Nomenclature Free
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Published:2019
"Nomenclature", Analysis of Oil and Gas Production Performance, Steven W. Poston, Marcelo Laprea-Bigott, Bobby D. Poe, Jr.
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- a
= loss ratio, q/(change in rate)
- A
= drainage area, ft2 (m2)
- AD
= dimensionless drainage area
- AR
= rectangular-drainage-area aspect ratio
- b
= Arps decline curve exponent
- bf
= fracture width, ft (m)
- B
= fluid formation volume factor, RB/STB (res m3/std m3)
- BCPD
= stock-tank barrels condensater/day, STB/D (std m3/d)
- BOPD
= stock-tank barrels oil/day, STB/D (std m3/d)
- bf
= fracture width, ft (m)
- Bg
= gas formation volume factor, res ft3/scf (res m3/std m3)
- Bo
= oil formation volume factor, RB/STB (res m3/std m3)
- bpss
= pseudosteady-state intercept
- CHP
= casinghead pressure, psi (Pa)
- CA
= Dietz steady-state shape factor
- CfD
= dimensionless fracture conductivity
- cf
= formation pore compressibility, 1/psi (1/Pa)
- cg
= gas compressibility, 1/psi (1/Pa)
- co
= oil compressibility, 1/psi (1/Pa)
- Cr
= relative conductivity
- ct
= total system compressibility, 1/psi (1/Pa)
- cw
= water compressibility, 1/psi (1/Pa)
- d
= effective decline rate, 1/ unit time
- D
= continuous decline rate, 1/unit of time
- Di
= Arps initial decline rate, 1/unit of time
- Dwb
= wellbore diameter, ft (m)
- EUR
= estimated ultimate recovery, STB (std m3)
- FTHP
= flowing tubinghead pressure, psi (Pa)
- fw
= fraction of water flowing, also called water cut
- GOR
= gas/oil ratio, Mscf/STB (1000 m3/m3)
- GWR
= gas/water ratio, Mscf/STBW (1000 std m3/std m3)
- Ga
= approximate original gas in place estimate, MMscf (million std m3)
- Gp
= cumulative gas production, MMscf (std m3)
- Gpmax
= estimated ultimate gas cumulative production, MMscf (std m3)
- h
= reservoir net-pay thickness, ft (m)
- HCPV
= hydrocarbon pore volume, ft3 (m3)
- J
= productivity index, STB/D/psi (std m3/s/Pa)
- k
= reservoir effective permeability, md (m2)
- kf
= fracture permeability, md (m2)
- kfbf
= fracture conductivity, md-ft (m3)
- kg
= formation effective permeability to gas, md (m2)
- kh
= formation conductivity, md-ft (m3)
- ko
= formation effective permeability to oil, md (m2)
- kw
= formation effective permeability to water, md (m2)
- kx
= effective permeability in x-direction, md (m2)
- ky
= effective permeability in y-direction, md (m2)
- kz
= vertical effective permeability, md (m2)
- Lc
= system characteristic length, ft (m)
- LD
= dimensionless horizontal wellbore length
- Lh
= effective horizontal well length in the reservoir, ft (m)
- m
= slope of line
- N
= number of fractures
- N
= original oil in place in the reservoir, STB (std m3)
- Np
= cumulative oil production, STB (std m3)
- OOIP
= original oil in place in the reservoir, STB (std m3)
- OGIP
= original gas in place in the reservoir, SCF (std m3)
- OWC
= oil water contact
- pe
= pressure at external boundary, psi (Pa)
- pi
= initial reservoir pressure, psi (Pa)
- pp
= real-gas pseudopressure, psia2/cp (Pa/s)
- pr
= average reservoir pressure, psia (Pa)
- psc
= standard-condition pressure, psia (Pa)
- ptf
= flowing tubinghead pressure, psi (Pa)
- pwD
= dimensionless wellbore pressure
- pwf
= sandface flowing pressure, psia (Pa)
- q
= well flow rate, STB/unit of time or Mscf/unit of time (std m3/s)
- q2
= well flow rate at later time t2, stb/d or scf/d (std m3/s)
- qD
= dimensionless flow rate
- qlast
= last measured rate, STB/unit of time or scf/unit of time (std m3/s)
- qDd
= dimensionless decline flow rate
- qDdi
= dimensionless flow rate integral function
- qDdid
= dimensionless flow rate integral derivative function
- qEL
= economic-limit flow rate, STB/unit of time (std m3/s)
- qg
= gas-flow rate, Mscf/unit of time (std m3/s)
- qi
= initial flow rate, STB/unit of time (std m3/s)
- qo
= oil-flow rate, STB/unit of time (std m3/s)
- Qmax
= maximum possible production @q = 0; STB or scf (std m3)
- Qp
= cumulative fluid production, STB or scf (std m3)
- QpD
= dimensionless cumulative production
- QpDd
= dimensionless decline cumulative production
- qwD
= dimensionless well flow rate
- re
= reservoir effective drainage radius, ft (m)
- reD
= dimensionless drainage radius
- rw
= wellbore radius, ft (m)
- rwa
= apparent wellbore radius, ft (m)
- rwDz
= dimensionless wellbore radius
- S
= steady-state skin effect
- Sg
= gas saturation, fraction of pore volume
- So
= oil saturation, fraction of pore volume
- Sw
= water saturation, fraction of pore volume
- Swi
= initial water saturation, fraction of pore volume
- t
= time, days (or months) (s)
- T
= reservoir temperature, °F (K)
- ta
= real-gas pseudo-time function, D-psi/cp
- tD
= dimensionless time
- tDA
= dimensionless time referenced to drainage area
- tDd
= dimensionless decline time
- tDmb
= dimensionless pseudo production time
- tmb
= pseudo production time, days (s)
- tmbDd
= dimensionless decline pseudo production time
- tp
= pseudo production time, days (s)
- tpDd
= dimensionless decline pseudo production time
- tpss
= start of boundary-dominated flow in real time
- Tsc
= standard-condition temperature, oF or oC
- Vb
= bulk volume of the reservoir, acre-ft or RB (res m3)
- Vp
= pore volume of the reservoir, acre-ft or RB (res m3)
- WOR
= water/oil ratio, STBW/stbo (std m3 water/ std m3 oil
- Xe
= drainage areal extent in the x-direction, ft (m)
- XeD
= dimensionless drainage extent in x-direction
- Xf
= effective fracture half-length, ft (m)
- XwD
= dimensionless wellbore location in x-direction
- Ye
= drainage areal extent in the y-direction, ft (m)
- Yield
= STB condensate/MMscf, (std m3/million std m3)
- YeD
= dimensionless drainage extent in y-direction
- YwD
= dimensionless wellbore location in y-direction
- z
= gas-law deviation (supercompressibility) factor
- Zw
= horizontal well standoff from bottom of reservoir, ft (m)
- ZwD
= dimensionless horizontal well standoff from bottom of pay
- α
= Prats (1961) dimensionless fracture capacity
- Δp
= pressure difference, psi (Pa)
- ε
= imaging function
- ϕ
= effective porosity of reservoir, fraction of pore volume
- γf
= gravity of fluid
- λ
= reservoir mobility of a fluid, md/cp (m2/Pa∙s)
- λt
= total system mobility (all fluids), md/cp (m2/ Pa∙s)
- μ
= reservoir fluid viscosity, cp (Pa∙s)
- μg
= gas viscosity, cp (Pa∙s)
- μgi
= initial reservoir gas viscosity, cp (Pa∙s)
- μo
= oil viscosity, cp (Pa∙s)
- μoi
= initial oil viscosity, cp (Pa∙s)