Economics of Gas Gathering Cashflow

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Instructions Page 1 INSTRUCTIONS FOR THE USE OF CASH.xls SPREADSHEET TO GENERATE CASHFLOW TABLE 1 Choose CASHFLOW SET UP from the Tools menu 2 Select the parameters you wish to update, by checking the appro 3 As long as the GENERATE CASHFLOW TABLE box is checked, the resu Note: There is a slight variation in the NPVs of the Plant Access cas "Economics of Gas Gathering and Processing in the Cooper Basin" See Results Sheet BACKGROUND This spreadsheet contains all the economic data which froms the basis for and Processing in the Cooper Basin". Economic data from the following GPA Engineering reports have been input: Cooper Basin Gas Field Development Study - updated version, Mar Moomba and Port Bonython Replacement Study - January 1996 (These reports form appendices to the MESA report). These data are used to automatically generate a cashflow table, based on The economic data is input as individual components as follows: Input Spreadsheet Page Processing Plant Capex prod_profile Wellhead Facilities and Flowline Cap facilities Field Compression Capex compression Trunklines and Roads Capex trunklines_road Field Facilites Opex field_opex Field Compression Opex comp_opex Processing Plant Opex plant_opex Trunklines and Roads Opex trunk_opex Fuel Gas Requirements fuel_gas QUERIES SHOULD BE DIRECTED TO: Richard McDonough Phone (08) 8274 7626 Senior Petroleum Engineer Fax (08) 8373 3269 Petroleum Division E-mail rmcdonough@msgate. Mines and Energy Resources SA PO Box 151 Eastwood SA 5063

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Transcript of Economics of Gas Gathering Cashflow

Page 1: Economics of Gas Gathering Cashflow

Instructions

Page 1

INSTRUCTIONS FOR THE USE OF CASH.xls SPREADSHEET

TO GENERATE CASHFLOW TABLE

1 Choose CASHFLOW SET UP from the Tools menu

2 Select the parameters you wish to update, by checking the appropriate box

3 As long as the GENERATE CASHFLOW TABLE box is checked, the results will be calculated

Note: There is a slight variation in the NPVs of the Plant Access cases (when compared to Table 4 in the report

"Economics of Gas Gathering and Processing in the Cooper Basin" as the Royalty calculation formula required updating.

See Results Sheet

BACKGROUND

This spreadsheet contains all the economic data which froms the basis for the MESA report "Economics of Gas Gathering

and Processing in the Cooper Basin".

Economic data from the following GPA Engineering reports have been input:

Cooper Basin Gas Field Development Study - updated version, March 1996

Moomba and Port Bonython Replacement Study - January 1996

(These reports form appendices to the MESA report).

These data are used to automatically generate a cashflow table, based on information selected in the INPUT page.

The economic data is input as individual components as follows:

Input Spreadsheet Page

Processing Plant Capex prod_profile

Wellhead Facilities and Flowline Capex facilities

Field Compression Capex compression

Trunklines and Roads Capex trunklines_road

Field Facilites Opex field_opex

Field Compression Opex comp_opex

Processing Plant Opex plant_opex

Trunklines and Roads Opex trunk_opex

Fuel Gas Requirements fuel_gas

QUERIES SHOULD BE DIRECTED TO:

Richard McDonough Phone (08) 8274 7626

Senior Petroleum Engineer Fax (08) 8373 3269

Petroleum Division E-mail [email protected]

Mines and Energy Resources SA

PO Box 151

Eastwood SA 5063

Page 2: Economics of Gas Gathering Cashflow

Instructions

Page 2

As long as the GENERATE CASHFLOW TABLE box is checked, the results will be calculated

There is a slight variation in the NPVs of the Plant Access cases (when compared to Table 4 in the report

"Economics of Gas Gathering and Processing in the Cooper Basin" as the Royalty calculation formula required updating.

This spreadsheet contains all the economic data which froms the basis for the MESA report "Economics of Gas Gathering

These data are used to automatically generate a cashflow table, based on information selected in the INPUT page.

[email protected]

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input

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SMALL GAS FIELDS STUDY - CASHFLOW SPREADSHEET

Field Size 50 size SINGLE FIELDS - 10/50/100 bcf: MULTIPLE FIELDS - 20/30/40/50 bcf

Field Depletion rate 10% depl SINGLE FIELDS - 5% or 10% only: MULTIPLE FIELDS - 5% of 50 bcf (ie. 2.5 bcf/yr)

Multiple Fields no multi

Number of Fields (1-5) 1

Distance to Transmission Line 50 km for Stand-Alone facility case

Distance to Satellite 50 km for Plant Access case

LPG Recovery ? no lpg

Port Bonython no lpg_pb

Stand-Alone no lpg_sa

Gas Type (rich/lean) lean gastype

CO2 Content (high/low) low CO_2

Moomba Plant Access Charge 1400 $/mmscf raw gas

RESULTS Stand-Alone Facility Moomba Plant

NPV of Cash Flow @10% 11612 $1995k -5022 $1995k

NPV of Cash Flow @12.5% 9387 $1995k -5651 $1995k

Economic recovery factor 73% 77%

Recoverable Sales Gas 34.5 PJ 32.0 PJ

LPG recovery 0 tonnes 20739 tonnes

Condensate recovery 15911 m3 18990 m3

Shrinkage 0.809278 shrink

Sales Gas HV 42.99 MJ/m3 heatval

Condensate Content 0.0155 m3 liquid / KCM raw gas cond

LPG Content 0.0000 tonnes LPG / KCM raw gas lpgcont

TOTAL LIQUIDS CONTENT 0.0155 m3 liquid / KCM raw gas totliq

Fuel Gas ex-LP Separator 0.73% % of raw gas fuelgas

Additional LPG recovery fuel req. 0.00% % of raw gas addfuel

Exploration Seismic Cost 0 $m X km/well at $Y/km

Development Seismic Cost 0 $m X km/well at $Y/km

Drilling Cost 1.1 $m drill

Completion Cost 0.35 $m complete

Frac Cost 0.3 $m frac

TOTAL WELL COST 1.75 $m

Gas Price 2 $/GJ gasprice

LPG Price 335 $/tonne lpgprice

Condensate Price 25 $/bbl condprice

157.24 $/m3

REVENUE CALCULATION ($1995k) Year 0 Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21 Year 22 Year 23 Year 24 Year 25 Year 26

Raw Gas Rate bcf/yr rawprod 0 5 5 5 5 4.296224 3.275937 2.585117 2.067255 1.701538 1.407877 1.186353 1.01613 0.869921 0.761388 0.665292 0.589941 0.517813 0.456326 0.412764 0.369229 0.325694 0.284612 0.01 0.01 0.01 0.01

MSCM/yr (million SCM/yr) 0 140.9 140.9 140.9 140.9 121.0 92.3 72.8 58.2 47.9 39.7 33.4 28.6 24.5 21.5 18.7 16.6 14.6 12.9 11.6 10.4 9.2 8.0 0.3 0.3 0.3 0.3

Gross Sales Gas Production MSCM/yr (million SCM/yr) 0 114.00 114.00 114.00 114.00 97.96 74.69 58.94 47.13 38.80 32.10 27.05 23.17 19.83 17.36 15.17 13.45 11.81 10.40 9.41 8.42 7.43 6.49 0.23 0.23 0.23 0.23

Fuel Gas fuel gas required (million SCM/yr) fuel 0 1.48 1.48 2.16 2.56 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43

additional fuel for LPG recovery 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

TOTAL FUEL REQUIREMENT 0 1.48 1.48 2.16 2.56 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43

fuel gas ex LP-separat(million SCM/yr) 0 1.03 1.03 1.03 1.03 0.89 0.68 0.53 0.43 0.35 0.29 0.25 0.21 0.18 0.16 0.14 0.12 0.11 0.09 0.09 0.08 0.07 0.06 0.00 0.00 0.00 0.00

sales gas put to fuel (million SCM/yr) 0 0.45 0.45 1.13 1.53 3.54 3.75 3.90 4.00 4.08 4.14 4.18 4.22 4.25 4.27 4.29 4.31 4.32 4.34 4.34 4.35 4.36 4.37 4.43 4.43 4.43 4.43

required fuel factor (million SCM/yr) 0 1.1% 1.1% 1.5% 1.8% 3.7% 4.8% 6.1% 7.6% 9.2% 11.2% 13.3% 15.5% 18.1% 20.7% 23.6% 26.7% 30.4% 34.5% 38.1% 42.6% 48.3% 55.2% 1572.4% 1572.4% 1572.4% 1572.4%

Net Sales Gas Production MSCM/yr (million SCM/yr) 0 113.56 113.56 112.88 112.48 94.42 70.94 55.05 43.13 34.72 27.96 22.87 18.95 15.58 13.09 10.88 9.14 7.48 6.07 5.07 4.07 3.06 2.12 0.00 0.00 0.00 0.00

PJ/yr 0 4.88 4.88 4.85 4.84 4.06 3.05 2.37 1.85 1.49 1.20 0.98 0.81 0.67 0.56 0.47 0.39 0.32 0.26 0.22 0.17 0.13 0.09 0.00 0.00 0.00 0.00

Net Sales Gas Yield 0 0.81 0.81 0.80 0.80 0.78 0.77 0.76 0.74 0.72 0.70 0.68 0.66 0.64 0.61 0.58 0.55 0.51 0.47 0.44 0.39 0.33 0.26 0.00 0.00 0.00 0.00

LPG Production tonnes/yr 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Condensate Production m3/yr 0 2178 2178 2178 2178 1872 1427 1126 901 741 613 517 443 379 332 290 257 226 199 180 161 142 124 4 4 4 4

TOTAL LIQUIDS m3/yr 0 2178 2178 2178 2178 1872 1427 1126 901 741 613 517 443 379 332 290 257 226 199 180 161 142 124 4 4 4 4

SALES GAS REVENUE ($1995K) 0 9764 9764 9705 9671 8118 6100 4733 3709 2985 2404 1966 1629 1340 1125 935 786 643 522 436 350 263 182 0 0 0 0

LPG REVENUE ($1995K) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

CONDENSATE REVENUE ($1995K) 0 343 343 343 343 294 224 177 142 117 96 81 70 60 52 46 40 35 31 28 25 22 19 1 1 1 1

TOTAL REVENUE ($1995K) 0 10106 10106 10048 10013 8412 6324 4910 3850 3102 2501 2047 1699 1400 1177 981 827 679 553 464 375 286 202 1 1 1 1

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CAPEX CALCULATION ($1995k) Year 0 Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21 Year 22 Year 23 Year 24 Year 25 Year 26

Wells Drilled wells 3 1 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Seismic Cost 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Drilling Cost 5250 1750 1750 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Wellhead Facilities and Flowlines flow 634 238 238 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Compression comp 0 0 600 1120 1000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Processing Plant plant 5250 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Gas Trunkline gastrunk 4770 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Liquids Trunkline liqtrunk 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Road 500 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Infrastructure 300 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

TOTAL CAPEX ($1995K) 16704 1988 2588 1120 1000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

OPEX CALCULATION ($1995k) Year 0 Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21 Year 22 Year 23 Year 24 Year 25 Year 26

Downhole downhole 0 135 180 225 225 225 225 225 225 225 225 225 225 225 225 225 225 225 225 225 225 225 225 225 225 225 225

Surface surface 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Wellhead Facilities and Flowlines fldop 0 12 12 12 19 19 19 26 34 34 34 34 34 34 34 34 34 34 34 34 34 34 34 34 34 34 34

Compression compop 0 0 0 76 142 231 231 231 231 231 231 231 231 231 231 231 231 231 231 231 231 231 231 231 231 231 231

Processing Plant plantop 0 816 816 816 948 948 948 948 948 948 948 948 948 948 948 948 948 948 948 948 948 948 948 948 948 948 948

Gas Trunkline gastrunkop 0 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143

Liquids Trunkline liqtrunkop 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Road 0 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16 16

Infrastructure & Fuel 0 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224 224

Liquids Trucking Cost 0 148 148 148 148 127 97 77 61 50 42 35 30 26 23 20 17 15 14 12 11 10 8 0 0 0 0

Liquids Toll through Pt Bonython 70 ($/m3 liquids) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

memo 6/5/96, SR 28/1/202/3

TOTAL OPEX ($1995K) 0 1494 1539 1660 1865 1933 1903 1890 1882 1871 1863 1856 1851 1847 1844 1841 1838 1836 1835 1833 1832 1831 1829 1821 1821 1821 1821

opex/mmscf raw gas produced 0 299 308 332 373 450 581 731 911 1100 1323 1565 1822 2123 2421 2767 3116 3546 4020 4441 4962 5621 6428 182130 182130 182130 182130

ROYALTY CALCULATION Year 0 Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21 Year 22 Year 23 Year 24 Year 25 Year 26

Revenue 0 10106 10106 10048 10013 8412 6324 4910 3850 3102 2501 2047 1699 1400 1177 981 827 679 553 464 375 286 202 1 1 1 1

Post-wellhead capex LTGBR 0.082 11454 238 838 1120 1000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Credit foncier over life of facility Period 10 years 0 1419 1449 1553 1691 1815 1815 1815 1815 1815 1815 396 367 263 124 0 0 0 0 0 0 0 0 0 0 0 0

Post-wellhead opex 0 1359 1359 1435 1640 1708 1678 1665 1657 1646 1638 1631 1626 1622 1619 1616 1613 1611 1610 1608 1607 1606 1604 1596 1596 1596 1596

Wellhead value 0 7328 7298 7060 6682 4889 2831 1430 378 0 0 20 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

ROYALTY @ 10% 2811 2630 0 733 730 706 668 489 283 143 38 0 0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

*** Royalty is 10% of wellhead value. Wellhead value is revenue minus post-wellhead opex and capex.

*** NOTE: Credit Foncier formula must be adjusted if period is not equal to 10 years ***

CASHFLOW ($1995K) NPV-10% NPV-12.5% Year 0 Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21 Year 22 Year 23 Year 24 Year 25 Year 26

Real Discount Rate 0.1 0.125

Cashflow 8814 7568 -16704 5891 5249 6562 6480 5990 4138 2877 1930 1230 638 189 -152 -447 -666 -860 -1012 -1157 -1281 -1369 -1457 -1545 -1628 -1821 -1821 -1821 -1821

Negative cashflows set to zero 11612 9387 -16704 5891 5249 6562 6480 5990 4138 2877 1930 1230 638 189 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

*** NOTE: Negative cashflows are NOT set to zero if there are subsequent positive cashflows

total

GAS PRODUCED WHILE CASHFLOW IS POSITIVE (bcf) 36.52 5.00 5.00 5.00 5.00 4.30 3.28 2.59 2.07 1.70 1.41 1.19 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Sales Gas Produced while cash flow is positive (PJ) 34.46 4.88 4.88 4.85 4.84 4.06 3.05 2.37 1.85 1.49 1.20 0.98 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

LPG Produced while cash flow is positive (tonnes) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Condensate produced while cash flow is positive (m3) 15911 2178 2178 2178 2178 1872 1427 1126 901 741 613 517 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

IMPACT OF INCREASING DOWNSTREAM COSTS BY 10% Year 0 Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21 Year 22 Year 23 Year 24 Year 25 Year 26

REVENUE 0 8270 8270 8075 5995 4301 3145 2355 1757 1350 1004 790 575 379 269 192 15 15 15 15 15 15 15 15 15 15 15

CAPEX 17786 1988 2648 1232 1100 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

OPEX 0 1630 1675 1804 2029 2104 2071 2056 2048 2036 2026 2019 2014 2009 2005 2002 2000 1997 1995 1994 1993 1991 1990 1981 1981 1981 1981

ROYALTY Post-wellhead capex LTGBR 0.082 12536 238 898 1232 1100 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Credit Foncier Period 10 years 0 1553 1583 1694 1847 1983 1983 1983 1983 1983 1983 430 400 289 136 0 0 0 0 0 0 0 0 0 0 0 0

Post wellhead opex 0 1495 1495 1579 1804 1879 1846 1831 1823 1811 1801 1794 1789 1784 1780 1777 1775 1772 1770 1769 1768 1766 1765 1756 1756 1756 1756

Wellhead value 0 5222 5193 4803 2345 439 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Royalty @ 10% 1452 1383 0 522 519 480 234 44 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

CASHFLOW -17786 4130 3428 4559 2632 2153 1074 299 -291 -686 -1022 -1230 -1439 -1630 -1737 -1810 -1985 -1983 -1981 -1979 -1978 -1976 -1975 -1966 -1966 -1966 -1966

Negative cashflows set to zero -3878 -4705 -17786 4130 3428 4559 2632 2153 1074 299 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

NPV-10% NPV-12.5%

::

CASHFLOW ASSUMING ACCESS TO SATELLITE, MOOMBA PLANT AND PORT BONYTHON (1995$k)

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Year 0 Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21 Year 22 Year 23 Year 24 Year 25 Year 26

RAW GAS ex-field bcf/yr 0.0 5.0 5.0 5.0 5.0 4.3 3.3 2.6 2.1 1.7 1.4 1.2 1.0 0.9 0.8 0.7 0.6 0.5 0.5 0.4 0.4 0.3 0.3 0.0 0.0 0.0 0.0

MSCM/yr (million SCM/yr) 0.0 140.9 140.9 140.9 140.9 121.0 92.3 72.8 58.2 47.9 39.7 33.4 28.6 24.5 21.5 18.7 16.6 14.6 12.9 11.6 10.4 9.2 8.0 0.3 0.3 0.3 0.3

Sales Gas Yield 2.956E-05 moomsales(PJ/KSCM raw gas) PJ 0.0 4.2 4.2 4.2 4.2 3.6 2.7 2.2 1.7 1.4 1.2 1.0 0.8 0.7 0.6 0.6 0.5 0.4 0.4 0.3 0.3 0.3 0.2 0.0 0.0 0.0 0.0

LPG Yield 0.019167 moomlpg (t/KSCM raw gas) tonnes 0 2700 2700 2700 2700 2320 1769 1396 1116 919 760 641 549 470 411 359 319 280 246 223 199 176 154 5 5 5 5

Condensate Yield 0.01755 moomcond(M3/KSCM raw gas) M3 0 2472 2472 2472 2472 2124 1620 1278 1022 841 696 587 502 430 376 329 292 256 226 204 183 161 141 5 5 5 5

nb: assumes field fuel = 2.4% of raw gas, and plant fuel = 6.8% of sales gas (from 1996 SIPS)

Sales Gas Revenue (1995$k) 0 8327 8327 8327 8327 7155 5456 4305 3443 2834 2345 1976 1692 1449 1268 1108 982 862 760 687 615 542 474 17 17 17 17

LPG Revenue (1995$k) 0 905 905 905 905 777 593 468 374 308 255 215 184 157 138 120 107 94 83 75 67 59 51 2 2 2 2

Condensate Revenue (1995$k) 0 389 389 389 389 334 255 201 161 132 109 92 79 68 59 52 46 40 35 32 29 25 22 1 1 1 1

TOTAL REVENUE (1995$k) 0 9620 9620 9620 9620 8266 6303 4974 3977 3274 2709 2283 1955 1674 1465 1280 1135 996 878 794 710 627 548 19 19 19 19

Stand-alone facility revenue 0 10106 10106 10048 10013 8412 6324 4910 3850 3102 2501 2047 1699 1400 1177 981 827 679 553 464 375 286 202 1 1 1 1

FIELD CAPEX 6384 1988 1988 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Trunkline capex (from field to satellite) 50 km sattrunk 4770 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

FIELD OPEX 0 163 208 253 260 260 260 267 275 275 275 275 275 275 275 275 275 275 275 275 275 275 275 275 275 275 275

Trunkline opex (from field to satellite) sattrunkop 0 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143 143

PLANT ACCESS CHARGE 1400 $/mmscf plantcharge 0 7000 7000 7000 7000 6015 4586 3619 2894 2382 1971 1661 1423 1218 1066 931 826 725 639 578 517 456 398 14 14 14 14

ROYALTY Post-wellhead capex LTGBR 0.082 5904 238 238 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Credit Foncier Period 10 years 0 732 761 791 791 791 791 791 791 791 791 59 29 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Post wellhead opex 0 7171 7171 7171 7178 6193 4764 3804 3087 2575 2164 1854 1616 1411 1259 1124 1019 918 832 771 710 649 591 207 207 207 207

Wellhead value 0 1718 1688 1659 1652 1283 748 379 100 0 0 370 310 263 206 156 116 78 46 23 0 0 0 0 0 0 0

Royalty @ 10% 724 668 0 172 169 166 165 128 75 38 10 0 0 37 31 26 21 16 12 8 5 2 0 0 0 0 0 0 0

CASHFLOW -11154 154 112 2058 2052 1720 1239 907 655 474 320 167 83 12 -40 -85 -120 -154 -183 -204 -225 -247 -269 -413 -413 -413 -413

Negative cashflows set to zero -5022 -5651 -11154 154 112 2058 2052 1720 1239 907 655 474 320 167 83 12 0 0 0 0 0 0 0 0 0 0 0 0 0

NPV-10% NPV-12.5%

total

GAS PRODUCED WHILE CASHFLOW IS POSITIVE (bcf) 38.4 5.0 5.0 5.0 5.0 4.3 3.3 2.6 2.1 1.7 1.4 1.2 1.0 0.9 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Sales Gas Produced while cash flow is positive (PJ) 32.0 4.2 4.2 4.2 4.2 3.6 2.7 2.2 1.7 1.4 1.2 1.0 0.8 0.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

LPG Produced while cash flow is positive (tonnes) 20739 2700 2700 2700 2700 2320 1769 1396 1116 919 760 641 549 470 0 0 0 0 0 0 0 0 0 0 0 0 0

Condensate produced while cash flow is positive (m3) 18990 2472 2472 2472 2472 2124 1620 1278 1022 841 696 587 502 430 0 0 0 0 0 0 0 0 0 0 0 0 0

COMPARE STAND-ALONE WITH ACCESS

Revenue stand-alone 0 10106 10106 10048 10013 8412 6324 4910 3850 3102 2501 2047 1699 1400 1177 981 827 679 553 464 375 286 202 1 1 1 1

access 0 9620 9620 9620 9620 8266 6303 4974 3977 3274 2709 2283 1955 1674 1465 1280 1135 996 878 794 710 627 548 19 19 19 19

Capex stand-alone 16704 1988 2588 1120 1000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

access 11154 1988 1988 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Opex stand-alone 0 1494 1539 1660 1865 1933 1903 1890 1882 1871 1863 1856 1851 1847 1844 1841 1838 1836 1835 1833 1832 1831 1829 1821 1821 1821 1821

access 0 7306 7351 7396 7403 6418 4989 4029 3312 2800 2389 2079 1841 1636 1484 1349 1244 1143 1057 996 935 874 816 432 432 432 432

Cash Flow stand-alone -16704 6624 5979 7268 7148 6479 4421 3020 1968 1230 638 191 -152 -447 -666 -860 -1012 -1157 -1281 -1369 -1457 -1545 -1628 -1821 -1821 -1821 -1821

access -11154 326 281 2224 2217 1848 1314 945 665 474 320 204 115 38 -19 -69 -109 -147 -179 -202 -225 -247 -269 -413 -413 -413 -413

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INDEX FOR DIALOG BOX

Dialog Box Description 1 2 3 4

1 2 index1 Single Field OGIP (bcf) 100 50 10

2 1 index2 Depletion Rate (% of OGIP/yr) 0.1 0.05

3 1 index3 Multiple Field OGIP (bcf) 50 40 30 20

4 2 index4 Distance to Transmission Line (km) 100 50 20

5 2 index5 Distance to Satellite (km) 100 50 20

6 2 index6 LPG Recovery Method 1= Pt Bonython, 2 = Stand-Alone Facilities

7 2 index7 Liquids Content of Raw Gas rich lean

8 2 index8 CO2 Content of Raw Gas high low

9 1 index9 Single or Multiple Field Study 1 = single field, 2 = multiple field

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results

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These results are contained in the report "Economics of Gas Gathering and Processing in the Cooper Basin"

Note that there is a slight variation in the NPVs of the Plant Access case, as the Royalty calculation formula required updating.

TABLE 4

COMPARISION OF STAND-ALONE PROCESSING AND ACCESS TO EXISTING FACILITIES

Field is 50 km from Moomba and 20 km from nearest satellite

sales gas price = $2.00/GJ Pt Bonython / PL2 access assumed to be $70/m3 liquid (stand-alone / lpg recovery case)

LPG price = $335/t No LPG recovery for 10 bcf cases

condensate price = $25/bbl

drilling and completion cost = $1.75m NPV of before tax cashflows ($1995K)

rich/high CO2

NPV@ NPV@

ogip (bcf) depl multi wells 10.0% 12.5%

100 5.0% no 10 stand-alone (no LPG recovery) 28222.6 22610.46

100 5.0% no 10 stand-alone (LPG recovery) 26721.79 19539.93

100 5.0% no 10 access = $2200/mmscf 35376.31 29446.2

100 5.0% no 10 access = $1800/mmscf 49410.01 41575.76

100 5.0% no 10 access = $1400/mmscf 63443.7 53705.31

100 5.0% no 10 access = $1000/mmscf 77477.39 65834.87

100 5.0% no 10 access = $600/mmscf 91511.09 77964.43

equivalent toll (no LPG recovery) 2403.901 2425.424

equivalent toll (LPG recovery) 2446.678 2526.682

50 5.0% no 5 stand-alone (no LPG recovery) 5616.75 3373.995

50 5.0% no 5 stand-alone (LPG recovery) 2992.85 -143.8937

50 5.0% no 5 access = $2200/mmscf 16679.79 13694.99

50 5.0% no 5 access = $1800/mmscf 23696.64 19759.77

50 5.0% no 5 access = $1400/mmscf 30713.49 25824.55

50 5.0% no 5 access = $1000/mmscf 37730.33 31889.33

50 5.0% no 5 access = $600/mmscf 44747.18 37954.1

equivalent toll (no LPG recovery) 2830.656 2880.717

equivalent toll (LPG recovery) 2980.233 0

50 10.0% no 5 stand-alone (no LPG recovery) 11461.69 9179.714

50 10.0% no 5 stand-alone (LPG recovery) 3965.799 1204.479

50 10.0% no 5 access = $2200/mmscf 22762.77 19786.44

50 10.0% no 5 access = $1800/mmscf 32046.12 28193.43

50 10.0% no 5 access = $1400/mmscf 41329.48 36600.42

50 10.0% no 5 access = $1000/mmscf 50612.83 45007.41

50 10.0% no 5 access = $600/mmscf 59896.18 53414.4

equivalent toll (no LPG recovery) 2686.94 2704.663

equivalent toll (LPG recovery) 3009.922 3084.12

10 5.0% no 1 stand-alone (no LPG recovery) -7635 -7635

10 5.0% no 1 stand-alone (LPG recovery) #VALUE! #VALUE!

10 5.0% no 1 access = $2200/mmscf 987.2149 368.0694

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10 5.0% no 1 access = $1800/mmscf 2389.554 1580.451

10 5.0% no 1 access = $1400/mmscf 3792.923 2793.406

10 5.0% no 1 access = $1000/mmscf 5196.293 4006.362

10 5.0% no 1 access = $600/mmscf 6599.662 5219.318

equivalent toll (no LPG recovery) 0 0

equivalent toll (LPG recovery) #VALUE! #VALUE!

10 10.0% no 1 stand-alone (no LPG recovery) -6057.439 -6183.566

10 10.0% no 1 stand-alone (LPG recovery) #VALUE! #VALUE!

10 10.0% no 1 access = $2200/mmscf 2836.275 2259.086

10 10.0% no 1 access = $1800/mmscf 4688.939 3938.019

10 10.0% no 1 access = $1400/mmscf 6543.093 5617.881

10 10.0% no 1 access = $1000/mmscf 8397.246 7297.744

10 10.0% no 1 access = $600/mmscf 10251.4 8977.606

equivalent toll (no LPG recovery) 0 0

equivalent toll (LPG recovery) #VALUE! #VALUE!

5 5.0% no 1 stand-alone (no LPG recovery) -7635 -7635

5 5.0% no 1 stand-alone (LPG recovery) #VALUE! #VALUE!

5 5.0% no 1 access = $2200/mmscf -1786.038 -2036.173

5 5.0% no 1 access = $1800/mmscf -1091.53 -1432.559

5 5.0% no 1 access = $1400/mmscf -396.9137 -830.229

5 5.0% no 1 access = $1000/mmscf 300.3053 -226.3251

5 5.0% no 1 access = $600/mmscf 999.6701 378.8399

equivalent toll (no LPG recovery) 0 0

equivalent toll (LPG recovery) #VALUE! #VALUE!

5 10.0% no 1 stand-alone (no LPG recovery) -8325 -8325

5 10.0% no 1 stand-alone (LPG recovery) #VALUE! #VALUE!

5 10.0% no 1 access = $2200/mmscf -831.0818 -1072.048

5 10.0% no 1 access = $1800/mmscf 85.53409 -237.903

5 10.0% no 1 access = $1400/mmscf 1006.404 598.7261

5 10.0% no 1 access = $1000/mmscf 1928.56 1435.822

5 10.0% no 1 access = $600/mmscf 2852.726 2273.998

equivalent toll (no LPG recovery) 0 0

equivalent toll (LPG recovery) #VALUE! #VALUE!

::

20 2.5 bcf/yr yes 2 stand-alone (no LPG recovery) -5360.589 -5858.449

20 2.5 bcf/yr yes 2 stand-alone (LPG recovery) -12561.91 -13211.7

20 2.5 bcf/yr yes 2 access = $2200/mmscf 6705.407 5771.026

20 2.5 bcf/yr yes 2 access = $1800/mmscf 10329.08 9120.592

20 2.5 bcf/yr yes 2 access = $1400/mmscf 13953.83 12470.83

20 2.5 bcf/yr yes 2 access = $1000/mmscf 17578.57 15821.07

20 2.5 bcf/yr yes 2 access = $600/mmscf 21203.32 19171.31

equivalent toll (no LPG recovery) 0 0

equivalent toll (LPG recovery) 0 0

30 2.5 bcf/yr yes 3 stand-alone (no LPG recovery) -1840 -2949.272

30 2.5 bcf/yr yes 3 stand-alone (LPG recovery) -7008.41 -8503.372

30 2.5 bcf/yr yes 3 access = $2200/mmscf 9631.215 7981.149

30 2.5 bcf/yr yes 3 access = $1800/mmscf 14719.86 12582.94

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30 2.5 bcf/yr yes 3 access = $1400/mmscf 19818.91 17191.83

30 2.5 bcf/yr yes 3 access = $1000/mmscf 24918.08 21800.8

30 2.5 bcf/yr yes 3 access = $600/mmscf 30017.25 26409.77

equivalent toll (no LPG recovery) 0 0

equivalent toll (LPG recovery) 0 0

40 2.5 bcf/yr yes 4 stand-alone (no LPG recovery) 407.2113 -1291.568

40 2.5 bcf/yr yes 4 stand-alone (LPG recovery) -3335.051 -5670.894

40 2.5 bcf/yr yes 4 access = $2200/mmscf 11452.31 9165.79

40 2.5 bcf/yr yes 4 access = $1800/mmscf 17623.77 14623.09

40 2.5 bcf/yr yes 4 access = $1400/mmscf 23798.15 20082.26

40 2.5 bcf/yr yes 4 access = $1000/mmscf 29972.53 25541.42

40 2.5 bcf/yr yes 4 access = $600/mmscf 36146.91 31000.59

equivalent toll (no LPG recovery) 2915.354 0

equivalent toll (LPG recovery) 0 0

50 5.0% yes 5 stand-alone (no LPG recovery) 2707.817 556.5698

50 5.0% yes 5 stand-alone (LPG recovery) 111.212 -2936.82

50 5.0% yes 5 access = $2200/mmscf 13488.38 10687.82

50 5.0% yes 5 access = $1800/mmscf 20461.66 16733.82

50 5.0% yes 5 access = $1400/mmscf 27437.8 22781.49

50 5.0% yes 5 access = $1000/mmscf 34416.16 28830.45

50 5.0% yes 5 access = $600/mmscf 41396.92 34880.78

equivalent toll (no LPG recovery) 2816.897 2869.243

equivalent toll (LPG recovery) 2965.683 0

50 10.0% yes 5 stand-alone (no LPG recovery) 7734.852 5559.106

50 10.0% yes 5 stand-alone (LPG recovery) 306.5165 -2356.827

50 10.0% yes 5 access = $2200/mmscf 18560.96 15850.52

50 10.0% yes 5 access = $1800/mmscf 27624.18 24111.15

50 10.0% yes 5 access = $1400/mmscf 36702.62 32381.92

50 10.0% yes 5 access = $1000/mmscf 45781.11 40652.73

50 10.0% yes 5 access = $600/mmscf 54868.83 48929.57

equivalent toll (no LPG recovery) 2674.622 2695.992

equivalent toll (LPG recovery) 3001.583 0

10 2.5 bcf/yr yes 2 stand-alone (no LPG recovery) -11929.66 -11996.06

10 2.5 bcf/yr yes 2 stand-alone (LPG recovery) -21003.46 -21103.63

10 2.5 bcf/yr yes 2 access = $2200/mmscf -372.9509 -682.5166

10 2.5 bcf/yr yes 2 access = $1800/mmscf 1434.319 1019.708

10 2.5 bcf/yr yes 2 access = $1400/mmscf 3244.122 2723.499

10 2.5 bcf/yr yes 2 access = $1000/mmscf 5055.518 4428.264

10 2.5 bcf/yr yes 2 access = $600/mmscf 6866.913 6133.029

equivalent toll (no LPG recovery) 0 0

equivalent toll (LPG recovery) 0 0

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TABLE 1

SUMMARY OF RESULTS FOR FIELD 50km FROM MOOMBA - ORIGINAL GAS IN PLACE

Field Maximum CO2 Liquids Minimum Economic Field Size (OGIP-bcf)

Type Depletion Content Content

Rate Stand-Alone Facilities Plant Access (LPG recovered)

LPG NOT LPG @ $1000

recovered recovered /mmscf

single 5% of OGIP/yr low lean 36 na 23

low rich 23 34 5-10

single 10% of OGIP/yr low lean 26 na 15

low rich 15 22* 5-10

single 5% of OGIP/yr high lean 100 na 23

high rich 38 50 5-10

single 10% of OGIP/yr high lean 72** na 17

high rich 26 34* 5-10

multiple 2.5 bcf/yr low lean 45 na marginal

low rich 20 33 10-20

multiple 2.5 bcf/yr high lean unecon. na marginal

high rich 47 70 10-20

NOTES:

1. NPV at 12.5% real discount rate

2. Gas Price at head of pipeline = $2.00/GJ, LPG price delivered to Adelaide = $335/tonne,

Condensate price at Adelaide Refinery = $157/m3 ($25/bbl).

3. Gas field is 50 km from Moomba and 20 km from the nearest satellite.

4. For "Stand-Alone - LPG Recovered Case", condensate and LPG is tolled through the Liquids Pipeline

and Port Bonython at $70/m3 ($11.10/bbl).

5. (*) indicates estimate based on "LPG NOT Recovered" case.

6. (**) indicates estimate based on "low CO2, low liquids" case.

7. For multiple field cases, individual field OGIP is 10 bcf each.

8. For multiple field cases with lean composition, economic original-gas-in-place > 20 bcf for 10% discount rate

if plant access is $1000/mmscf.

::

TABLE 2

SUMMARY OF RESULTS FOR FIELD 50km FROM MOOMBA - RECOVERABLE RAW GAS

Field Maximum CO2 Liquids Minimum Economic Field Size (Recoverable Raw Gas-bcf)

Type Depletion Content Content

Rate Stand-Alone Facilities Plant Access (LPG recovered)

LPG NOT LPG @ $1000

recovered recovered /mmscf

single 5% of OGIP/yr low lean 26.64 na 18

low rich 18 27 4-8

single 10% of OGIP/yr low lean 19 na 12

low rich 12 18* 4-8

single 5% of OGIP/yr high lean 72 na 19

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high rich 28.88 38 4-8

single 10% of OGIP/yr high lean 53** na 14.11

high rich 20 25* 4-8

multiple 2.5 bcf/yr low lean 32.56 na marginal

low rich 12 23 7-15

multiple 2.5 bcf/yr high lean unecon. na marginal

high rich 35 46 7-15

NOTES:

1. NPV at 12.5% real discount rate

2. Gas Price at head of pipeline = $2.00/GJ, LPG price delivered to Adelaide = $335/tonne,

Condensate price at Adelaide Refinery = $157/m3 ($25/bbl).

3. Gas field is 50 km from Moomba and 20 km from the nearest satellite.

4. For "Stand-Alone - LPG Recovered Case", condensate and LPG is tolled through the Liquids Pipeline

and Port Bonython at $70/m3 ($11.10/bbl).

5. Use recovery factor from nearest profitable case (generally 50 bcf case)

6. (*) indicates estimate based on "LPG NOT Recovered" case.

7. (**) indicates estimate based on "low CO2, low liquids" case.

8. For multiple field cases, individual field OGIP is 10 bcf each.

9. For multiple field cases with lean composition, economic recoverable raw gas >15 bcf for 10% discount rate

if plant access is $1000/mmscf.

::

TABLE 3

SUMMARY OF RESULTS FOR FIELD 50km FROM MOOMBA - RECOVERABLE SALES GAS

Field Maximum CO2 Liquids Minimum Economic Field Size (Recoverable Sales Gas-PJ)

Type Depletion Content Content

Rate Stand-Alone Facilities Plant Access (LPG recovered)

LPG NOT LPG @ $1000

recovered recovered /mmscf

single 5% of OGIP/yr low lean 25.704 na 15

low rich 15.796 17 3-7

single 10% of OGIP/yr low lean 18 na 10

low rich 10.59 11* 3-7

single 5% of OGIP/yr high lean 42.4 na 11

high rich 16.948 16 3-7

single 10% of OGIP/yr high lean 31** na 8

high rich 11 10* 3-7

multiple 2.5 bcf/yr low lean 32 na marginal

low rich 11 15 5-12

multiple 2.5 bcf/yr high lean unecon. na marginal

high rich 19.872 19 5-12

NOTES:

1. NPV at 12.5% real discount rate

2. Gas Price at head of pipeline = $2.00/GJ, LPG price delivered to Adelaide = $335/tonne,

Condensate price at Adelaide Refinery = $157/m3 ($25/bbl).

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3. Gas field is 50 km from Moomba and 20 km from the nearest satellite.

4. For "Stand-Alone - LPG Recovered Case", condensate and LPG is tolled through the Liquids Pipeline

and Port Bonython at $70/m3 ($11.10/bbl).

5. (*) indicates estimate based on "LPG NOT Recovered" case.

6. (**) indicates estimate based on "low CO2, low liquids" case.

7. For multiple field cases, individual field OGIP is 10 bcf each.

8. For multiple field cases with lean composition, economic recoverable sales gas >12 PJ for 10% discount rate

if plant access is $1000/mmscf.

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These results are contained in the report "Economics of Gas Gathering and Processing in the Cooper Basin"

Note that there is a slight variation in the NPVs of the Plant Access case, as the Royalty calculation formula required updating.

Pt Bonython / PL2 access assumed to be $70/m3 liquid (stand-alone / lpg recovery case)

NPV of before tax cashflows ($1995K)

lean/high CO2

recovery sales gas LPG Condens. NPV@ NPV@ recovery sales gas LPG

factor (PJ) (tonnes) (m3) 10.0% 12.5% factor (PJ) (tonnes)

0.800543 46.83447 0 685935.9 2536.362 342.1613 0.723565 42.37618 0

0.78889 33.33272 303032.2 737817.5 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.841683 49.97661 303847.5 747234.8 -8454 -8454 0 0 0

0.841683 49.97661 303847.5 747234.8 -8454 -8454 0 0 0

0.841683 49.97661 303847.5 747234.8 -2760.655 -3547.542 0.78889 46.07118 147522.4

0.841683 49.97661 303847.5 747234.8 11166.66 8519.816 0.835257 48.779 156193

0.841683 49.97661 303847.5 747234.8 25195.22 20646.51 0.841683 49.15428 157394.7

1246.078 1269.741

#VALUE! #VALUE!

0.760731 22.31147 0 325911.5 -6904.146 -7551.207 0.672586 19.76601 0

0.760731 16.14237 146107.8 355740.7 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.841683 24.9883 151923.8 373617.4 -5841 -5841 0 0 0

0.841683 24.9883 151923.8 373617.4 -5841 -5841 0 0 0

0.841683 24.9883 151923.8 373617.4 -2375.894 -2794.203 0.775757 22.65212 72533.33

0.841683 24.9883 151923.8 373617.4 4577.534 3233.247 0.82796 24.17643 77414.26

0.841683 24.9883 151923.8 373617.4 11589.25 9295.148 0.841683 24.57714 78697.35

0 0

#VALUE! #VALUE!

0.750729 21.84684 0 321626.3 -5328.421 -6189.657 0.644491 18.60926 0

0.730406 15.00524 140283.5 341559.9 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.855788 25.40707 154469.8 379878.6 -8454 -8454 0 0 0

0.855788 25.40707 154469.8 379878.6 -8454 -8454 0 0 0

0.855788 25.40707 154469.8 379878.6 -2385.794 -3027.032 0.783355 22.87396 73243.67

0.855788 25.40707 154469.8 379878.6 6768.305 5295.09 0.836198 24.41697 78184.47

0.855788 25.40707 154469.8 379878.6 16027.93 13687.38 0.855788 24.98902 80016.2

0 0

#VALUE! #VALUE!

0 0 0 0 -7655 -7655 0 0 0

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.835257 4.959504 30152.77 74152.98 -3855 -3855 0 0 0

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0.841683 4.997661 30384.75 74723.48 -3855 -3855 0 0 0

0.841683 4.997661 30384.75 74723.48 -2872.646 -2986.675 0.723565 4.225619 13530.66

0.841683 4.997661 30384.75 74723.48 -1415.481 -1713.872 0.78889 4.607118 14752.24

0.841683 4.997661 30384.75 74723.48 -26.86915 -509.6109 0.819793 4.787588 15330.12

0 0

#VALUE! #VALUE!

0.551443 3.235182 0 47249.74 -8317.531 -8318.586 0.1 0.592887 0

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.843582 5.008937 30453.31 74892.09 -3855 -3855 0 0 0

0.850096 5.047615 30688.46 75470.38 -3855 -3855 0 0 0

0.850096 5.047615 30688.46 75470.38 -2163.123 -2288.242 0.730406 4.265571 13658.59

0.850096 5.047615 30688.46 75470.38 -345.1399 -629.6054 0.796661 4.652498 14897.55

0.850096 5.047615 30688.46 75470.38 1495.806 1043.11 0.827942 4.835183 15482.52

0 0

#VALUE! #VALUE!

0 0 0 0 -7655 -7655 0 0 0

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.775757 2.303108 14002.42 34435.35 -3855 -3855 0 0 0

0.800543 2.376693 14449.81 35535.59 -3855 -3855 0 0 0

0.810754 2.407008 14634.12 35988.84 -3759.902 -3769.938 0.598752 1.748356 5598.332

0.819793 2.433841 14797.25 36390.04 -3058.499 -3150.016 0.700205 2.044599 6546.918

0.835257 2.479752 15076.39 37076.49 -2326.076 -2507.897 0.743584 2.171266 6952.513

0 0

#VALUE! #VALUE!

0 0 0 0 -8365 -8365 0 0 0

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.783355 2.325663 14139.55 34772.59 -3855 -3855 0 0 0

0.808459 2.400195 14592.69 35886.97 -3855 -3855 0 0 0

0.818816 2.430941 14779.62 36346.68 -3304.903 -3340.117 0.603146 1.761185 5639.411

0.827942 2.458036 14944.36 36751.8 -2391.956 -2498.03 0.706679 2.063502 6607.448

0.843582 2.504469 15226.66 37446.04 -1492.325 -1674.972 0.750729 2.192127 7019.312

0 0

#VALUE! #VALUE!

0.576234 6.727535 0 98747.75 -11463.82 -11602.32 0.462666 5.274742 0

0.576234 4.603004 44269.12 107785.7 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.728725 8.653906 52613.98 129390.5 -6555 -6555 0 0 0

0.735194 8.730727 53081.03 130539.1 -6433.344 -6438.402 0.37205 4.345546 13914.68

0.735194 8.730727 53081.03 130539.1 -3089.276 -3302.264 0.665706 7.775444 24897.4

0.735194 8.730727 53081.03 130539.1 477.7461 7.880077 0.711425 8.309439 26607.28

0.735194 8.730727 53081.03 130539.1 4082.064 3344.69 0.720853 8.419558 26959.89

0 0

#VALUE! #VALUE!

0.650871 11.43672 0 167307.3 -10837.19 -11174.14 0.565696 9.856809 0

0.650871 8.106736 75004.72 182620.2 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.765102 13.62884 82860.57 203774.2 -6555 -6555 0 0 0

0.765102 13.62884 82860.57 203774.2 -6555 -6555 0 0 0

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0.770025 13.71653 83393.71 205085.4 -4153.073 -4502.632 0.701245 12.28581 39339.83

0.770025 13.71653 83393.71 205085.4 875.9385 58.29105 0.748258 13.10949 41977.3

0.770025 13.71653 83393.71 205085.4 5942.911 4645.025 0.757996 13.28008 42523.56

0 0

#VALUE! #VALUE!

0.711735 16.66816 0 243936.5 -10754.12 -11237.13 0.616471 14.34468 0

0.711735 11.83244 109358 266262.8 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.785388 18.6536 113410.1 278902.9 -6555 -6555 0 0 0

0.790899 18.78449 114205.9 280859.9 -6555 -6555 0 0 0

0.790899 18.78449 114205.9 280859.9 -5211.205 -5602.771 0.731152 17.0797 54690.15

0.790899 18.78449 114205.9 280859.9 844.0788 -224.3417 0.769316 17.97123 57544.86

0.790899 18.78449 114205.9 280859.9 6981.511 5210.762 0.785388 18.34667 58747.04

0 0

#VALUE! #VALUE!

0.73549 21.55664 0 315097.7 -9825.341 -10384.38 0.685202 20.11599 0

0.752517 15.89605 144530.2 351899.7 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.805695 23.91987 145427.9 357642.5 -6555 -6555 0 0 0

0.805695 23.91987 145427.9 357642.5 -6508.864 -6509.889 0.05 1.46 4675

0.808472 24.00231 145929.1 358875.1 -5458.928 -5754.725 0.766437 22.37995 71661.82

0.808472 24.00231 145929.1 358875.1 1470.23 264.036 0.795386 23.22529 74368.64

0.810539 24.06368 146302.3 359792.8 8431.14 6302.61 0.801333 23.39893 74924.65

0 0

#VALUE! #VALUE!

0.704268 20.58634 0 301721.5 -8699.194 -9538.204 0.648671 18.74178 0

0.704268 14.59756 135263.3 329336.7 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.790589 23.4714 142701.3 350937.1 -11630 -11630 0 0 0

0.790589 23.4714 142701.3 350937.1 -11630 -11630 0 0 0

0.795303 23.61135 143552.2 353029.6 -5969.065 -6547.939 0.723483 21.12571 67645.68

0.795303 23.61135 143552.2 353029.6 2979.452 1635.579 0.76688 22.3929 71703.31

0.79864 23.71043 144154.5 354511 11998.87 9866.554 0.784499 22.90736 73350.63

0 0

#VALUE! #VALUE!

0.437 2.521989 0 37443.81 -13795.71 -13806.48 0.213 1.266542 0

0.437 1.75527 16786.25 40870.87 #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0.655 3.889193 23645.5 58150.02 -6555 -6555 0 0 0

0.655 3.889193 23645.5 58150.02 -6543.408 -6543.666 0.213 1.24392 3983.1

0.665 3.94857 24006.5 59037.81 -5152.843 -5206.335 0.546 3.18864 10210.2

0.665 3.94857 24006.5 59037.81 -3433.787 -3574.491 0.608 3.55072 11369.6

0.665 3.94857 24006.5 59037.81 -1675.535 -1910.94 0.626 3.65584 11706.2

0 0

#VALUE! #VALUE!

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Plant Access (LPG recovered)

@ $1400 @$1800

/mmscf /mmscf

unecon. unecon.

5-10 5-10

unecon. unecon.

5-10 5-10

unecon. unecon.

5-10 5-10

unecon. unecon.

5-10 5-10

unecon. unecon.

10-20 10-20

unecon. unecon.

10-20 10-20

For "Stand-Alone - LPG Recovered Case", condensate and LPG is tolled through the Liquids Pipeline

For multiple field cases with lean composition, economic original-gas-in-place > 20 bcf for 10% discount rate

Minimum Economic Field Size (Recoverable Raw Gas-bcf)

Plant Access (LPG recovered)

@ $1400 @$1800

/mmscf /mmscf

unecon. unecon.

4-8 4-8

unecon. unecon.

4-8 4-8

unecon. unecon.

Page 17: Economics of Gas Gathering Cashflow

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Page 17

4-8 4-8

unecon. unecon.

4-8 4-8

unecon. unecon.

7-15 7-15

unecon unecon

7-15 7-15

For "Stand-Alone - LPG Recovered Case", condensate and LPG is tolled through the Liquids Pipeline

For multiple field cases with lean composition, economic recoverable raw gas >15 bcf for 10% discount rate

Minimum Economic Field Size (Recoverable Sales Gas-PJ)

Plant Access (LPG recovered)

@ $1400 @$1800

/mmscf /mmscf

unecon. unecon.

3-7 3-7

unecon. unecon.

3-7 3-7

unecon. unecon.

3-7 3-7

unecon. unecon.

3-7 3-7

unecon. unecon.

5-12 5-12

unecon unecon

5-12 5-12

Page 18: Economics of Gas Gathering Cashflow

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Page 18

For "Stand-Alone - LPG Recovered Case", condensate and LPG is tolled through the Liquids Pipeline

For multiple field cases with lean composition, economic recoverable sales gas >12 PJ for 10% discount rate

Page 19: Economics of Gas Gathering Cashflow

results

Page 19

rich/low CO2 lean/low CO2

Condens. NPV@ NPV@ recovery sales gas LPG Condens. NPV@ NPV@

(m3) 10.0% 12.5% factor (PJ) (tonnes) (m3) 10.0% 12.5%

15762.15 54292.05 45267.82 0.819793 74.45479 0 773862.7 29344.34 23688.61

#VALUE! 49579.19 39395.08 0.810754 50.97534 448160.1 632869.8 #VALUE! #VALUE!

0 66750.74 56563.64 0.841683 67.72181 464609 657711.2 -8454 -8454

0 80784.43 68693.2 0.841683 67.72181 464609 657711.2 -8454 -8454

54308.47 94818.13 80822.76 0.841683 67.72181 464609 657711.2 -2022.906 -2906.886

57500.43 108851.8 92952.31 0.841683 67.72181 464609 657711.2 11914.67 9166.653

57942.81 122885.5 105081.9 0.841683 67.72181 464609 657711.2 25944.27 21293.93

2555.108 2572.506 503.06 521.015

2689.438 2766.173 #VALUE! #VALUE!

7325.81 18361.93 14474.88 0.78889 35.92362 0 372345.8 6231.973 3959.744

#VALUE! 14307.17 9714.109 0.78889 24.87045 218037.1 307901.3 #VALUE! #VALUE!

0 32367.01 27253.71 0.841683 33.8609 232304.5 328855.6 -5841 -5841

0 39383.85 33318.49 0.841683 33.8609 232304.5 328855.6 -5841 -5841

26702.2 46400.7 39383.27 0.841683 33.8609 232304.5 328855.6 -2008.747 -2474.977

28499.05 53417.55 45448.05 0.841683 33.8609 232304.5 328855.6 4950.893 3556.297

28971.41 60434.39 51512.83 0.841683 33.8609 232304.5 328855.6 11963.77 9618.856

2998.369 3042.823 926.9299 973.381

3229.513 3356.818 #VALUE! #VALUE!

7019.796 28438.57 24731.04 0.783355 35.33832 0 369733.2 11611.69 9387.532

#VALUE! 18800.55 14789.83 0.750729 23.16076 207489.9 293007 #VALUE! #VALUE!

0 43517.1 38581.53 0.855788 34.42836 236197.5 334366.7 -8454 -8454

0 52800.45 46988.52 0.855788 34.42836 236197.5 334366.7 -8454 -8454

26963.7 62083.8 55395.51 0.855788 34.42836 236197.5 334366.7 -1903.237 -2587.068

28782.59 71367.15 63802.5 0.855788 34.42836 236197.5 334366.7 7261.232 5742.203

29456.92 80650.51 72209.48 0.855788 34.42836 236197.5 334366.7 16523.43 14136.11

2849.702 2858.999 812.12 826.2869

3264.984 3331.996 #VALUE! #VALUE!

0 -6498.518 -6606.284 0.598752 5.460006 0 56520.63 -7625 -7625

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0 4123.627 3079.239 0.841683 6.772181 46460.9 65771.12 -3855 -3855

Page 20: Economics of Gas Gathering Cashflow

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Page 20

0 5526.997 4292.195 0.841683 6.772181 46460.9 65771.12 -3855 -3855

4981.137 6930.366 5505.151 0.841683 6.772181 46460.9 65771.12 -2794.512 -2918.161

5430.847 8333.735 6718.106 0.841683 6.772181 46460.9 65771.12 -1341.706 -1649.806

5643.584 9737.105 7931.062 0.841683 6.772181 46460.9 65771.12 47.64334 -445.0938

0 0 0 0

#VALUE! #VALUE! #VALUE! #VALUE!

217.8401 -3165.248 -3486.58 0.603146 5.50007 0 56935.37 -5988.891 -6115.462

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0 6980.024 6013.741 0.850096 6.839872 46925.3 66428.53 -3855 -3855

0 8834.177 7693.603 0.850096 6.839872 46925.3 66428.53 -3813.633 -3815.776

5028.233 10688.33 9373.466 0.850096 6.839872 46925.3 66428.53 -2067.287 -2200.53

5484.341 12542.48 11053.33 0.850096 6.839872 46925.3 66428.53 -247.0647 -540.3947

5699.688 14396.64 12733.19 0.850096 6.839872 46925.3 66428.53 1594.364 1132.548

0 0 0 0

#VALUE! #VALUE! #VALUE! #VALUE!

0 -7605 -7605 0 0 0 0 -7625 -7625

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0 -232.856 -688.0633 0.810754 3.261665 22376.82 31677.14 -3855 -3855

0 464.9651 -83.80267 0.82796 3.330883 22851.7 32349.39 -3855 -3855

2060.953 1164.793 521.6289 0.835257 3.360238 23053.09 32634.48 -3723.929 -3737.932

2410.163 1865.694 1127.67 0.841683 3.38609 23230.45 32885.56 -3019.921 -3116.1

2559.477 2567.379 1734.147 0.841683 3.38609 23230.45 32885.56 -2286.629 -2473.381

0 0 0 0

#VALUE! #VALUE! #VALUE! #VALUE!

0 -8066.358 -8071.091 0.1 0.911898 0 9439.739 -8315 -8315

#VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE! #VALUE!

0 1223.274 795.6964 0.818816 3.294096 22599.31 31992.11 -3855 -3855

0 2146.583 1633.554 0.836198 3.364023 23079.05 32671.24 -3855 -3855

2076.076 3070.818 2471.695 0.843582 3.393731 23282.87 32959.76 -3258.589 -3297.072

2432.446 3996.807 3310.948 0.850096 3.419936 23462.65 33214.27 -2344.267 -2454.289

2584.069 4923.884 4150.879 0.850096 3.419936 23462.65 33214.27 -1444.18 -1630.986

0 0 0 0

#VALUE! #VALUE! #VALUE! #VALUE!

2015.746 832.3339 -47.29328 0.613615 11.09829 0 115847.3 -5475.3 -5943.479

#VALUE! -7001.468 -7994.974 0.613615 7.382987 67837.49 95796.79 #VALUE! #VALUE!

0 14808 13260.32 0.735194 11.83075 81165.45 114899.7 -6555 -6555

5122.507 18432.74 16610.56 0.735194 11.83075 81165.45 114899.7 -6288.702 -6300.434

9165.653 22057.49 19960.8 0.735194 11.83075 81165.45 114899.7 -2901.516 -3127.595

9795.123 25682.24 23311.04 0.735194 11.83075 81165.45 114899.7 670.0721 185.9734

9924.931 29306.98 26661.28 0.735194 11.83075 81165.45 114899.7 4274.703 3522.954

3742.25 0 0 0

0 0 #VALUE! #VALUE!

3696.937 7213.465 5318.212 0.701245 19.04876 0 198587 -1666.715 -2753.893

#VALUE! 1070.392 -1126.664 0.701245 12.939 116288 164216.2 #VALUE! #VALUE!

0 21020.53 18277.93 0.770025 18.58686 127516.1 180514.8 -6555 -6555

0 26119.7 22886.9 0.770025 18.58686 127516.1 180514.8 -6555 -6555

Page 21: Economics of Gas Gathering Cashflow

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Page 21

14482.45 31218.87 27495.88 0.770025 18.58686 127516.1 180514.8 -3887.174 -4260.957

15453.4 36318.03 32104.85 0.770025 18.58686 127516.1 180514.8 1145.99 302.8739

15654.49 41417.2 36713.82 0.770025 18.58686 127516.1 180514.8 6213.626 4890.023

3283.084 3324.739 0 0

3764.972 0 #VALUE! #VALUE!

5371.682 11501.34 8602.963 0.731152 26.57951 0 276075.2 706.4172 -970.5176

#VALUE! 6523.054 3122.508 0.731152 18.18727 161663.3 228293 #VALUE! #VALUE!

0 25253.14 21368.71 0.790899 25.4543 174630.6 247211 -6555 -6555

0 31427.52 26827.87 0.790899 25.4543 174630.6 247211 -6555 -6555

20133.47 37601.9 32287.04 0.790899 25.4543 174630.6 247211 -4890.884 -5317.737

21184.39 43776.28 37746.21 0.790899 25.4543 174630.6 247211 1170.875 65.2307

21626.96 49950.66 43205.37 0.790899 25.4543 174630.6 247211 7310.439 5501.743

3090.894 3135.362 1030.26 0

3413.407 3536.922 #VALUE! #VALUE!

7463.226 15399.18 11631.33 0.766437 34.81521 0 361748.1 3326.475 1145.614

#VALUE! 11385.3 6902.738 0.766437 24.11897 211831.3 299137.8 #VALUE! #VALUE!

0 29082.25 24206.92 0.808472 32.52481 223138.2 315879.5 -6555 -6555

1721.04 36060.61 30255.88 0.808472 32.52481 223138.2 315879.5 -6460.341 -6462.444

26381.37 43042.74 36306.99 0.812415 32.68345 224226.5 317420.2 -5091.202 -5434.834

27377.85 50027.36 42359.49 0.812415 32.68345 224226.5 317420.2 1841.26 586.0341

27582.53 57011.98 48411.99 0.812415 32.68345 224226.5 317420.2 8802.871 6625.036

2983.109 3030.775 914.6626 962.9356

3212.979 3343.28 #VALUE! #VALUE!

7065.332 24370.67 20863.75 0.740153 33.49031 0 349342.6 7968.686 5835.058

#VALUE! 14836.96 11005.17 0.723483 22.44288 199959.7 282373.2 #VALUE! #VALUE!

0 38841.96 34330.94 0.795303 31.99503 219503.6 310734.3 -11630 -11630

0 47922.18 42602.88 0.79864 32.12929 220424.7 312038.2 -11630 -11630

24902.88 57010.49 50880.09 0.79864 32.12929 220424.7 312038.2 -5496.582 -6114.798

26396.64 66098.8 59157.31 0.79864 32.12929 220424.7 312038.2 3459.158 2073.75

27003.08 75187.11 67434.53 0.79864 32.12929 220424.7 312038.2 12481.46 10306.67

2836.563 2850.552 800.0719 817.2553

3256.166 3326.972 #VALUE! #VALUE!

463.9995 -9224.666 -9388.02 0.501 4.455517 0 47293.09 -11886.52 -11947.56

#VALUE! -18556.11 -18741.77 0.437 2.67197 24156.02 34111.95 #VALUE! #VALUE!

0 3670.977 3125.227 0.665 5.35059 36708 51964.69 -6555 -6555

1466.326 5482.373 4829.992 0.665 5.35059 36708 51964.69 -6502.067 -6503.243

3758.752 7293.768 6534.757 0.665 5.35059 36708 51964.69 -5064.621 -5122.253

4185.57 9102.649 8237.421 0.665 5.35059 36708 51964.69 -3339.833 -3485.545

4309.485 10910.55 9939.265 0.665 5.35059 36708 51964.69 -1580.722 -1821.349

0 0 0 0

0 0 #VALUE! #VALUE!

Page 22: Economics of Gas Gathering Cashflow

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Page 22

recovery sales gas LPG Condens.

factor (PJ) (tonnes) (m3)

0.78889 75.40612 0 34370.38

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0 0 0 0

0.78889 65.69087 42600.06 39006.77

0.835257 69.55184 45103.87 41299.39

0.841683 70.08694 45450.88 41617.12

0.743584 35.68302 0 16198.25

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0 0 0 0

0.78889 32.84544 21300.03 19503.39

0.82796 34.47212 22354.92 20469.3

0.841683 35.04347 22725.44 20808.56

0.730406 34.45867 0 15911.17

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0 0 0 0

0.783355 32.61498 21150.58 19366.54

0.836198 34.81508 22577.33 20672.95

0.855788 35.63074 23106.28 21157.28

0 0 0 0

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

Page 23: Economics of Gas Gathering Cashflow

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Page 23

0 0 0 0

0.723565 6.025125 3907.25 3577.676

0.78889 6.569087 4260.006 3900.677

0.819793 6.826412 4426.88 4053.475

0.551443 5.257389 0 2402.529

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0.4 3.3308 2160 1977.805

0.730406 6.082091 3944.192 3611.502

0.796661 6.633793 4301.967 3939.099

0.827942 6.894275 4470.888 4093.771

0 0 0 0

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0 0 0 0

0.598752 2.492904 1616.631 1480.269

0.700205 2.915304 1890.554 1731.087

0.743584 3.095913 2007.678 1838.331

0 0 0 0

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0 0 0 0

0.603146 2.511196 1628.493 1491.131

0.706679 2.942258 1908.033 1747.092

0.750729 3.125659 2026.967 1855.994

0.576234 10.73453 0 5021.072

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0.462666 7.705245 4996.797 4575.32

0.665706 11.08666 7189.623 6583.182

0.711425 11.84806 7683.385 7035.297

0.720853 12.00508 7785.208 7128.53

0.650871 18.51249 0 8507.151

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0 0 0 0

Page 24: Economics of Gas Gathering Cashflow

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Page 24

0.720316 17.9942 11669.11 10684.83

0.748258 18.69224 12121.79 11099.32

0.757996 18.93549 12279.53 11243.76

0.711735 27.00488 0 12403.55

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0 0 0 0

0.731152 24.3532 15792.88 14460.76

0.769316 25.62439 16617.23 15215.58

0.785388 26.15971 16964.39 15533.45

0.73549 35.26164 0 16021.92

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0.05 2.08175 1350 1236.128

0.778158 32.39859 21010.25 19238.05

0.795386 33.11592 21475.43 19664

0.801333 33.3635 21635.99 19811.01

0.704268 33.36203 0 15341.77

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0 0 0 0

0.723483 30.12222 19534.05 17886.36

0.76688 31.92906 20705.77 18959.25

0.784499 32.6626 21181.46 19394.82

0.437 4.080814 0 1903.923

#VALUE! #VALUE! #VALUE! #VALUE!

0 0 0 0

0.213 1.773651 1150.2 1053.181

0.546 4.546542 2948.4 2699.704

0.608 5.062816 3283.2 3006.264

0.626 5.212702 3380.4 3095.265

Page 25: Economics of Gas Gathering Cashflow

macros

Page 25

CASHFLOW MACRO

1. IMPORT RAW GAS PROFILE, FUEL PROFILE, CAPEX

This table provides a unique flag for the production profile, based on the input parameters.

The FLAG1 cell is set to a number between 1 and 7

The FLAG1 cell is used in the macro \i to select the macro to copy all information to the cashflow table

LIQUIDS TRUNKLINE PLANT ACCESS TRUNKLINE TO SATELLITE

rate flag size depl multi plant capex trunkline capex case trunkline opex liquids trunk capex liquids trunk opex capex opex

388 0 100 0.05 1 4690 plant1 4770 trunk1 AC case1 143 trnkop1 0 liq_cap1 0 liq_op1 2070 ptrunk1 62 ptrunkop1

194 0 50 0.05 1 3890 plant2 4770 trunk2 BC case2 143 trnkop2 0 liq_cap2 0 liq_op2 1445 ptrunk2 43 ptrunkop2

388 0 50 0.1 1 4690 plant3 4770 trunk3 AC case3 143 trnkop3 0 liq_cap3 0 liq_op3 2070 ptrunk3 62 ptrunkop3

39 0 10 0.05 1 1650 plant4 3245 trunk4 DC case4 97 trnkop4 0 liq_cap4 0 liq_op4 1445 ptrunk4 43 ptrunkop4

77 0 10 0.1 1 2300 plant5 3245 trunk5 CC case5 97 trnkop5 0 liq_cap5 0 liq_op5 1445 ptrunk5 43 ptrunkop5

194 0 50 0.05 5 3890 plant6 4770 trunk6 BC case6 143 trnkop6 0 liq_cap6 0 liq_op6 1445 ptrunk6 43 ptrunkop6

388 0 50 0.1 5 4690 plant7 4770 trunk7 AC case7 143 trnkop7 0 liq_cap7 0 liq_op7 2070 ptrunk7 62 ptrunkop7

154 0 10 0.2 1 3890 plant8 4770 trunk8 BC case8 143 trnkop8 0 liq_cap8 0 liq_op8 1445 ptrunk8 43 ptrunkop8

194 9 20 0.05 2 3890 plant9 4770 trunk9 BC case9 143 trnkop9 0 liq_cap9 0 liq_op9 1445 ptrunk9 43 ptrunkop9

194 0 30 0.05 3 3890 plant10 4770 trunk10 BC case10 143 trnkop10 0 liq_cap10 0 liq_op10 1445 ptrunk10 43 ptrunkop10

194 0 40 0.05 4 3890 plant11 4770 trunk11 BC case11 143 trnkop11 0 liq_cap11 0 liq_op11 1445 ptrunk11 43 ptrunkop11

9 FLAG1 BC CASE 143 TRNKOP 0 LIQ_CAP 0 LIQ_OP 43 PTRUNKOP

This macro copies the correct profile to the cashflow sheet, based on FLAG

\i {if FLAG1=1}{branch MAC1}

{if FLAG1=2}{branch MAC2}

{if FLAG1=3}{branch MAC3}

{if FLAG1=4}{branch MAC4}

{if FLAG1=5}{branch MAC5}

{if FLAG1=6}{branch MAC6}

{if FLAG1=7}{branch MAC7} {BlockValues PROD1~RAWPROD}

{if FLAG1=8}{branch MAC8}

{if FLAG1=9}{branch MAC9}

{if FLAG1=10}{branch MAC10} {edit}{bs}}~

{if FLAG1=11}{branch MAC11} {edit}{home}

\j {goto}GASTYPE~

{edit}{home}{del}{del}{del}{del}BlockValues ~{down}

mac1 {BlockValues PROD1,RAWPROD} production profile

{BlockValues FUEL1,FUEL} fuel profile

{BlockValues FLOW1,FLOW} flowline capex

{BlockValues COMP1,COMP} compressor capex

{BlockValues PLANT1,PLANT} plant capex 5 5 5 5 5 5 5 5 5 5 5 4.875204

{BlockValues TRUNK1,TRUNK} trunkline capex

{BlockValues PTRUNK1,PTRUNK} trunkline capex to satellite (plant access case only)

{BlockValues FLDOP1,FLDOP} field facilities opex

{BlockValues W_OPEX1,WELLOPEX} well opex

{BlockValues CMPOP1,CMPOP} compressor opex

{BlockValues CASE1,CASE} case, for plant opex

{BlockValues TRNKOP1,TRNKOP} trunkline opex

{BlockValues PTRUNKOP1,PTRUNKOP} trunkline opex to satellite (plant access case only)

{BlockValues LIQ_CAP1,LIQ_CAP} liquids line capex

{BlockValues LIQ_OP1,LIQ_OP} liquids line opex

{BlockValues WELL1,WELL} wells drilled

{branch \j} goto output table

Page 26: Economics of Gas Gathering Cashflow

prod_profile

Page 26

FIELDS PRODUCTION PROFILES AND WELL REQUIREMENTS

Data generated by MESA in c:\gen\gpa\lean\bhp.wb1

For completeness, minimum rate set to 0.01 mmmscfd (this is required for computational purposes)

time increment inc1 0.5

time increment inc2 0.25

CASE FIELD WELLS DEPLN MAX. Year 0 Year 1

SIZE RATE RATE

(bcf) (% pa) (KSCMD)

single 100 10 0.05 386 bcf/yr prod1 0 5

wells drille well1 3 0

wells on 0 3

single 50 5 0.05 193 bcf/yr prod2 0 2.5

wells drille well2 2 0

wells on 0 2

single 50 5 0.1 386 bcf/yr prod3 0 5

wells drille well3 3 1

wells on 0 3

single 10 1 0.05 39 bcf/yr prod4 0 0.5

wells drille well4 1 0

wells on 0 1

single 10 1 0.1 77 bcf/yr prod5 0 1

wells drille well5 1 0

wells on 0 1

multiple 50 5 0.05 193 bcf/yr prod6 0 2.5

wells drille well6 2 0

wells on 0 2

multiple 50 5 0.1 386 bcf/yr prod7 0 5

wells drille well7 4 1

wells on 0 4

increment 10 1 0.05 39 bcf/yr 0 0.5

wells drilled 1 0

wells on 0 1

increment 10 1 0.1 77 bcf/yr 0 1

wells drilled 1 0

wells on 0 1

single 10 1 0.2 154 bcf/yr prod8 0 1.966375

wells drille well8 1 0

wells on 0 1

multiple 20 2 193 bcf/yr prod9 0 2.5

depleted at rate equivalent to 50 bcf @ 5%/yr wells drille well9 2 0

wells on 0 2

multiple 30 3 193 bcf/yr prod10 0 2.5

depleted at rate equivalent to 50 bcf @ 5%/yr wells drille well10 2 1

Page 27: Economics of Gas Gathering Cashflow

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Page 27

wells on 0 2

multiple 40 4 193 bcf/yr prod11 0 2.5

depleted at rate equivalent to 50 bcf @ 5%/yr wells drille well11 2 1

wells on 0 2

multiple 10 2 193 bcf/yr 0 2.13

depleted at rate equivalent to 50 bcf @ 5%/yr wells drilled 2 0

wells on 0 2

Page 28: Economics of Gas Gathering Cashflow

prod_profile

Page 28

Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10

5 5 5 5 5 5 5 5 5

1 0 1 1 2 2 0 0 0

3 4 4 5 6 8 10 10 10

2.5 2.5 2.5 2.5 2.5 2.5 2.5 2.5 2.5

0 0 1 0 1 1 0 0 0

2 2 2 3 3 4 5 5 5

5 5 5 4.296224 3.275937 2.585117 2.067255 1.701538 1.407877

1 0 0 0 0 0 0 0 0

4 5 5 5 5 5 5 5 5

0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

1 1 1 0.859245 0.655187 0.517023 0.413451 0.340308 0.281575

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

2.5 2.5 2.5 2.5 2.5 2.5 2.5 2.5 2.5

1 0 1 0 1 0 0 0 0

2 3 3 4 4 5 5 5 5

5 5 5 4.614243 3.355681 2.501263 1.96238 1.559237 1.220574

0 0 0 0 0 0 0 0 0

5 5 5 5 5 5 5 5 5

0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

1 1 1 0.8731 0.653173 0.515976 0.411876 0.339916 0.281217

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

1.465698 1.037588 0.771942 0.59646 0.474412 0.382599 0.316615 0.262708 0.223588

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

2.5 2.441003 1.812324 1.300235 0.97111 0.747625 0.578427 0.463392 0.365471

0 0 0 0 0 0 0 0 0

2 2 2 2 2 2 2 2 2

2.5 2.5 2.5 2.5 2.5 1.970874 1.452722 1.102538 0.826837

0 0 0 0 0 0 0 0 0

Page 29: Economics of Gas Gathering Cashflow

prod_profile

Page 29

3 3 3 3 3 3 3 3 3

2.5 2.5 2.5 2.5 2.5 2.5 2.5 2.5 2.158825

0 1 0 0 0 0 0 0 0

3 3 4 4 4 4 4 4 4

1.34 0.9 0.64 0.45 0.35 0.27 0.18 0.15 0.14

0 0 0 0 0 0 0 0 0

2 2 2 2 2 2 2 2 2

Page 30: Economics of Gas Gathering Cashflow

prod_profile

Page 30

Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19

5 4.875204 4.045991 3.337398 2.761915 2.335977 2.00194 1.714664 1.502658

0 0 0 0 0 0 0 0 0

10 10 10 10 10 10 10 10 10

2.5 2.437602 2.022996 1.668699 1.380958 1.167989 1.00097 0.857332 0.751329

0 0 0 0 0 0 0 0 0

5 5 5 5 5 5 5 5 5

1.186353 1.01613 0.869921 0.761388 0.665292 0.589941 0.517813 0.456326 0.412764

0 0 0 0 0 0 0 0 0

5 5 5 5 5 5 5 5 5

0.5 0.48752 0.404599 0.33374 0.276192 0.233598 0.200194 0.171466 0.150266

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

0.237271 0.203226 0.173984 0.152278 0.133058 0.117988 0.103563 0.091265 0.082553

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

2.5 2.5 2.398699 1.861407 1.405011 1.109368 0.851375 0.69597 0.586047

0 0 0 0 0 0 0 0 0

5 5 5 5 5 5 2 2 2

0.960781 0.833498 0.729224 0.607134 0.494786 0.386134 0.304515 0.235691 0.166866

0 0 0 0 0 0 0 0 0

5 5 5 5 5 5 5 5 5

0.5 0.5 0.411545 0.333054 0.274274 0.230313 0.199484 0.1702 0.150266

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

0.236586 0.202832 0.173918 0.152278 0.132862 0.117988 0.103563 0.090913 0.082553

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

0.191794 0.16487 0.144676 0.126948 0.112494 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

0.304792 0.244113 0.18856 0.157457 0.129378 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0 0 0

2 2 2 2 2 2 2 2 2

0.684372 0.572124 0.467245 0.371041 0.292118 0.213195 0.147685 0.01 0.01

0 0 0 0 0 0 0 0 0

Page 31: Economics of Gas Gathering Cashflow

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Page 31

3 3 3 3 3 3 3 3 3

1.575212 1.255107 0.980239 0.776684 0.605711 0.495881 0.424991 0.355107 0.287773

0 0 0 0 0 0 0 0 0

4 4 4 4 4 4 4 4 4

0.1 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0 0 0

2 2 2 2 2 2 2 2 2

Page 32: Economics of Gas Gathering Cashflow

prod_profile

Page 32

Year 20 Year 21 Year 22 Year 23 Year 24 Year 25 Year 26

1.313255 1.165341 1.021085 0.903821 0.816751 0.729681 0.642611

0 0 0 0 0 0 0

10 10 10 10 10 10 10

0.656627 0.58267 0.510542 0.451911 0.408375 0.36484 0.321305

0 0 0 0 0 0 0

5 5 5 5 5 5 5

0.369229 0.325694 0.284612 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0

5 5 5 5 5 5 5

0.131325 0.116534 0.102108 0.090382 0.081675 0.072968 0.064261

0 0 0 0 0 0 0

1 1 1 1 1 1 1

0.073846 0.065139 0.01 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0

1 1 1 1 1 1 1

0.481388 0.380059 0.297331 0.218085 0.138839 0.103368 0.093796

0 0 0 0 0 0 0

2 2 2 2 2 2 2

0.110919 0.098233 0.01 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0

5 5 5 5 5 5 5

0.130308 0.116534 0.102108 0.089747 0.081675 0.072968 0.064261

0 0 0 0 0 0 0

1 1 1 1 1 1 1

0.073846 0.065139 0.01 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0

1 1 1 1 1 1 1

0.01 0.01 0.01 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0

1 1 1 1 1 1 1

0.01 0.01 0.01 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0

2 2 2 2 2 2 2

0.01 0.01 0.01 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0

Page 33: Economics of Gas Gathering Cashflow

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Page 33

3 3 3 3 3 3 3

0.22044 0.01 0.01 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0

4 4 4 4 4 4 4

0.01 0.01 0.01 0.01 0.01 0.01 0.01

0 0 0 0 0 0 0

2 2 2 2 2 2 2

Page 34: Economics of Gas Gathering Cashflow

conv_fact

Page 34

SALES GAS HEATING VALUES

LPG Sales Gas HV Fuel Gas Avail Ratio Shrinkage Cond. Content

Recovery (MJ/m3) (SCM/SCM) (M3/KSCM)

BROLGA Pat rich high CO2 no 43.91 heat1 0.091795 richfuel 0.474227 shk1 0.304124 liq1

COOBA Pat lean high CO2 no 42.99 heat2 0.007344 leanfuel 0.497423 shk2 0.007732 liq2

GIDG STH Pat rich low CO2 no 43.91 heat3 0.091795 0.737113 shk3 0.335052 liq3

DELLA Too/Pat lean low CO2 no 42.99 heat4 0.007344 0.809278 shk4 0.015464 liq4

see file note 6/5/96 from GPA Table 9 from GPA Table 7.4 from GPA Table 7.4

SR 28/1/202/1 vol 2

12/8/97 - see note to file. Della HV is too high, and should be 37.5 MJ/m3.

This has not been chaged to avoid confusion with published data. I suspect it makes little difference to any results.

LPG RECOVERY CASE Cond. Content LPG Content Total Liquids Content

(M3/KSCM raw gas) (t/KSCM raw gas) (M3/KSCM raw gas)

BROLGA Pat rich high CO2 yes 40.72 heat5 0 lpgfuel 0.404639 shk5 0.331959 liq5 0.13634 lpg5 0.592784 totliq5

GIDG STH Pat rich low CO2 yes 40.82 heat6 0 0.590206 shk6 0.277062 liq6 0.196198 lpg6 0.64433 totliq6

HV calculated in c:\gen\prop\bg.wb1 from GPA Fax 23/4/96 see hand-written memo to file 30/4/96

PRODUCT YIELDS BASED ON MOOMBA PLANT

Data calculated in c:\gen\prop\bg.wb1

nb: assumes field fuel = 2.4% of raw gas, and plant fuel = 6.8% of sales gas

Sales Gas HV Sales Gas Yield LPG Yield Condensate Yield

(MJ/m3) (GJ/mmscf raw gas) (t/mmscf raw gas) (bbls/mmscf raw gas)

BROLGA Pat rich high CO2 40.78 593.77 3.61 55.84

COOBA Pat lean high CO2 40.46 584 1.87 4.33

GIDG STH Pat rich low CO2 40.88 804.6 5.52 49.15

DELLA Too/Pat lean low CO2 36.82 832.7 0.54 3.11

metric units

Sales Gas HV Sales Gas Yield LPG Yield Condensate Yield

(MJ/m3) (PJ/KSCM raw gas) (t/KSCM raw gas) (M3/KSCM raw gas)

BROLGA Pat rich high CO2 40.78 2.108E-05 sales1 0.128132 lpg1 0.315109 cond1

COOBA Pat lean high CO2 40.46 2.073E-05 sales2 0.066373 lpg2 0.024434 cond2

GIDG STH Pat rich low CO2 40.88 2.856E-05 sales3 0.195925 lpg3 0.277356 cond3

DELLA Too/Pat lean low CO2 36.82 2.956E-05 sales4 0.019167 lpg4 0.01755 cond4

Page 35: Economics of Gas Gathering Cashflow

plant

Page 35

CAPITAL EXPENDITURE ESTIMATES

PROCESSING PLANT CONSTRUCTION COSTS AND INITIAL THROUGHPUT

GPA REPORT

SECTION 7.4 (updated 19 March 1996)

**** UPDATE 1/5/96 **** If LPG recovery is used, sales gas, liquid rate and capex are updated according to

GPA fax dated 23 April 1996. This is only applied for rich fields with rates >= 190 KSCMD, (Cases AA, AC, BA, BC).

CAPEX INCURRED IN YEAR 0

CASE FIELD WELLS DEPLN LIQUIDS CO2 RAW SALES APPROX. CAPEX

SIZE RATE CONTENT CONTENT GAS GAS COND/LIQ

(bcf) (% pa) (KSCMD) (KSCMD) (M3/D) (1995$K)

AA 100 10 0.05 rich high 388 184 118 pcap_aa 5270

AA 50 5 0.1 rich high 388 184 118 5270

AB 100 10 0.05 lean high 388 193 3 pcap_ab 5380

AB 50 5 0.1 lean high 388 193 3 5380

AC 100 10 0.05 rich low 388 286 130 pcap_ac 4690

AC 50 5 0.1 rich low 388 286 130 4690

AD 100 10 0.05 lean low 388 314 6 pcap_ad 5250

AD 50 5 0.1 lean low 388 314 6 5250

BA 50 5 0.05 rich high 194 93 59 pcap_ba 4050

BB 50 5 0.05 lean high 194 96 1.5 pcap_bb 4100

BC 50 5 0.05 rich low 194 142 65 pcap_bc 3890

BD 50 5 0.05 lean low 194 155 3 pcap_bd 3970

CA 10 1 0.1 rich high 77 37 23 pcap_ca 2370

CB 10 1 0.1 lean high 77 40 0.6 pcap_cb 2410

CC 10 1 0.1 rich low 77 57 26 pcap_cc 2300

CD 10 1 0.1 lean low 77 62 1.2 pcap_cd 2360

DA 10 1 0.05 rich high 39 18 12 pcap_da 1680

DB 10 1 0.05 lean high 39 19 0.3 pcap_db 1700

DC 10 1 0.05 rich low 39 28 13 pcap_dc 1650

DD 10 1 0.05 lean low 39 31 0.6 pcap_dd 1670

Page 36: Economics of Gas Gathering Cashflow

facilities

Page 36

CAPITAL EXPENDITURE ESTIMATES

WELLHEAD FACILITIES AND FLOWLINES

GPA REPORT

SECTION 7.1

CASE FIELD WELLS DEPLN CAPEX

SIZE RATE Year 0 Year 1 Year 2 Year 3

(bcf) (% pa) (1995$K) (1995$K) (1995$K) (1995$K)

single 100 10 0.05 flow1 634 0 238 0

single 50 5 0.05 flow2 396 0 0 0

single 50 5 0.1 flow3 634 238 238 0

single 10 1 0.05 flow4 160 0 0 0

single 10 1 0.1 flow5 160 0 0 0

multiple 50 5 0.05 flow6 1110 0 0 950

multiple 50 5 0.1 flow7 2060 950 950 0

increment 10 1 0.05 1995 0 0 0

increment 10 1 0.1 1995 0 0 0

single 10 1 0.2 flow8 160 0 0 0

multiple 20 2 5% of 50 flow9 1110 0 0 0

multiple 30 3 5% of 50 flow10 1110 950 0 0

multiple 40 4 5% of 50 flow11 1110 950 0 0

NOTE: 2, 3, and 4 fields cases based on 5 field case at 5% depletion

Assume 1 well at plant and the rest are 10 km away

Based on single well and multiple field costs, cost of first well is $160k, cost of subsequent wells is $950k

2 field case, 2 wells are required for the start of Year 1

3 field case, 2 wells are required for the start of Year 1, 1 well is required for the start of Year 2

4 field case, 2 wells are required for the start of Year 1, 1 well is required for the start of Year 2, 1 well is required in the middle of year 4

For consistency, 5 field case has also been adjusted

GPA adjusted

multiple 50 5 0.05 1900 1110

multiple 50 5 0.1 2850 2060

Well head cost = $150k

Flowline Cost = $800k/km

Page 37: Economics of Gas Gathering Cashflow

facilities

Page 37

Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

238 246 484 484 0 0 0 0 0

238 0 238 246 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 950 0 950 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

950 0 0 0 0 0 0 0 0

Based on single well and multiple field costs, cost of first well is $160k, cost of subsequent wells is $950k

3 field case, 2 wells are required for the start of Year 1, 1 well is required for the start of Year 2

4 field case, 2 wells are required for the start of Year 1, 1 well is required for the start of Year 2, 1 well is required in the middle of year 4

Page 38: Economics of Gas Gathering Cashflow

facilities

Page 38

Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

Page 39: Economics of Gas Gathering Cashflow

facilities

Page 39

Year 22 Year 23 Year 24 Year 25 Year 26

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

Page 40: Economics of Gas Gathering Cashflow

compression

Page 40

CAPITAL EXPENDITURE ESTIMATES

FIELD BOOST COMPRESSION

GPA REPORT

SECTION 7.2

CASE FIELD WELLS DEPLN CAPEX

SIZE RATE Year 0 Year 1 Year 2 Year 3

(bcf) (% pa) (1995$K) (1995$K) (1995$K) (1995$K)

single 100 10 0.05 comp1 0 0 0 0

single 50 5 0.05 comp2 0 0 0 0

single 50 5 0.1 comp3 0 0 600 1120

single 10 1 0.05 comp4 0 0 0 0

single 10 1 0.1 comp5 0 0 150 250

multiple 50 5 0.05 comp6 0 0 0 0

multiple 50 5 0.1 comp7 0 0 420 1060

increment 10 1 0.05 0 0 0 0

increment 10 1 0.1 0 0 0 0

single 10 1 0.1 comp8 0 1470 0 0

multiple 20 2 5% of 50 comp9 0 720 750 0

multiple 30 3 5% of 50 comp10 0 0 0 300

multiple 40 4 5% of 50 comp11 0 0 0 0

NOTE: 2, 3, and 4 fields cases based on 5 field case at 5% depletion

2 field case, stage 1 compression required by start Year 2, stage 2 compression required by start Year 3

3 field case, stage 1 compression required by mid Year 4, stage 2 compression required by start Year 6

4 field case, stage 1 compression required by mid Year 6, stage 2 compression required by mid Year 8

Page 41: Economics of Gas Gathering Cashflow

compression

Page 41

Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

0 0 0 300 1020 0 600 800 0

0 0 0 220 500 0 300 450 0

1000 0 0 0 0 0 0 0 0

0 0 0 0 150 0 50 100 0

200 0 0 0 0 0 0 0 0

0 0 0 0 300 420 0 300 450

1400 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

720 450 0 0 0 0 0 0 0

0 300 420 300 450 0 0 0 0

2 field case, stage 1 compression required by start Year 2, stage 2 compression required by start Year 3

3 field case, stage 1 compression required by mid Year 4, stage 2 compression required by start Year 6

4 field case, stage 1 compression required by mid Year 6, stage 2 compression required by mid Year 8

Page 42: Economics of Gas Gathering Cashflow

compression

Page 42

Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

Page 43: Economics of Gas Gathering Cashflow

compression

Page 43

Year 22 Year 23 Year 24 Year 25 Year 26

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

0 0 0 0 0

Page 44: Economics of Gas Gathering Cashflow

trunk

Page 44

LIQUIDS TRUNKLINE (RICH FIELDS ONLY)

CASE LIQUIDS CAPEX

FLOW RATE 20 km 50 km 100 km

(m3/d) (1995$K) (1995$K) (1995$K)

20 50 100

AA 230 870 2406 4506

AC 250 870 2406 4506

BA 115 870 1706 4506

BC 125 870 1706 4506

Page 45: Economics of Gas Gathering Cashflow

field_opex

Page 45

OPERATING EXPENDITURE ESTIMATES

FIELD FACILITIES

GPA REPORT

SECTION 8.1

CASE FIELD WELLS DEPLN OPEX

SIZE RATE Year 0 Year 1 Year 2 Year 3

(bcf) (% pa) (1995$K) (1995$K) (1995$K) (1995$K)

single 100 10 0.05 fldop1 0 19 19 26

single 50 5 0.05 fldop2 0 12 12 12

single 50 5 0.1 fldop3 0 12 12 12

single 10 1 0.05 fldop4 0 7 7 7

single 10 1 0.1 fldop5 0 7 7 7

multiple 50 5 0.05 fldop6 0 57 57 71

multiple 50 5 0.1 fldop7 0 85 114 142

increment 10 1 0.05 0 92 92 92

increment 10 1 0.1 0 92 92 92

single 10 1 0.2 fldop8 0 7 7 7

multiple 20 2 5% of 50 fldop9 0 57 57 57

multiple 30 3 5% of 50 fldop10 0 57 86 86

multiple 40 4 5% of 50 fldop11 0 57 86 86

Based on Multiple Field, 5 well case @ 5% depletion

Wells OPEX

2 57

3 86

4 114

DOWNHOLE AND SURFACE OPEX

Based on MESA in-house estimates

Downhole 45 ($k/well)

Surface 0 ($k/well)

CASE FIELD WELLS DEPLN

SIZE RATE

(bcf) (% pa) Year 0 Year 1 Year 2 Year 3

(1995$K) (1995$K) (1995$K) (1995$K)

single 100 10 0.05 wells on 0 3 3 4

downhole1 0 135 135 180

surface1 0 0 0 0

single 50 5 0.05 wells on 0 2 2 2

Page 46: Economics of Gas Gathering Cashflow

field_opex

Page 46

downhole2 0 90 90 90

surface2 0 0 0 0

single 50 5 0.1 wells on 0 3 4 5

downhole3 0 135 180 225

surface3 0 0 0 0

single 10 1 0.05 wells on 0 1 1 1

downhole4 0 45 45 45

surface4 0 0 0 0

single 10 1 0.1 wells on 0 1 1 1

downhole5 0 45 45 45

surface5 0 0 0 0

multiple 50 5 0.05 wells on 0 2 2 3

downhole6 0 90 90 135

surface6 0 0 0 0

multiple 50 5 0.1 wells on 0 4 5 5

downhole7 0 180 225 225

surface7 0 0 0 0

increment 10 1 0.05 wells on 0 1 1 1

downhole 0 45 45 45

surface 0 0 0 0

increment 10 1 0.1 wells on 0 1 1 1

downhole 0 45 45 45

surface 0 0 0 0

single 10 1 0.2 wells on 0 1 1 1

downhole8 0 45 45 45

surface8 0 0 0 0

multiple 20 2 5% of 50 wells on 0 2 2 2

downhole9 0 90 90 90

surface9 0 0 0 0

multiple 30 3 5% of 50 wells on 0 2 3 3

downhole10 0 90 135 135

surface10 0 0 0 0

multiple 40 4 5% of 50 wells on 0 2 3 3

downhole11 0 90 135 135

surface11 0 0 0 0

Page 47: Economics of Gas Gathering Cashflow

field_opex

Page 47

Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

26 33 41 55 70 70 70 70 70

19 19 19 26 34 34 34 34 34

19 19 19 26 34 34 34 34 34

7 7 7 7 7 7 7 7 7

7 7 7 7 7 7 7 7 7

86 100 114 128 142 142 142 142 142

142 142 142 142 142 142 142 142 142

92 92 92 92 92 92 92 92 92

92 92 92 92 92 92 92 92 92

7 7 7 7 7 7 7 7 7

57 57 57 57 57 57 57 57 57

86 86 86 86 86 86 86 86 86

114 114 114 114 114 114 114 114 114

Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

4 5 6 8 10 10 10 10 10

180 225 270 360 450 450 450 450 450

0 0 0 0 0 0 0 0 0

2 3 3 4 5 5 5 5 5

Page 48: Economics of Gas Gathering Cashflow

field_opex

Page 48

90 135 135 180 225 225 225 225 225

0 0 0 0 0 0 0 0 0

5 5 5 5 5 5 5 5 5

225 225 225 225 225 225 225 225 225

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45

0 0 0 0 0 0 0 0 0

3 4 4 5 5 5 5 5 5

135 180 180 225 225 225 225 225 225

0 0 0 0 0 0 0 0 0

5 5 5 5 5 5 5 5 5

225 225 225 225 225 225 225 225 225

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45

0 0 0 0 0 0 0 0 0

2 2 2 2 2 2 2 2 2

90 90 90 90 90 90 90 90 90

0 0 0 0 0 0 0 0 0

3 3 3 3 3 3 3 3 3

135 135 135 135 135 135 135 135 135

0 0 0 0 0 0 0 0 0

4 4 4 4 4 4 4 4 4

180 180 180 180 180 180 180 180 180

0 0 0 0 0 0 0 0 0

Page 49: Economics of Gas Gathering Cashflow

field_opex

Page 49

Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

70 70 70 70 70 70 70 70 70

34 34 34 34 34 34 34 34 34

34 34 34 34 34 34 34 34 34

7 7 7 7 7 7 7 7 7

7 7 7 7 7 7 7 7 7

142 142 142 142 142 142 142 142 142

142 142 142 142 142 142 142 142 142

92 92 92 92 92 92 92 92 92

92 92 92 92 92 92 92 92 92

7 7 7 7 7 7 7 7 7

57 57 57 57 57 57 57 57 57

86 86 86 86 86 86 86 86 86

114 114 114 114 114 114 114 114 114

Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

10 10 10 10 10 10 10 10 10

450 450 450 450 450 450 450 450 450

0 0 0 0 0 0 0 0 0

5 5 5 5 5 5 5 5 5

Page 50: Economics of Gas Gathering Cashflow

field_opex

Page 50

225 225 225 225 225 225 225 225 225

0 0 0 0 0 0 0 0 0

5 5 5 5 5 5 5 5 5

225 225 225 225 225 225 225 225 225

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45

0 0 0 0 0 0 0 0 0

5 5 5 5 2 2 2 2 2

225 225 225 225 90 90 90 90 90

0 0 0 0 0 0 0 0 0

5 5 5 5 5 5 5 5 5

225 225 225 225 225 225 225 225 225

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45

0 0 0 0 0 0 0 0 0

1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45

0 0 0 0 0 0 0 0 0

2 2 2 2 2 2 2 2 2

90 90 90 90 90 90 90 90 90

0 0 0 0 0 0 0 0 0

3 3 3 3 3 3 3 3 3

135 135 135 135 135 135 135 135 135

0 0 0 0 0 0 0 0 0

4 4 4 4 4 4 4 4 4

180 180 180 180 180 180 180 180 180

0 0 0 0 0 0 0 0 0

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Page 51

Year 22 Year 23 Year 24 Year 25 Year 26

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

70 70 70 70 70

34 34 34 34 34

34 34 34 34 34

7 7 7 7 7

7 7 7 7 7

142 142 142 142 142

142 142 142 142 142

92 92 92 92 92

92 92 92 92 92

7 7 7 7 7

57 57 57 57 57

86 86 86 86 86

114 114 114 114 114

Year 22 Year 23 Year 24 Year 25 Year 26

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

10 10 10 10 10

450 450 450 450 450

0 0 0 0 0

5 5 5 5 5

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225 225 225 225 225

0 0 0 0 0

5 5 5 5 5

225 225 225 225 225

0 0 0 0 0

1 1 1 1 1

45 45 45 45 45

0 0 0 0 0

1 1 1 1 1

45 45 45 45 45

0 0 0 0 0

2 2 2 2 2

90 90 90 90 90

0 0 0 0 0

5 5 5 5 5

225 225 225 225 225

0 0 0 0 0

1 1 1 1 1

45 45 45 45 45

0 0 0 0 0

1 1 1 1 1

45 45 45 45 45

0 0 0 0 0

1 1 1 1 1

45 45 45 45 45

0 0 0 0 0

2 2 2 2 2

90 90 90 90 90

0 0 0 0 0

3 3 3 3 3

135 135 135 135 135

0 0 0 0 0

4 4 4 4 4

180 180 180 180 180

0 0 0 0 0

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OPERATING EXPENDITURE ESTIMATES

FIELD BOOST COMPRESSION

GPA REPORT

SECTION 8.2

CASE FIELD WELLS DEPLN OPEX

SIZE RATE Year 0 Year 1 Year 2 Year 3

(bcf) (% pa) (1995$K) (1995$K) (1995$K) (1995$K)

single 100 10 0.05 cmpop1 0 0 0 0

single 50 5 0.05 cmpop2 0 0 0 0

single 50 5 0.1 cmpop3 0 0 0 76

single 10 1 0.05 cmpop4 0 0 0 0

single 10 1 0.1 cmpop5 0 0 0 33

multiple 50 5 0.05 cmpop6 0 0 0 0

multiple 50 5 0.1 cmpop7 0 0 0 48

increment 10 1 0.05 0 0 0 0

increment 10 1 0.1 0 0 0 0

single 10 1 0.2 cmpop8 0 111 111 111

multiple 20 2 5% of 50 cmpop9 0 0 61 125

multiple 30 3 5% of 50 cmpop10 0 0 0 0

multiple 40 4 5% of 50 cmpop11 0 0 0 0

NOTE: 2, 3, and 4 fields cases based on 5 field case at 5% depletion

2 field case, stage 1 compression required by start Year 2, stage 2 compression required by start Year 3

3 field case, stage 1 compression required by mid Year 4, stage 2 compression required by start Year 6

4 field case, stage 1 compression required by mid Year 6, stage 2 compression required by mid Year 8

FUEL GAS REQUIREMENTS

GPA REPORT

SECTION 8.2

CASE FIELD WELLS DEPLN FUEL GAS

SIZE RATE Year 0 Year 1 Year 2 Year 3

(bcf) (% pa) (KSMCD) (KSMCD) (KSMCD) (KSMCD)

single 100 10 0.05 0 0 0 0

single 50 5 0.05 0 0 0 0

single 50 5 0.1 0 0 0 1.863014

single 10 1 0.05 0 0 0 0

single 10 1 0.1 0 0 0 0.767123

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multiple 50 5 0.05 0 0 0 0

multiple 50 5 0.1 0 0 0 0.931507

increment 10 1 0.05 0 0 0 0

increment 10 1 0.1 0 0 0 0

single 10 1 0.2 0 4.027397 4.027397 4.027397

multiple 20 2 5% of 50 0 0 1.86 6.71

multiple 30 3 5% of 50 0 0 0 0

multiple 40 4 5% of 50 0 0 0 0

NOTE: 2, 3, and 4 fields cases based on 5 field case at 5% depletion

2 field case, stage 1 compression required by start Year 2, stage 2 compression required by start Year 3

3 field case, stage 1 compression required by mid Year 4, stage 2 compression required by start Year 6

4 field case, stage 1 compression required by mid Year 6, stage 2 compression required by mid Year 8

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Page 55

Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

0 0 0 0 20 112 112 172 231

0 0 0 0 20 56 56 83 111

142 231 231 231 231 231 231 231 231

0 0 0 0 0 20 13 13 20

32 51 51 51 51 51 51 51 51

0 0 0 0 0 51 61 61 82

112 245 245 245 245 245 245 245 245

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

111 111 111 111 111 111 111 111 111

125 125 125 125 125 125 125 125 125

61 61 125 125 125 125 125 125 125

0 0 61 61 125 125 125 125 125

2 field case, stage 1 compression required by start Year 2, stage 2 compression required by start Year 3

3 field case, stage 1 compression required by mid Year 4, stage 2 compression required by start Year 6

4 field case, stage 1 compression required by mid Year 6, stage 2 compression required by mid Year 8

Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Year 11 Year 12

(KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD)

0 0 0 0 0 3.69863 3.69863 5.890411 8.082192

0 0 0 0 0 1.863014 1.863014 2.958904 4.027397

2.958904 8.082192 8.082192 8.082192 8.082192 8.082192 8.082192 8.082192 8.082192

0 0 0 0 0 0 0.410959 0.410959 0.630137

1.424658 1.643836 1.643836 1.643836 1.643836 1.643836 1.643836 1.643836 1.643836

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0 0 0 0 0 0.931507 1.863014 1.863014 2.958904

3.69863 8.054795 8.054795 8.054795 8.054795 8.054795 8.054795 8.054795 8.054795

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

4.027397 4.027397 4.027397 4.027397 4.027397 4.027397 4.027397 4.027397 4.027397

6.71 6.71 6.71 6.71 6.71 6.71 6.71 6.71 6.71

1.86 1.86 6.71 6.71 6.71 6.71 6.71 6.71 6.71

0 0 1.86 1.86 6.71 6.71 6.71 6.71 6.71

2 field case, stage 1 compression required by start Year 2, stage 2 compression required by start Year 3

3 field case, stage 1 compression required by mid Year 4, stage 2 compression required by start Year 6

4 field case, stage 1 compression required by mid Year 6, stage 2 compression required by mid Year 8

Page 57: Economics of Gas Gathering Cashflow

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Page 57

Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

231 231 231 231 231 231 231 231 231

111 111 111 111 111 111 111 111 111

231 231 231 231 231 231 231 231 231

26 26 26 26 26 26 26 26 26

51 51 51 51 51 51 51 51 51

125 125 125 125 125 125 125 125 125

245 245 245 245 245 245 245 245 245

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

111 111 111 111 111 111 111 111 111

125 125 125 125 125 125 125 125 125

125 125 125 125 125 125 125 125 125

125 125 125 125 125 125 125 125 125

Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19 Year 20 Year 21

(KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD)

8.082192 8.082192 8.082192 8.082192 8.082192 8.082192 8.082192 8.082192 8.082192

4.027397 4.027397 4.027397 4.027397 4.027397 4.027397 4.027397 4.027397 4.027397

8.082192 8.082192 8.082192 8.082192 8.082192 8.082192 8.082192 8.082192 8.082192

0.821918 0.821918 0.821918 0.821918 0.821918 0.821918 0.821918 0.821918 0.821918

1.643836 1.643836 1.643836 1.643836 1.643836 1.643836 1.643836 1.643836 1.643836

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6.712329 6.712329 6.712329 6.712329 6.712329 6.712329 6.712329 6.712329 6.712329

8.054795 8.054795 8.054795 8.054795 8.054795 8.054795 8.054795 8.054795 8.054795

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

4.027397 4.027397 4.027397 4.027397 4.027397 4.027397 4.027397 4.027397 4.027397

6.71 6.71 6.71 6.71 6.71 6.71 6.71 6.71 6.71

6.71 6.71 6.71 6.71 6.71 6.71 6.71 6.71 6.71

6.71 6.71 6.71 6.71 6.71 6.71 6.71 6.71 6.71

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Year 22 Year 23 Year 24 Year 25 Year 26

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

231 231 231 231 231

111 111 111 111 111

231 231 231 231 231

26 26 26 26 26

51 51 51 51 51

125 125 125 125 125

245 245 245 245 245

0 0 0 0 0

0 0 0 0 0

111 111 111 111 111

125 125 125 125 125

125 125 125 125 125

125 125 125 125 125

Year 22 Year 23 Year 24 Year 25 Year 26

(KSMCD) (KSMCD) (KSMCD) (KSMCD) (KSMCD)

8.082192 8.082192 8.082192 8.082192 8.082192

4.027397 4.027397 4.027397 4.027397 4.027397

8.082192 8.082192 8.082192 8.082192 8.082192

0.821918 0.821918 0.821918 0.821918 0.821918

1.643836 1.643836 1.643836 1.643836 1.643836

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6.712329 6.712329 6.712329 6.712329 6.712329

8.054795 8.054795 8.054795 8.054795 8.054795

0 0 0 0 0

0 0 0 0 0

4.027397 4.027397 4.027397 4.027397 4.027397

6.71 6.71 6.71 6.71 6.71

6.71 6.71 6.71 6.71 6.71

6.71 6.71 6.71 6.71 6.71

Page 61: Economics of Gas Gathering Cashflow

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Page 61

OPERATING EXPENDITURE ESTIMATES

PROCESSING PLANT OPEX

GPA REPORT

SECTION 8.3

**** UPDATE 1/5/96 **** If LPG recovery is used, opex is updated according to

GPA fax dated 23 April 1996. This is only applied for rich fields with rates >= 190 KSCMD, (Cases AA, AC, BA, BC).

CASE FIELD WELLS DEPLN LIQUIDS CO2 OPEX

SIZE RATE CONTENT CONTENT Year 0 Year 1

(bcf) (% pa) (1995$K) (1995$K)

AA 100 10 0.05 rich high pop_aa 0 816

AA 50 5 0.1 rich high 0 816

AB 100 10 0.05 lean high pop_ab 0 816

AB 50 5 0.1 lean high 0 816

AC 100 10 0.05 rich low pop_ac 0 816

AC 50 5 0.1 rich low 0 816

AD 100 10 0.05 lean low pop_ad 0 816

AD 50 5 0.05 lean low 0 816

BA 50 5 0.05 rich high pop_ba 0 791

BB 50 5 0.05 lean high pop_bb 0 791

BC 50 5 0.05 rich low pop_bc 0 791

BD 50 5 0.05 lean low pop_bd 0 791

CA 10 1 0.1 rich high pop_ca 0 764

CB 10 1 0.1 lean high pop_cb 0 764

CC 10 1 0.1 rich low pop_cc 0 764

CD 10 1 0.1 lean low pop_cd 0 764

DA 10 1 0.05 rich high pop_da 0 751

DB 10 1 0.05 lean high pop_db 0 751

DC 10 1 0.05 rich low pop_dc 0 751

DD 10 1 0.05 lean low pop_dd 0 751

Column 1 2 3 4 5 6 7

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GPA fax dated 23 April 1996. This is only applied for rich fields with rates >= 190 KSCMD, (Cases AA, AC, BA, BC).

Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

816 816 936 936 936 936 936 936 936

816 816 936 936 936 936 936 936 936

816 816 984 984 984 984 984 984 984

816 816 984 984 984 984 984 984 984

816 816 900 900 900 900 900 900 900

816 816 900 900 900 900 900 900 900

816 816 948 948 948 948 948 948 948

816 816 948 948 948 948 948 948 948

791 791 851 851 851 851 851 851 851

791 791 875 875 875 875 875 875 875

791 791 833 833 833 833 833 833 833

791 791 857 857 857 857 857 857 857

764 764 789 789 789 789 789 789 789

764 764 798 798 798 798 798 798 798

764 764 781 781 781 781 781 781 781

764 764 781 781 781 781 781 781 781

751 751 764 764 764 764 764 764 764

751 751 768 768 768 768 768 768 768

751 751 760 760 760 760 760 760 760

751 751 764 764 764 764 764 764 764

8 9 10 11 12 13 14 15 16

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Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

936 936 936 936 936 936 936 936 936

936 936 936 936 936 936 936 936 936

984 984 984 984 984 984 984 984 984

984 984 984 984 984 984 984 984 984

900 900 900 900 900 900 900 900 900

900 900 900 900 900 900 900 900 900

948 948 948 948 948 948 948 948 948

948 948 948 948 948 948 948 948 948

851 851 851 851 851 851 851 851 851

875 875 875 875 875 875 875 875 875

833 833 833 833 833 833 833 833 833

857 857 857 857 857 857 857 857 857

789 789 789 789 789 789 789 789 789

798 798 798 798 798 798 798 798 798

781 781 781 781 781 781 781 781 781

781 781 781 781 781 781 781 781 781

764 764 764 764 764 764 764 764 764

768 768 768 768 768 768 768 768 768

760 760 760 760 760 760 760 760 760

764 764 764 764 764 764 764 764 764

17 18 19 20 21 22 23 24 25

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Year 20 Year 21 Year 22 Year 23 Year 24 Year 25 Year 26

(1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K) (1995$K)

936 936 936 936 936 936 936

936 936 936 936 936 936 936

984 984 984 984 984 984 984

984 984 984 984 984 984 984

900 900 900 900 900 900 900

900 900 900 900 900 900 900

948 948 948 948 948 948 948

948 948 948 948 948 948 948

851 851 851 851 851 851 851

875 875 875 875 875 875 875

833 833 833 833 833 833 833

857 857 857 857 857 857 857

789 789 789 789 789 789 789

798 798 798 798 798 798 798

781 781 781 781 781 781 781

781 781 781 781 781 781 781

764 764 764 764 764 764 764

768 768 768 768 768 768 768

760 760 760 760 760 760 760

764 764 764 764 764 764 764

26 27 28 29 30 31 32

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LIQUIDS TRUNKLINE (RICH FIELDS ONLY)

CASE LIQUIDS OPEX

FLOW RATE 20 km 50 km 100 km

(m3/d) (1995$K) (1995$K) (1995$K)

20 50 100

AA 230 26 72 135

AC 250 26 72 135

BA 115 26 51 135

BC 125 26 51 135

ROADS OPEX 16 (1995$K)

INFRASTRUCTURE OPEX 224 (1995$K)

Includes significant annual deisel costs for power generation to accommodation.

TRUCKING COSTS

Condensate 68 (1995$/m3)

LPG 153 (1995$/tonne)

Page 66: Economics of Gas Gathering Cashflow

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Page 66

FUEL GAS REQUIREMENTS

GPA REPORT

SECTION 8.2 & 9

RICH FIELD LEAN FIELD

max daily max annuaannual fuel ratio annual fuel ratio

rate rate available available

(KSCMD) (MSCM/yr) (MSCM/yr) (MSCM/yr)

386 140.89 13 0.092271 1.04 0.007382

194 70.81 6.5 0.091795 0.52 0.007344

77 28.105 2.6 0.09251 0.21 0.007472

39 14.235 1.3 0.091324 0.1 0.007025

ADDITIONAL FUEL GAS REQUIREMENT FOR LPG RECOVERY, (RICH FIELDS ONLY)

GPA Fax 23 April 1996, Table 3

fuel ratio

Rich Field, High CO2 0.008897 lpgfuel1

Rich Field, Low CO2 0.012922 lpgfuel2

Note: The following tables do NOT include additional fuel gas for LPG Recovery

CASE FIELD WELLS DEPLN MAX. PLANT FUEL GAS REQUIREMENT

SIZE RATE RATE Year 0 Year 1

(bcf) (% pa) (KSCMD) (MSMC/yr) (MSMC/yr)

single 100 10 0.05 385.9451 Compressor 0 0

Gen Sets 0 0.22

Refrig 0 1.26

TOTAL fuel1 0 1.48

single 50 5 0.05 192.9725 Compressor 0 0

Gen Sets 0 0.2

Refrig 0 0.63

TOTAL fuel2 0 0.83

single 50 5 0.1 385.9451 Compressor 0 0

Gen Sets 0 0.22

Refrig 0 1.26

TOTAL fuel3 0 1.48

single 10 1 0.05 38.59451 Compressor 0 0

Gen Sets 0 0.16

Refrig 0 0.13

TOTAL fuel4 0 0.29

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single 10 1 0.1 77.18901 Compressor 0 0

Gen Sets 0 0.18

Refrig 0 0.25

TOTAL fuel5 0 0.43

multiple 50 5 0.05 192.9725 Compressor 0 0

Gen Sets 0 0.2

Refrig 0 0.63

TOTAL fuel6 0 0.83

multiple 50 5 0.1 385.9451 Compressor 0 0

Gen Sets 0 0.22

Refrig 0 1.26

TOTAL fuel7 0 1.48

increment 10 1 0.05 38.59451 Compress 0 0

increment 10 1 0.1 77.18901 Compress 0 0

single 10 1 0.2 154.378 Compressor 0 1.47

Gen Sets 0 0.2

Refrig 0 0.63

TOTAL fuel8 0 2.3

multiple 20 2 5% of 50 192.9725 Compressor 0 0

Gen Sets 0 0.2

Refrig 0 0.63

TOTAL fuel9 0 0.83

multiple 30 3 5% of 50 192.9725 Compressor 0 0

Gen Sets 0 0.2

Refrig 0 0.63

TOTAL fuel10 0 0.83

multiple 40 4 5% of 50 192.9725 Compressor 0 0

Gen Sets 0 0.2

Refrig 0 0.63

TOTAL fuel11 0 0.83

NOTE: 2, 3, and 4 fields cases based on 5 field case at 5% depletion

2 field case, stage 1 compression required by start Year 2, stage 2 compression required by start Year 3

3 field case, stage 1 compression required by mid Year 4, stage 2 compression required by start Year 6

4 field case, stage 1 compression required by mid Year 6, stage 2 compression required by mid Year 8

Page 68: Economics of Gas Gathering Cashflow

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Page 68

FUEL GAS REQUIREMENT

Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10

(MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr)

0 0 0 0 0 0 0 1.35 1.35

0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22

1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26

1.48 1.48 1.48 1.48 1.48 1.48 1.48 2.83 2.83

0 0 0 0 0 0 0 0.68 0.68

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

0.83 0.83 0.83 0.83 0.83 0.83 0.83 1.51 1.51

0 0.68 1.08 2.95 2.95 2.95 2.95 2.95 2.95

0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22

1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26

1.48 2.16 2.56 4.43 4.43 4.43 4.43 4.43 4.43

0 0 0 0 0 0 0 0 0.15

0.16 0.16 0.16 0.16 0.16 0.16 0.16 0.16 0.16

0.13 0.13 0.13 0.13 0.13 0.13 0.13 0.13 0.13

0.29 0.29 0.29 0.29 0.29 0.29 0.29 0.29 0.44

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0 0.28 0.52 0.6 0.6 0.6 0.6 0.6 0.6

0.18 0.18 0.18 0.18 0.18 0.18 0.18 0.18 0.18

0.25 0.25 0.25 0.25 0.25 0.25 0.25 0.25 0.25

0.43 0.71 0.95 1.03 1.03 1.03 1.03 1.03 1.03

0 0 0 0 0 0 0 0.34 0.68

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

0.83 0.83 0.83 0.83 0.83 0.83 0.83 1.17 1.51

0 0.34 1.35 2.94 2.94 2.94 2.94 2.94 2.94

0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22

1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26

1.48 1.82 2.83 4.42 4.42 4.42 4.42 4.42 4.42

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

1.47 1.47 1.47 1.47 1.47 1.47 1.47 1.47 1.47

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

2.3 2.3 2.3 2.3 2.3 2.3 2.3 2.3 2.3

0.6789 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

1.5089 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915

0 0 0.6789 0.6789 2.44915 2.44915 2.44915 2.44915 2.44915

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

0.83 0.83 1.5089 1.5089 3.27915 3.27915 3.27915 3.27915 3.27915

0 0 0 0 0.6789 0.6789 2.44915 2.44915 2.44915

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

0.83 0.83 0.83 0.83 1.5089 1.5089 3.27915 3.27915 3.27915

2 field case, stage 1 compression required by start Year 2, stage 2 compression required by start Year 3

3 field case, stage 1 compression required by mid Year 4, stage 2 compression required by start Year 6

4 field case, stage 1 compression required by mid Year 6, stage 2 compression required by mid Year 8

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Year 11 Year 12 Year 13 Year 14 Year 15 Year 16 Year 17 Year 18 Year 19

(MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr)

2.15 2.95 2.95 2.95 2.95 2.95 2.95 2.95 2.95

0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22

1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26

3.63 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43

1.08 1.47 1.47 1.47 1.47 1.47 1.47 1.47 1.47

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

1.91 2.3 2.3 2.3 2.3 2.3 2.3 2.3 2.3

2.95 2.95 2.95 2.95 2.95 2.95 2.95 2.95 2.95

0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22

1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26

4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43 4.43

0.15 0.23 0.3 0.3 0.3 0.3 0.3 0.3 0.3

0.16 0.16 0.16 0.16 0.16 0.16 0.16 0.16 0.16

0.13 0.13 0.13 0.13 0.13 0.13 0.13 0.13 0.13

0.44 0.52 0.59 0.59 0.59 0.59 0.59 0.59 0.59

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0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6

0.18 0.18 0.18 0.18 0.18 0.18 0.18 0.18 0.18

0.25 0.25 0.25 0.25 0.25 0.25 0.25 0.25 0.25

1.03 1.03 1.03 1.03 1.03 1.03 1.03 1.03 1.03

0.68 1.08 2.45 2.45 2.45 2.45 2.45 2.45 2.45

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

1.51 1.91 3.28 3.28 3.28 3.28 3.28 3.28 3.28

2.94 2.94 2.94 2.94 2.94 2.94 2.94 2.94 2.94

0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22

1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26 1.26

4.42 4.42 4.42 4.42 4.42 4.42 4.42 4.42 4.42

0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 0 0 0

1.47 1.47 1.47 1.47 1.47 1.47 1.47 1.47 1.47

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

2.3 2.3 2.3 2.3 2.3 2.3 2.3 2.3 2.3

2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915

2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915

2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915

0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63 0.63

3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915

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Year 20 Year 21 Year 22 Year 23 Year 24 Year 25 Year 26

(MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr) (MSMC/yr)

2.95 2.95 2.95 2.95 2.95 2.95 2.95

0.22 0.22 0.22 0.22 0.22 0.22 0.22

1.26 1.26 1.26 1.26 1.26 1.26 1.26

4.43 4.43 4.43 4.43 4.43 4.43 4.43

1.47 1.47 1.47 1.47 1.47 1.47 1.47

0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63

2.3 2.3 2.3 2.3 2.3 2.3 2.3

2.95 2.95 2.95 2.95 2.95 2.95 2.95

0.22 0.22 0.22 0.22 0.22 0.22 0.22

1.26 1.26 1.26 1.26 1.26 1.26 1.26

4.43 4.43 4.43 4.43 4.43 4.43 4.43

0.3 0.3 0.3 0.3 0.3 0.3 0.3

0.16 0.16 0.16 0.16 0.16 0.16 0.16

0.13 0.13 0.13 0.13 0.13 0.13 0.13

0.59 0.59 0.59 0.59 0.59 0.59 0.59

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0.6 0.6 0.6 0.6 0.6 0.6 0.6

0.18 0.18 0.18 0.18 0.18 0.18 0.18

0.25 0.25 0.25 0.25 0.25 0.25 0.25

1.03 1.03 1.03 1.03 1.03 1.03 1.03

2.45 2.45 2.45 2.45 2.45 2.45 2.45

0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63

3.28 3.28 3.28 3.28 3.28 3.28 3.28

2.94 2.94 2.94 2.94 2.94 2.94 2.94

0.22 0.22 0.22 0.22 0.22 0.22 0.22

1.26 1.26 1.26 1.26 1.26 1.26 1.26

4.42 4.42 4.42 4.42 4.42 4.42 4.42

0 0 0 0 0 0 0

0 0 0 0 0 0 0

1.47 1.47 1.47 1.47 1.47 1.47 1.47

0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63

2.3 2.3 2.3 2.3 2.3 2.3 2.3

2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915

0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63

3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915

2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915

0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63

3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915

2.44915 2.44915 2.44915 2.44915 2.44915 2.44915 2.44915

0.2 0.2 0.2 0.2 0.2 0.2 0.2

0.63 0.63 0.63 0.63 0.63 0.63 0.63

3.27915 3.27915 3.27915 3.27915 3.27915 3.27915 3.27915