalent Number of Multiple Fracs Fracture Slurry Efficiency**
530 108 9551 9659 1.0 0.44
Propped Half-Length (ft) Total Propped Height (ft) Depth to Propped Fracture Top (ft) Depth to Propped Fracture Bottom (ft) Max. Fracture Width (in) Avg. Fracture Width (in) Avg. Proppant Concentration (lb/ft²)
500 102 9557 9659 0.35 0.20 1.28
Model Net Pressure** (psi) Observed Net Pressure** (psi) Hydrostatic Head*** (psi) Reservoir Pressure (psi)
2364 0 4144 4180
BH Fracture Closure Stress (psi) Closure Stress Gradient (psi/ft) Avg. Surface Pressure (psi) Max. Surface Pressure (psi)
5961 0.620 6234 6775
Total Clean Fluid Pumped (bbls) Total Slurry Pumped (bbls) Pad Volume (bbls) Pad Fraction (% of Slurry Vol)** Pad Fraction (% of Clean Vol)** Primary Fluid Type
954.5 1062.2 238.1 24.3 27.4 HYBOR H 30# WG-11
Secondary Fluid Type © 2011 Halliburton. All Rights Reserved.
Total Proppant Pumped (klbs) 103.9 Total Proppant in Fracture (klbs) 102.8 Avg. Hydraulic Horsepower (hp) 2747 Max. Hydraulic Horsepower (hp) 2985 Avg Btm Slurry Rate (bpm) 18.1 Primary Proppant Type CarboLite 16/20 Secondary Proppant Type
39
Frac Geometry
© 2011 Halliburton. All Rights Reserved.
40
Treatment Parameters
© 2011 Halliburton. All Rights Reserved.
41
© 2011 Halliburton. All Rights Reserved.
42
Technical Advisory Team Presentation
Introduction
Will T Louviere quote: “To effectively and economically drain a reservoir in 5 years time the propped frac length needs to cover 50 to 70% of the drainage radius” © 2011 Halliburton. All Rights Reserved.
2
20 Rules for Gas Fracturing by Steve Holditch
Rule#9. The optimum fracture length will be a function of the (optimum) drainage area (xe). The following can be used to estimate the optimum fracture length as a function of gas permeability.
© 2011 Halliburton. All Rights Reserved.
3
20 Rules for Gas Fracturing by Steve Holditch Rule#16. The pad volume of a treatment should be • In most reservoirs 25 – 30% • In tight reservoirs 10 – 20% • In high permeability reservoirs 50 – 70% If the pad volume is too small, the treatment may screen out. If the pad volume is too large, you will waste money, the propped fracture length will be shorter, and the fracture will not close as rapidly as it would with a smaller pad volume. © 2011 Halliburton. All Rights Reserved.
4
20 Rules for Gas Fracturing by Steve Holditch
Rule#18. No well is straight and no well is vertical. As such, the chances that multiple fractures will occur increase with the length of the perforated interval. A perforation interval of 20 ft. or less, located in the most porous and permeable zone, should be sufficient for most cases. A properly packed fracture will connect the entire pay interval to the well bore assuming the treatment is pumped correctly and is not over flushed.
© 2011 Halliburton. All Rights Reserved.
5
FC vs Prop Concentration
© 2011 Halliburton. All Rights Reserved.
6
Prop Concentration
2000 lb/ per 1000 sq ft or 2 lb/ft^2 what does it mean? w
Bulk volume of sand is 100 lbs/ft^3 so 2lb/ft^2 gives 0.02 ft width or w = 0.24 in.
1 ft
How many proppant layers is that? 1 ft
© 2011 Halliburton. All Rights Reserved.
7
Prop Concentration
Properties for Various Size Proppants Proppants Size Mesh 4/8 6/12** 8/12 8/16** 10/20 10/30 12/20* 16/20** 16/30** 18/20** 18/35 20/40* 20/50 30/50** 30/60 40/60 40/70* 70/140**(100 mesh)
Maximum Diameter - Maximum Diameter - Average Proppant Diameter - Average Proppant Diameter in. mm in. mm 0.187 4.75 0.173 4.39 0.132 3.35 0.099 2.51 0.093 2.36 0.087 2.21 0.093 2.36 0.082 2.08 0.079 2.01 0.061 1.55 0.079 2.01 0.056 1.42 0.067 1.70 0.054 1.37 0.047 1.19 0.041 1.04 0.047 1.19 0.039 0.99 0.039 0.99 0.036 0.91 0.039 0.99 0.032 0.81 0.0336 0.85 0.0272 0.69 0.0336 0.85 0.0218 0.55 0.0237 0.60 0.0185 0.47 0.0237 0.60 0.018 0.46 0.0168 0.43 0.014 0.36 0.0168 0.43 0.013 0.33 0.0099 0.25 0.0084 0.21
*Recognized by API as a primary proppant size **Recognized by API as an alternate proppant
© 2011 Halliburton. All Rights Reserved.
8
Prop Concentration Bulk volume of sand is 100 lbs/ft^3 so 2lb/ft^2 gives 0.02 ft width or w = 0.24 in.
2 lb/ft^2 what does it mean? w
How many proppant layers is that? 0.24 / 0.0272 = 8.8 ! 1 ft
1 ft
© 2011 Halliburton. All Rights Reserved.
That is equivalent to 1.712.802 proppant grains, or 1.88 million grains in a kilo.....so next time that you go to the beach..... 9
FC vs Prop Concentration
0.5 partial mono layer 8.8 layer
© 2011 Halliburton. All Rights Reserved.
10
Perforation Diameter based on Max Proppant Diameter (6:1 ratio)
© 2011 Halliburton. All Rights Reserved.
11
Perforation Diameter based on Max Proppant Diameter (6:1 ratio)
© 2011 Halliburton. All Rights Reserved.
12
Frac Geometry Example 2 lb/ft^2
S = 80 acres
50 ft
500 ft Area = 2 wings * 50’ * 500’ = 50,000 ft^2
500 ft
Proppant Amount Required: 50,000 ft^2 * 2 lb/ft^2 = 100,000 lbs © 2011 Halliburton. All Rights Reserved.
13
Well Spacing and Drainage Radius
Square Well Spacing (S) in Acres Drainage Length (Re) in ft 40 80 160 320 640
© 2011 Halliburton. All Rights Reserved.
Circular Drainage Radius (Re) in ft
Re = 104.4*S^0.5
Re = 117.8*S^0.5
660 933 1,320 1,867 2,641
745 1,053 1,490 2,107 2,980
14
Frac Schedule 100,000 lbs of proppant required Assume 4 lbs/gal average concentration 25,000 gal fluid required for proppant Pad volume: 10,000 gal S-shape proppant addition curve (to reduce NWB and avoid proppant convection) 10,000 gal w/ 1 ppg-10,000 lbs stage 2,000 gal w/ 2 pgg-4,000 lbs stage 1,500 gal w/ 3 ppg-4,500 lbs stage 1,000 gal w/ 4 ppg-4,000 lbs stage 1,000 gal w/ 5 ppg-5,000 lbs stage 2,000 gal w/ 6 ppg-12,000 lbs stage 3,000 gal w/ 7 ppg-21,000 lbs stage 5,000 gal w/ 8 ppg-40,000 lbs stage
© 2011 Halliburton. All Rights Reserved.
15
Frac Schedule Pump Rate Pump rate depends on: 1) Completion. Check minimum ID’s in wellbore and try to keep velocity below 44 ft/sec. This is based on yardtests. We are using 20 ft/sec when pumping proppant on the outside of coil. In general 35/ft/sec is ok. 2) Available equipment. Maximum rate through surface lines is 2*ID^2. So, 3” is 18 bpm, 4” is 32 bpm etc. 3) Pressure rating. WHTP = BHTP-Hydrostatic+Friction Hydraulic Horsepower: (Max WHTP*Design rate)/40.8 = 4411hhp for 10,000 psi and 18 bpm
© 2011 Halliburton. All Rights Reserved.
16
Frac Schedule Pump Rate There are some velocity guidelines for Wellhead Isolation Tools/Tree Savers. To minimize the risk of excessive tubing wear, restrict velocity through the tool to the rates listed below for each material. Sand-laden fluids ................................... 125 ft/sec Clean fluids ........................................... 200 ft/sec High-strength proppant .......................... 100 ft/sec Foamed fluid with sand ........................... 100 ft/sec Foamed fluid with high-strength proppant ... 80 ft/sec These values are for reference only if proppant concentration does not exceed 8 lb/gal or 6 lb/gal with foam.
© 2011 Halliburton. All Rights Reserved.
17
Frac Schedule Pump rate
V=(17.157* Q)/ID^2, where V velocity (ft/sec) Q pump rate (bbl/min) ID internal diameter of inner mandrel (in.) Sand Laden Fluid through 2.922 in tubing: Q =(2.922^2 * 125)/17.157 = 62.2 bpm With 35 ft/sec this would be: 17.4 bpm, so a design rate of 17 to 18 bpm for 3.5” tubing is ok.
© 2011 Halliburton. All Rights Reserved.
18
Production Increase Curves
Flow capacity: 2800 md-ft Ki =0.1 mD Cr = 17.8 ->Y-axis: 4.2 Jfs/Ji = (4.2 * ln(1053/.375))/6.215 = 5.36 © 2011 Halliburton. All Rights Reserved.
19
Frac Schedule other Considerations 1) DFIT: Diagnostic Fluid Injection test 2) Minifrac using linear gel and Stepdown Rate test 3) Minifrac using gel for mainfrac and proppant slug
© 2011 Halliburton. All Rights Reserved.
20
Layout – All Water in Tanks prior to job start
© 2011 Halliburton. All Rights Reserved.
21
Production Enhancement Equipment Available out of Celle Base Description
Quantity
2000 HHP Grizzly Pump Trailer 2000 HHP HQ Twin Pump Trailer 100 bpm ARC Blender 50 bpm ARC Blender 100 bpm ARC Pre Gel Blender 50 bpm ARC Pre Gel Blender Technical Command Center with RTO & Field Lab 80 m³ Fluid Storage Tank 60 m³ Liquid KCL Storage Tank 60 m³ Proppant Silo 34 m³ Proppant Silo 1000 HHP Annulus Truck ( HT 400 ) 600 HHP Annulus Truck ( HT 400 ) 60 / 80 k Coiled Tubing Unit 1 3/4”-2 3/8” 38 k Coiled Tubing Unit 2000 scf/min N2 Unit 3000 scf/min N2 Unit 6000 scf/min N2 Unit 2500 kw Mobile Fluid Heating Unit
© 2011 Halliburton. All Rights Reserved.
22
10 2 1 1 1 1 2 12 2 2 2 2 2 3 1 2 1 2 1
2000 HHP Grizzly Pump Trailer
© 2011 Halliburton. All Rights Reserved.
23
Pumprate vs pressure, 4" FE, HQ-Pump Gear
Minimum bpm
Maximum bpm
P Rating psi
Minimum m³/min
Maximum m³/min
P Rating bar
1 2 3 4 5
2,6 4,8 6,6 8,5 11,2
3,6 6,6 9 11,7 15,3
14200 7201 5294 4066 3086
0,41 0,76 1,05 1,35 1,78
0,57 1,05 1,43 1,86 2,43
979,3 496,6 365,1 280,4 212,8
Pumprate vs pressure, 4" FE, Grizzley-Pump
© 2011 Halliburton. All Rights Reserved.
Gang
Minimum bpm
Maximum bpm
P Rating psi
Minimum m³/min
Maximum m³/min
P Rating bar
1 2 3 4 5 6 7
3,1 4,7 5,7 7 8 9,8 12,3
4,3 5,9 7,3 9,1 10,1 12,6 16
14200 14200 11917 9572 8403 6803 5476
0,48 0,75 0,9 1,11 1,27 1,55 1,95
0,68 0,94 1,15 1,44 1,6 2 2,54
979,3 979,3 821,9 660,1 579,5 469,2 377,7
24
100 bpm ARC Pre Gel Blender Mixing system: Two Gorman/Rupp 12 x 12 centrifugal pumps, hydraulically driven. The mixing system is capable of mixing at rates up to 100 bbl/min (15.9 m3/min). Engine: CAT C11 diesel engine (420 HP at 2100 rpm) or equivalent driving four hydraulic pumps through a four-pump drive gearbox Dimensions: Length: 13.39 mtr Width: 2.44 mtr Height: 4.11 mtr Weight: 22 200 kg
© 2011 Halliburton. All Rights Reserved.
25
100 bpm ARC Blender
© 2011 Halliburton. All Rights Reserved.
26
Frac Van
© 2011 Halliburton. All Rights Reserved.
27
Fluid Storage Description: Tank Trailer
Capabilities Manifold:
Capacity: Volume:
80m³
Mixline: 4” Size: 10” with 4 each outlets with 4” fig 206 weco unions Jeager air connection: to connect multiple tanks in one common manifold
Dimensions: Weight: Height: Width: Length:
12,300 Kg 4,00 mtr 2,50 mtr 13,10 mtr
© 2011 Halliburton. All Rights Reserved.
28
Proppant Silo Description: 34 m3 Sand Silo 60 m³ Sand Silo
© 2011 Halliburton. All Rights Reserved.
Dimensions: 34 m3 Weight: Height: Width: Length:
6.500 Kg 9,00 mtr 2,44 mtr 2,80 mtr
29
60 m³ 7.500 Kg 13,12 mtr 2,50 mtr 2,56 mtr
Mounted Equipment Description: 15,000 psi Manifold Trailer ( Connects 16 Pumps )
Capacity: 50,000 lb (22 676 kg) lift for positioning trailer for hookup and/or disconnect from tractor Stroke: 36 in. (914 mm)
© 2011 Halliburton. All Rights Reserved.
30
60 – 100K Coiled Tubing Unit 1 1/4”-2 3/8” Capacity: Tubing OD Range: Hydr. Pressure: Max. Pull Max. Push
1.25” – 2 3/8” 5000 psi 60 000 lbs 30 000 lbs
Dimensions: 60k Weight: 48,000 Kg Height: 4,10 mtr Width: 2,55 mtr Length: 13,30 mtr
© 2011 Halliburton. All Rights Reserved.
1.50” – 2 3/8” 5000 psi 100,000 lbs 45,000 lbs
100k 48,000 Kg 4,10 mtr 2,55 mtr 13,30 mtr
31
Transverse CT Reel 2 3/8” CT Total length 7200 mtr
© 2011 Halliburton. All Rights Reserved.
32
2500KW Heating Unit Capable to heat 80m3 water from 5C to 50C in 1hour 15min Diesel usage ca 200ltr/hour
© 2011 Halliburton. All Rights Reserved.
34
Multi Purpose Twin Pump Unit
© 2011 Halliburton. All Rights Reserved.
35
Skandi Fjord – Stimulation Vessel
© 2011 Halliburton. All Rights Reserved.
36
Frac Schedule 100,000 lbs of proppant required Assume 4 lbs/gal average concentration 25,000 gal fluid required for proppant Pad volume: 10,000 gal S-shape proppant addition curve (to reduce NWB and avoid proppant convection) 10,000 gal w/ 1 ppg-10,000 lbs stage 2,000 gal w/ 2 pgg-4,000 lbs stage 1,500 gal w/ 3 ppg-4,500 lbs stage 1,000 gal w/ 4 ppg-4,000 lbs stage 1,000 gal w/ 5 ppg-5,000 lbs stage 2,000 gal w/ 6 ppg-12,000 lbs stage 3,000 gal w/ 7 ppg-21,000 lbs stage 5,000 gal w/ 8 ppg-40,000 lbs stage
© 2011 Halliburton. All Rights Reserved.
37
Model Input
© 2011 Halliburton. All Rights Reserved.
38
Model Output Fracture Half-Length (ft) Total Fracture Height (ft) Depth to Fracture Top (ft) Depth to Fracture Bottom (ft) Equivalent Number of Multiple Fracs Fracture Slurry Efficiency**
530 108 9551 9659 1.0 0.44
Propped Half-Length (ft) Total Propped Height (ft) Depth to Propped Fracture Top (ft) Depth to Propped Fracture Bottom (ft) Max. Fracture Width (in) Avg. Fracture Width (in) Avg. Proppant Concentration (lb/ft²)
500 102 9557 9659 0.35 0.20 1.28
Model Net Pressure** (psi) Observed Net Pressure** (psi) Hydrostatic Head*** (psi) Reservoir Pressure (psi)
2364 0 4144 4180
BH Fracture Closure Stress (psi) Closure Stress Gradient (psi/ft) Avg. Surface Pressure (psi) Max. Surface Pressure (psi)
5961 0.620 6234 6775
Total Clean Fluid Pumped (bbls) Total Slurry Pumped (bbls) Pad Volume (bbls) Pad Fraction (% of Slurry Vol)** Pad Fraction (% of Clean Vol)** Primary Fluid Type
954.5 1062.2 238.1 24.3 27.4 HYBOR H 30# WG-11
Secondary Fluid Type © 2011 Halliburton. All Rights Reserved.
Total Proppant Pumped (klbs) 103.9 Total Proppant in Fracture (klbs) 102.8 Avg. Hydraulic Horsepower (hp) 2747 Max. Hydraulic Horsepower (hp) 2985 Avg Btm Slurry Rate (bpm) 18.1 Primary Proppant Type CarboLite 16/20 Secondary Proppant Type
39
Frac Geometry
© 2011 Halliburton. All Rights Reserved.
40
Treatment Parameters
© 2011 Halliburton. All Rights Reserved.
41
© 2011 Halliburton. All Rights Reserved.
42
