Top Banner
Well Well Number Engineer Date Economic Data Frac Fluid Unit Cost Proppant Unit Cost Fixed Equipment Cost Workover Cost Unit Revenue for Production Oil/Gas Revenue Escalation Rate Discount Rate Time Period Frac Costs Frac Fluid Frac Prop Size Volume Cost (Tonnes) (m³) (€) Base 0 0 0 Scenario 1 T 0.00 Scenario 2 T 0.00 Scenario 3 T 0.00 Scenario 4 T 0.00 Scenario 5 T 0.00 Scenario 6 T 0.00 Scenario 7 T 0.00 Scenario 8 T 0.00 Scenario 9 T 0.00 Scenario 10 T 0.00 USER GRAPH 8.00 10.00 12.00 years NPV
93

NPV_Gas_Apr 1_2011

Jul 18, 2016

Download

Documents

Mayer
Welcome message from author
This document is posted to help you gain knowledge. Please leave a comment to let me know what you think about it! Share it to your friends and learn new things together.
Transcript
Page 1: NPV_Gas_Apr 1_2011

WellWell NumberEngineerDate

Economic DataFrac Fluid Unit CostProppant Unit CostFixed Equipment CostWorkover CostUnit Revenue for Production Oil/GasRevenue Escalation RateDiscount RateTime Period

Frac CostsFrac Fluid Frac PropSize Volume Cost

(Tonnes) (m³) (€)Base 0 0 0Scenario 1 T 0.00Scenario 2 T 0.00Scenario 3 T 0.00Scenario 4 T 0.00Scenario 5 T 0.00Scenario 6 T 0.00Scenario 7 T 0.00Scenario 8 T 0.00Scenario 9 T 0.00Scenario 10 T 0.00

USER GRAPH

0 2 4 6 8 10 120.00

2.00

4.00

6.00

8.00

10.00

12.00 years

Frac Size (tonnes)

NP

V

Page 2: NPV_Gas_Apr 1_2011

CHART 1

0 2 4 6 8 10 120.00

2.00

4.00

6.00

8.00

10.00

12.00 years

Frac Size (tonnes)

NP

V

Page 3: NPV_Gas_Apr 1_2011

Economics 1170 ron / t Merisani Oil Adrian M. Feb 10, 2011Net Price 500 ron / 1000 m3 Merisani Gas

Reservoir Data€/m³ Formation€/kg Reservoir Fluid€ Bottomhole Temp€ Reservoir Btm Pressure€/m³ Reservoir Drainage area% Porosity% Permeabilityyears Water Saturation

Gas Specific Gravity

Frac Fluid Frac Cost Initial Propped Upper ProppedCost Investment Length Height(€) (€) (€) (m) (m)0 0 0 0 0

0.00 0.00 0.000.00 0.00 0.000.00 0.00 0.000.00 0.00 0.000.00 0.00 0.000.00 0.00 0.000.00 0.00 0.000.00 0.00 0.000.00 0.00 0.000.00 0.00 0.00

0 2 4 6 8 10 120.00

2.00

4.00

6.00

8.00

10.00

12.00 years

Frac Size (tonnes)

NP

V

0 2 4 6 8 10 120

2

4

6

8

10

12 Net Present Value Tonnes

Days

NP

V

Page 4: NPV_Gas_Apr 1_2011

CHART 1

0 2 4 6 8 10 120.00

2.00

4.00

6.00

8.00

10.00

12.00 years

Frac Size (tonnes)

NP

V

0 2 4 6 8 10 120

2

4

6

8

10

12 Net Present Value Tonnes

Days

NP

V

Page 5: NPV_Gas_Apr 1_2011

Top BottomPerforation Intervals

Oil/Gas/Water°Cbarha% TVD Top PerforationmD Net Pay Height%

Lower Propped Avg. Propped Fcd Cumulative Net Height Width Production Production

(m) (mm) (m³) (m³)0 0 0 0 0

0 00 00 00 00 00 00 00 00 00 0

Recommended frac size (tonnnes):Time to Recover Initial Investment (days):

NPV Rt/(1+i)^twheret = the time of the cash flowi = the discount rate (the rate of return that could be earned on an investment in the financial markets with similar risk)Rt = the net cash flow (the amount of cash, inflow minus outflow) at time t. For educational purposes, Ro is commonly placed to the left of the sum to emphasize its role as (minus) the investment

0 2 4 6 8 10 120

2

4

6

8

10

12 Net Present Value Tonnes

Days

NP

V

Page 6: NPV_Gas_Apr 1_2011

Net Present Value Tonnes

CHART 2

0 2 4 6 8 10 120

2

4

6

8

10

12 Net Present Value Tonnes

Days

NP

V

Page 7: NPV_Gas_Apr 1_2011

m Fluid Systemm Gel Loading kg/m3m Proppantm Proppant Size Mesh

mm

Net NPVValue years

(€) (€)0 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.00

i = the discount rate (the rate of return that could be earned on an investment in the financial markets with similar risk)Rt = the net cash flow (the amount of cash, inflow minus outflow) at time t. For educational purposes, Ro is commonly placed to the left of the sum to emphasize its role as (minus) the investment

0 2 4 6 8 10 120

2

4

6

8

10

12 Net Present Value Tonnes

Days

NP

V

Page 8: NPV_Gas_Apr 1_2011

CHART 2

0 2 4 6 8 10 120

2

4

6

8

10

12 Net Present Value Tonnes

Days

NP

V

Page 9: NPV_Gas_Apr 1_2011

Rt = the net cash flow (the amount of cash, inflow minus outflow) at time t. For educational purposes, Ro is commonly placed to the left of the sum to emphasize its role as (minus) the investment

Page 10: NPV_Gas_Apr 1_2011
Page 11: NPV_Gas_Apr 1_2011

BASETime Flow Rate Cum. Prod. Cum. Prod.

(d) (sm^3/d) (10^6 m^3) (%GIP) (bar) (bar) (J/Jo(t)) (J/Jo|avg)

Average Pressure

Flowing Pressure

Prod. Ratio Q/Qbase

Prod. Ratio V/Vbase

Page 12: NPV_Gas_Apr 1_2011
Page 13: NPV_Gas_Apr 1_2011
Page 14: NPV_Gas_Apr 1_2011
Page 15: NPV_Gas_Apr 1_2011

0

BASE

Page 16: NPV_Gas_Apr 1_2011

1Time Flow Rate Cum. Prod. Cum. Prod.

(d) (sm^3/d) (10^6 m^3) (%GIP) (bar) (bar) (J/Jo(t))

Average Pressure

Flowing Pressure

Prod. Ratio Q/Qbase

Page 17: NPV_Gas_Apr 1_2011
Page 18: NPV_Gas_Apr 1_2011
Page 19: NPV_Gas_Apr 1_2011
Page 20: NPV_Gas_Apr 1_2011

0

1

Page 21: NPV_Gas_Apr 1_2011

1 2Time Flow Rate Cum. Prod. Cum. Prod.

(J/Jo|avg) (d) (sm^3/d) (10^6 m^3) (%GIP) (bar) (bar)

Prod. Ratio V/Vbase

Average Pressure

Flowing Pressure

Page 22: NPV_Gas_Apr 1_2011
Page 23: NPV_Gas_Apr 1_2011
Page 24: NPV_Gas_Apr 1_2011
Page 25: NPV_Gas_Apr 1_2011

0

1 2

Page 26: NPV_Gas_Apr 1_2011

2 3Time Flow Rate Cum. Prod. Cum. Prod.

(J/Jo(t)) (J/Jo|avg) (d) (sm^3/d) (10^6 m^3) (%GIP) (bar)

Prod. Ratio Q/Qbase

Prod. Ratio V/Vbase

Average Pressure

Page 27: NPV_Gas_Apr 1_2011
Page 28: NPV_Gas_Apr 1_2011
Page 29: NPV_Gas_Apr 1_2011
Page 30: NPV_Gas_Apr 1_2011

0

2 3

Page 31: NPV_Gas_Apr 1_2011

3 4Time Flow Rate Cum. Prod. Cum. Prod.

(bar) (J/Jo(t)) (J/Jo|avg) (d) (sm^3/d) (10^6 m^3) (%GIP)

Flowing Pressure

Prod. Ratio Q/Qbase

Prod. Ratio V/Vbase

Page 32: NPV_Gas_Apr 1_2011
Page 33: NPV_Gas_Apr 1_2011
Page 34: NPV_Gas_Apr 1_2011
Page 35: NPV_Gas_Apr 1_2011

0

3 4

Page 36: NPV_Gas_Apr 1_2011

4 5Time Flow Rate Cum. Prod.

(bar) (bar) (J/Jo(t)) (J/Jo|avg) (d) (sm^3/d) (10^6 m^3)

Average Pressure

Flowing Pressure

Prod. Ratio Q/Qbase

Prod. Ratio V/Vbase

Page 37: NPV_Gas_Apr 1_2011
Page 38: NPV_Gas_Apr 1_2011
Page 39: NPV_Gas_Apr 1_2011
Page 40: NPV_Gas_Apr 1_2011

0

4 5

Page 41: NPV_Gas_Apr 1_2011

5 6Cum. Prod. Time Flow Rate

(%GIP) (bar) (bar) (J/Jo(t)) (J/Jo|avg) (d) (sm^3/d)

Average Pressure

Flowing Pressure

Prod. Ratio Q/Qbase

Prod. Ratio V/Vbase

Page 42: NPV_Gas_Apr 1_2011
Page 43: NPV_Gas_Apr 1_2011
Page 44: NPV_Gas_Apr 1_2011
Page 45: NPV_Gas_Apr 1_2011

5 6

Page 46: NPV_Gas_Apr 1_2011

6 7Cum. Prod. Cum. Prod. Time

(10^6 m^3) (%GIP) (bar) (bar) (J/Jo(t)) (J/Jo|avg) (d)

Average Pressure

Flowing Pressure

Prod. Ratio Q/Qbase

Prod. Ratio V/Vbase

Page 47: NPV_Gas_Apr 1_2011
Page 48: NPV_Gas_Apr 1_2011
Page 49: NPV_Gas_Apr 1_2011
Page 50: NPV_Gas_Apr 1_2011

0

6 7

Page 51: NPV_Gas_Apr 1_2011

7Flow Rate Cum. Prod. Cum. Prod.

(sm^3/d) (10^6 m^3) (%GIP) (bar) (bar) (J/Jo(t)) (J/Jo|avg)

Average Pressure

Flowing Pressure

Prod. Ratio Q/Qbase

Prod. Ratio V/Vbase

Page 52: NPV_Gas_Apr 1_2011
Page 53: NPV_Gas_Apr 1_2011
Page 54: NPV_Gas_Apr 1_2011
Page 55: NPV_Gas_Apr 1_2011

0

7

Page 56: NPV_Gas_Apr 1_2011

8Time Flow Rate Cum. Prod. Cum. Prod.

(d) (sm^3/d) (10^6 m^3) (%GIP) (bar) (bar) (J/Jo(t)) (J/Jo|avg)

Average Pressure

Flowing Pressure

Prod. Ratio Q/Qbase

Prod. Ratio V/Vbase

Page 57: NPV_Gas_Apr 1_2011
Page 58: NPV_Gas_Apr 1_2011
Page 59: NPV_Gas_Apr 1_2011
Page 60: NPV_Gas_Apr 1_2011

0

8

Page 61: NPV_Gas_Apr 1_2011

9Time Flow Rate Cum. Prod. Cum. Prod.

(d) (sm^3/d) (10^6 m^3) (%GIP) (bar) (bar) (J/Jo(t))

Average Pressure

Flowing Pressure

Prod. Ratio Q/Qbase

Page 62: NPV_Gas_Apr 1_2011
Page 63: NPV_Gas_Apr 1_2011
Page 64: NPV_Gas_Apr 1_2011
Page 65: NPV_Gas_Apr 1_2011

0

9

Page 66: NPV_Gas_Apr 1_2011

9 10Time Flow Rate Cum. Prod. Cum. Prod.

(J/Jo|avg) (d) (sm^3/d) (10^6 m^3) (%GIP) (bar) (bar)

Prod. Ratio V/Vbase

Average Pressure

Flowing Pressure

Page 67: NPV_Gas_Apr 1_2011
Page 68: NPV_Gas_Apr 1_2011
Page 69: NPV_Gas_Apr 1_2011
Page 70: NPV_Gas_Apr 1_2011

0

9 10

Page 71: NPV_Gas_Apr 1_2011

10 Choosen TonnesTime Flow Rate Cum. Prod. Cum. Prod.

(J/Jo(t)) (J/Jo|avg) (d) (sm^3/d) (10^6 m^3) (%GIP) (bar)

Prod. Ratio Q/Qbase

Prod. Ratio V/Vbase

Average Pressure

Page 72: NPV_Gas_Apr 1_2011
Page 73: NPV_Gas_Apr 1_2011
Page 74: NPV_Gas_Apr 1_2011
Page 75: NPV_Gas_Apr 1_2011

10 Choosen

Page 76: NPV_Gas_Apr 1_2011

Choosen Tonnes Net Cumulative ProductionCum. Prod.

(bar) (J/Jo(t)) (J/Jo|avg) (10^6 m^3)

00000000000000000000000000000000000000000

Flowing Pressure

Prod. Ratio Q/Qbase

Prod. Ratio V/Vbase

Page 77: NPV_Gas_Apr 1_2011

000000000000000000000000000000000000000000000

Page 78: NPV_Gas_Apr 1_2011

000000000000000000000000000000000000000000000

Page 79: NPV_Gas_Apr 1_2011

000000000000000000000000000000000000000000000

Page 80: NPV_Gas_Apr 1_2011

000000000000000000000

Choosen Net Choosen

Page 81: NPV_Gas_Apr 1_2011

Net Cumulative ProductionNet Cash Flow

€ Initial Investment for Tonne Frac

0 0.000 Input000000000000000000000000000000000000000

Page 82: NPV_Gas_Apr 1_2011

000000000000000000000000000000000000000000000

Page 83: NPV_Gas_Apr 1_2011

000000000000000000000000000000000000000000000

Page 84: NPV_Gas_Apr 1_2011

000000000000000000000000000000000000000000000

Page 85: NPV_Gas_Apr 1_2011

000000000000000000000

Net Choosen

Page 86: NPV_Gas_Apr 1_2011

RESERVOIR DATA:

FORMATION: 0

RESERVOIR FLUID: 0

BOTTOMHOLE TEMPERATURE: 0

RESERVOIR BOTTOMHOLE PRESSURE: 0

RESERVOIR DRAINAGE AREA 0.0

POROSITY: 0

PERMEABILITY: 0.000

WATER SATURATION: 0

GAS SPECIFIC GRAVITY 0.000

NET PAY THICKNESS: 0.0

PERFORATIONS: 0.0 - 0.00.0 - 0.00.0 - 0.00.0 - 0.0

TVD TOP PERFORATION: 0.0

OBJECTIVES:

1. Predict post fracture geometry in formation for well .

2. Determine optimum frac size using Net Present Value (NPV) analysis.

PROCEDURE:

1. Determine rock properties from customer supplied logs and information. Create model in Meyers Fracture Simulator.

2. Use Meyers Fracture Simulator (MFRAC) to predict fracture geometry.

3. Use Meyers Production Simulator (MPROD) to predict post fracture production.

4. Perform NPV analysis and report results.

Page 87: NPV_Gas_Apr 1_2011

ECONOMIC INPUTS:

Frac Fluid Unit Cost 0Proppant Unit Cost 0Fixed Equipment Cost 0Workover Cost 0Unit Revenue for Production Gas (Net) 0Revenue Escalation Rate 0Discount Rate 0Time Period 0

MISCELLANEOUS INPUTS:

Fluid System 0Gel Loading 0Proppant Type 0Proppant Size 0

FRAC COSTS:

Frac Size Fluid Volume Frac Cost Initial Investment(Tonne) (m³) (€) (€)

Scenario 1 0 0.0 0 0Scenario 2 0 0.0 0 0Scenario 3 0 0.0 0 0Scenario 4 0 0.0 0 0Scenario 5 0 0.0 0 0Scenario 6 0 0.0 0 0Scenario 7 0 0.0 0 0Scenario 8 0 0.0 0 0Scenario 9 0 0.0 0 0Scenario 10 0 0.0 0 0

FRAC GEOMETRY:

Propped Upper Lower Average Fcd EstimatedLength Propped Propped Propped (Dim. Net Cumulative

Height Height Width Frac Production(m) (m) (m) (mm) Cond.) (m³)

Scenario 1 0.0 0.0 0.0 0.0 0.0 0Scenario 2 0.0 0.0 0.0 0.0 0.0 0Scenario 3 0.0 0.0 0.0 0.0 0.0 0Scenario 4 0.0 0.0 0.0 0.0 0.0 0Scenario 5 0.0 0.0 0.0 0.0 0.0 0Scenario 6 0.0 0.0 0.0 0.0 0.0 0Scenario 7 0.0 0.0 0.0 0.0 0.0 0Scenario 8 0.0 0.0 0.0 0.0 0.0 0Scenario 9 0.0 0.0 0.0 0.0 0.0 0Scenario 10 0.0 0.0 0.0 0.0 0.0 0

Page 88: NPV_Gas_Apr 1_2011

0 2 4 6 8 10 120.00

2.00

4.00

6.00

8.00

10.00

12.00Initial Investmest vs. Frac Size

Frac Size (tonnes)

Init

ial

Inv

es

tme

st

(€)

0 2 4 6 8 10 120

2

4

6

8

10

12Propped Length vs. Frac Size

Frac Size (tonnes)

Pro

pp

ed

Le

ng

th (

m)

0 2 4 6 8 10 120

2

4

6

8

10

12Production Rate vs. Time

Base

T

T

T

T

T

T

T

T

T

TTime (days)

Flo

w R

ate

(m

³/d

ay

)

Page 89: NPV_Gas_Apr 1_2011

CONCLUSIONS:

Various sized fracture treatments were modeled in Meyers Fracture Simulator. In conjuctionwith Meyers Production Simulator, net present value analysis was performed for the formation at . Based on the year NPV the optimum treatment sizewould be in the tonne range. The initial investment is estimated to be recovered in days.

Reported by:0

0 2 4 6 8 10 120

2

4

6

8

10

12Net Present Value Tonnes

Time (days)

NP

V (

€)

0 2 4 6 8 10 120.00

2.00

4.00

6.00

8.00

10.00

12.00Net Present Value vs. Time

Frac Size (tonnes)

NP

V (

€)

? tonnes

Page 90: NPV_Gas_Apr 1_2011

0

0

0 °C

0 bar

0.0 ha

0 %

0.000 mD

0 %

0.000

0.0 m

0.0 - 0.0 m0.0 - 0.0 m0.0 - 0.0 m0.0 - 0.0 m

0.0 m

Determine rock properties from customer supplied logs and information. Create

Use Meyers Production Simulator (MPROD) to predict post fracture production.

Page 91: NPV_Gas_Apr 1_2011

0 €/m³0 €/kg0 €0 €0 €/m³0 %0 %0 years

00 kg/m³00 mesh

Initial Investment(€)0000000000

EstimatedNet Cumulative

Production(m³)

0000000000

Page 92: NPV_Gas_Apr 1_2011

0 2 4 6 8 10 120.00

2.00

4.00

6.00

8.00

10.00

12.00Initial Investmest vs. Frac Size

Frac Size (tonnes)

Init

ial

Inv

es

tme

st

(€)

0 2 4 6 8 10 120

2

4

6

8

10

12Propped Length vs. Frac Size

Frac Size (tonnes)

Pro

pp

ed

Le

ng

th (

m)

0 2 4 6 8 10 120

2

4

6

8

10

12Production Rate vs. Time

Base

T

T

T

T

T

T

T

T

T

TTime (days)

Flo

w R

ate

(m

³/d

ay

)

Page 93: NPV_Gas_Apr 1_2011

0

0 2 4 6 8 10 120

2

4

6

8

10

12Net Present Value Tonnes

Time (days)

NP

V (

€)

0 2 4 6 8 10 120.00

2.00

4.00

6.00

8.00

10.00

12.00Net Present Value vs. Time

Frac Size (tonnes)

NP

V (

€)

? tonnes