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El. knyga: Formulas and Calculations for Petroleum Engineering

4.50/5 (4 ratings by Goodreads)

Tayfun Tuna (Post-doc Fellow, College of Natural Sciences and Mathematics, University of Houston, and Data Scientist, Blue Barrel Solutions, USA), Mehmet Melih Oskay (Professor, King Fahd University of Petroleum and M), Luigi Saputelli, Cenk Temizel (Saudi Aramco, Dhahran, Kingdom of Saudi Arabia)

Formatas: EPUB+DRM
Išleidimo metai: 15-Aug-2019
Leidėjas: Gulf Professional Publishing
Kalba: eng
ISBN-13: 9780128165553

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Formatas: EPUB+DRM
Išleidimo metai: 15-Aug-2019
Leidėjas: Gulf Professional Publishing
Kalba: eng
ISBN-13: 9780128165553

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Formulas and Calculations for Petroleum Engineering unlocks the capability for any petroleum engineering individual, experienced or not, to solve problems and locate quick answers, eliminating non-productive time spent searching for that right calculation. Enhanced with lab data experiments, practice examples, and a complimentary online software toolbox, the book presents the most convenient and practical reference for all oil and gas phases of a given project. Covering the full spectrum, this reference gives single-point reference to all critical modules, including drilling, production, reservoir engineering, well testing, well logging, enhanced oil recovery, well completion, fracturing, fluid flow, and even petroleum economics.

Presents single-point access to all petroleum engineering equations, including calculation of modules covering drilling, completion and fracturing
Helps readers understand petroleum economics by including formulas on depreciation rate, cashflow analysis, and the optimum number of development wells

Biographies of authors

xxv

Foreword

xxvii

Acknowledgement

xxix

1 Reservoir engineering formulas and calculations

1.1 API gravity

(1)

1.2 Average permeability for linear flow-Layered beds

(1)

1.3 Average permeability for linear flow-Series beds

(1)

1.4 Average permeability for parallel-layered systems

(1)

1.5 Average permeability in radial systems

(1)

1.6 Average temperature of a gas column

(1)

1.7 Calculation of fractional flow curve

(1)

1.8 Capillary number

(1)

1.9 Capillary pressure

(1)

1.10 Characteristic time for linear diffusion in reservoirs

(1)

1.11 Cole plot

(1)

1.12 Communication between compartments in tight gas reservoirs

(1)

1.13 Communication factor in a compartment in tight gas reservoirs

(1)

1.14 Compressibility drive in gas reservoirs

(1)

1.15 Correction factor-Hammerlindl

(1)

1.16 Critical rate for horizontal Wells in edge-water drive reservoirs

(1)

1.17 Crossflow index

(1)

1.18 Cumulative effective compressibility-Fetkovich

(1)

1.19 Cumulative gas production-Tarner's method

(1)

1.20 Cumulative oil production-Undersaturated oil reservoirs

(1)

1.21 Deliverability equation for shallow gas reservoirs

(1)

1.22 Dimensionless pressure-Kamal and Brigham

(1)

1.23 Dimensionless radius of radial flow-Constant-rate production

(1)

1.24 Dimensionless time-Myhill and Stegemeier's method

(1)

1.25 Dimensionless time for interference testing in homogeneous reservoirs-Earlougher

(1)

1.26 Dimensionless vertical well critical rate correlations- Hoyland, Papatzacos, and Skjaeveland

(1)

1.27 Dimensionless wellbore storage coefficient of radial flow-Constant-rate production

(1)

1.28 Effective compressibility in undersaturated oil reservoirs-Hawkins

(1)

1.29 Effective wellbore radius of a horizontal well-Method 1-Anisotropic reservoirs

(1)

1.30 Effective wellbore radius of a horizontal well-Method 1-Isotropic reservoirs

(1)

1.31 Effective wellbore radius of a horizontal well-van der Vlis et al. method

(1)

1.32 Effective wellbore radius of a well in presence of uniform-flux fractures

(1)

1.33 Effective wellbore radius to calculate slant well productivity-van der Vlis et al.

(1)

1.34 Estimation of average reservoir pressure-MDH method

(1)

1.35 Formation temperature for a given gradient

(1)

1.36 Fraction of the total solution gas retained in the reservoir as free gas

(1)

1.37 Fractional gas recovery below the critical desorption pressure in coal bed methane reservoirs

(1)

1.38 Free gas in place

(1)

1.39 Gas adsorbed in coal bed methane reservoirs

(1)

1.40 Gas bubble radius

(1)

1.41 Gas cap ratio

(1)

1.42 Gas cap shrinkage

(1)

1.43 Gas drive index in gas reservoirs

(1)

1.44 Gas expansion factor

(1)

1.45 Gas expansion term in gas reservoirs

(1)

1.46 Gas flow rate into the wellbore

(1)

1.47 Gas flow under laminar viscous conditions

(1)

1.48 Gas formation volume factor

(1)

1.49 Gas hydrate dissociation pressure

(1)

1.50 Gas material balance equation

(1)

1.51 Gas produced by gas expansion

(1)

1.52 Gas saturation-Water-drive gas reservoirs

(1)

1.53 Gas solubility in coalbed methane reservoirs

(1)

1.54 Geertsma's model for porosity/transit-time relationship

(1)

1.55 Geothermal gradient

(1)

1.56 Hagen Poiseuille equation

(1)

1.57 Hagoort and Hoogstra gas flow in tight reservoirs

(1)

1.58 Hammerlindl method for gas in place

(1)

1.59 High-pressure region gas flow rate

(1)

1.60 Horizontal well breakthrough time-With gas cap or bottom water

(1)

1.61 Horizontal well critical rate correlation-Chaperon

(1)

1.62 Horizontal well critical rate correlations - Efros

(1)

1.63 Horizontal well critical rate correlations-Giger and Karcher

(1)

1.64 Horizontal well critical rate correlations-Joshi method for gas coning

(1)

1.65 Hydrocarbon pore volume occupied by evolved solution gas

(1)

1.66 Hydrocarbon pore volume occupied by gas cap

(1)

1.67 Hydrocarbon pore volume occupied by remaining oil

(1)

1.68 Hydrostatic pressure

(1)

1.69 Incremental cumulative oil production in undersaturated reservoirs

(1)

1.70 Ineffective porosity

(1)

1.71 Initial gas cap

(1)

1.72 Initial gas in place for water-drive gas reservoirs

(1)

1.73 Injectivity index

(1)

1.74 Instantaneous gas-oil ratio

(1)

1.75 Interporosity flow coefficient

(1)

1.76 Interstitial velocity

(1)

1.77 Isothermal compressibility of oil -Vasquez-Beggs correlation-P > Pb

(1)

1.78 Isothermal compressibility of oil -Villena-Lanzi correlation-P < Pb

(1)

1.79 Isothermal compressibility of water-Osif correlation

(1)

1.80 Kerns method for gas flow in a fracture

(1)

1.81 Klinkenberg gas effect

(1)

1.82 Kozeny equation

(1)

1.83 Kozeny-Carman relationship

(1)

1.84 Leverett J-function

(1)

1.85 Line-source solution for damaged or stimulated wells

(1)

1.86 Low-pressure region gas flow rate for non-circular drainage area

(1)

1.87 Material balance for cumulative water influx-Havlena and Odeh

(1)

1.88 Maximum height of oil column in cap rock

(1)

1.89 Modified Cole plot

(1)

1.90 Modified Kozeny-Carman relationship

(1)

1.91 Normalized saturation

(1)

1.92 Oil bubble radius of the drainage area of each well represented by a circle

(1)

1.93 Oil density-Standing's correlation

(1)

1.94 Oil formation volume factor-Standing's correlation

(1)

1.95 Oil formation volume factor-Beggs-standing correlation-P < Pb

(1)

1.96 Oil formation volume factor-Beggs-standing correlation-P > Pb

(1)

1.97 Oil in place for undersaturated oil reservoirs without fluid injection

(1)

1.98 Oil in place in saturated oil reservoirs

(1)

1.99 Oil lost in migration

(1)

1.100 Oil saturation at any depletion state below the bubble point pressure

(1)

1.101 Original gas in place

(1)

1.102 Payne method for intercompartmental flow in tight gas reservoirs

(1)

1.103 Performance coefficient for shallow gas reservoirs

(1)

1.104 Poisson's ratio

(1)

1.105 Pore throat sorting

(1)

1.106 Pore volume occupied by injection of gas and water

(1)

1.107 Pore volume through squared method in tight gas reservoirs

(1)

1.108 Porosity determination-IES and FDC logs

(1)

1.109 Produced gas-oil ratio

(1)

1.110 Productivity index for a gas well

(1)

1.111 Pseudo-steady state productivity of horizontal Wells-Method 1

(1)

1.112 Pseudo-steady state productivity of horizontal Wells-Method 2

(1)

1.113 Pseudo-steady state productivity of horizontal wells-Method 3

(1)

1.114 Pseudo-steady state radial flow equation

(1)

1.115 Relative permeability-Corey exponents

(1)

1.116 Remaining gas in place in coalbed methane reservoirs

(1)

1.117 Roach plot for abnormally pressured gas reservoirs

(1)

1.118 Rock expansion term in abnormally pressured gas reservoirs

(1)

1.119 Shape factor-Earlougher

(1)

1.120 Solution gas oil ratio-Beggs-standing correlation-P < Pb

(1)

1.121 Solution gas oil ratio-Standing's correlation

(1)

1.122 Solution gas water ratio

(1)

1.123 Somerton method for formation permeability in coalbed methane reservoirs

(1)

1.124 Specific gravity of gas hydrate forming components

(1)

1.125 Time to reach the semi-steady state for a gas well in a circular or square drainage area

(1)

1.126 Time to the end of infinite-acting period for a well in a circular reservoir

(1)

1.127 Torcaso and Wyllie's correlation for relative permeability ratio prediction

(1)

1.128 Total compressibility

(1)

1.129 Total pore volume compressibility

(1)

1.130 Transmissibility between compartments

(1)

1.131 Transmissibility of a compartment

(1)

1.132 Transmissivity

(1)

1.133 Trapped gas volume in water-invaded zones

(1)

1.134 Two-phase formation volume factor

(1)

1.135 Underground fluid withdrawal-Havlena and Odeh

(1)

1.136 Vertical well critical rate correlations-Craft and Hawkins method

(1)

1.137 Vertical well critical rate correlations-Hoyland, Papatzacos, and Skjaeveland-Isotropic reservoirs

(1)

1.138 Vertical well critical rate correlations-Meyer, Gardner, and Pirson-Simultaneous gas and water coning

(1)

1.139 Vertical well critical rate correlations-Meyer, Gardner, and Pirson-Water coning

(1)

1.140 Vertical well critical rate correlations-Meyer, Gardner, and Pirson-Gas coning

(1)

1.141 Viscosibility

(1)

1.142 Viscosity of crude oil through API

(1)

1.143 Viscosity of dead oil-Standing's correlation

(1)

1.144 Viscosity of dead-oil-Egbogah correlation-P < Pb

(1)

1.145 Viscosity of live oil-Beggs/Robinson correlation

(1)

1.146 Viscosity of oil-Vasquez/Beggs correlation-P > Pb

(1)

1.147 Viscosity of water at atmospheric pressure-McCain correlation

(1)

1.148 Viscosity of water at reservoir pressure-McCain correlation

(1)

1.149 Volume of gas adsorbed in coalbed methane reservoirs

(1)

1.150 Volumetric heat capacity of a reservoir

(1)

1.151 Water breakthrough correlation in vertical wells-Bournazel and Jeanson

(1)

1.152 Water breakthrough correlations in vertical wells-Sobocinski and Cornelius

(1)

1.153 Water content of sour gas

(1)

1.154 Water cut-Stiles

(1)

1.155 Water-drive index for gas reservoirs

(1)

1.156 Water-drive recovery

(1)

1.157 Water expansion term in gas reservoirs

(1)

1.158 Water formation volume factor-McCain correlation

(1)

1.159 Water influx-Pot aquifer model

(1)

1.160 Water influx constant for the van Everdingen and Hurst unsteady-state model

(1)

1.161 Water two-phase formation volume factor

(1)

1.162 Waxman and Smits model-Clean sands

(1)

1.163 Welge extension-Fractional flow

(3)

2 Drilling engineering formulas and calculations

2.1 Accumulator capacity

(1)

2.2 Accumulator precharge pressure

(1)

2.3 Amount of additive required to achieve a required cement slurry density

(1)

2.4 Amount of cement to be left in casing

(1)

2.5 Amount of mud required to displace cement in drillpipe

(1)

2.6 Angle of twist-Rod subjected to torque

(1)

2.7 Annular capacity between casing and multiple strings of tubing

(1)

2.8 Annular capacity between casing and multiple tubing strings

(1)

2.9 Annular velocity-Using circulation rate in Gpm

(1)

2.10 Annular velocity-Using pump output in bbl/min

(1)

2.11 Annular velocity for a given circulation rate

(1)

2.12 Annular velocity for a given pump output

(1)

2.13 Annular volume capacity of pipe

(1)

2.14 API water loss calculations

(1)

2.15 Area below the casing shoe

(1)

2.16 Axial loads in slips

(1)

2.17 Beam force

(1)

2.18 Bit nozzle pressure loss

(1)

2.19 Bit nozzle selection-Optimized hydraulics for two and three jets

(1)

2.20 Borehole torsion-Cylindrical helical method

(1)

2.21 Bottomhole annulus pressure

(1)

2.22 Bottomhole assembly length required for a desired weight on bit

(1)

2.23 Bulk density of cuttings-Using the mud balance

(1)

2.24 Bulk modulus using Poisson's ratio and Young's modulus

(1)

2.25 Buoyancy weight

(1)

2.26 Buoyancy factor

(1)

2.27 Buoyancy factor using mud weight

(1)

2.28 Calculations for the number of feet to be cemented

(1)

2.29 Calculations required for spotting pills

(1)

2.30 Capacity formulas-bbl/ft

(1)

2.31 Capacity formulas-gal/ft

(1)

2.32 Capacity of tubulars and open-hole

(1)

2.33 CO2 solubility in oil and oil-mud emulsifiers

(1)

2.34 Combined solubility-Hydrocarbon gas, CO2, and H2S-in each of the mud components

(1)

2.35 Control drilling-Maximum drilling rate

(1)

2.36 Conversion of pressure into the mud weight

(1)

2.37 Cost per foot during drilling

(1)

2.38 Cost per foot of coring

(1)

2.39 Critical annular velocity and critical flow rate

(1)

2.40 Critical flow rate for flow regime change

(1)

2.41 Critical velocity for change in flow regime

(1)

2.42 Crown block capacity

(1)

2.43 Current drag force-Offshore

(1)

2.44 Curvature radius for a borehole

(1)

2.45 Cutting slip velocity

(1)

2.46 Cuttings produced per foot of hole drilled - bbls

(1)

2.47 Cuttings produced per foot of hole drilled - lbs

(1)

2.48 D-Exponent

(1)

2.49 Depth of a washout-Method 1

(1)

2.50 Depth of a washout-Method 2

(1)

2.51 Derrick efficiency factor

(1)

2.52 Difference in pressure gradient between the cement and mud

(1)

2.53 Differential hydrostatic pressure between cement in the annulus and mud inside the casing

(1)

2.54 Dilution of a mud system

(1)

2.55 Direction of dip

(1)

2.56 Directional curvature for a deviated well

(1)

2.57 Downward force or weight of casing

(1)

2.58 Drill pipe or drill collar capacity

(1)

2.59 Drill pipe or drill collar displacement and weight

100

(1)

2.60 Drill string design-Drill pipe length for bottomhole assembly

100

(1)

2.61 Drilled gas entry rate

101

(1)

2.62 Drilling cost per foot

101

(1)

2.63 Drilling ton miles-Coring operation ton miles

102

(1)

2.64 Drilling ton miles-Drilling/connection ton miles

102

(1)

2.65 Drilling ton miles-Round trip ton miles

102

(1)

2.66 Drilling ton miles-While making short trip ton miles

103

(1)

2.67 Drilling ton miles-Setting casing ton miles

103

(1)

2.68 Duplex pump factor

104

(1)

2.69 Duplex pump output-Using liner diameter

104

(1)

2.70 Duplex pump output-Using rod diameter

104

(1)

2.71 Duplex pump output by using liner and rod diameters

105

(1)

2.72 Dynamically coupled linear flow-Formation invasion

105

(1)

2.73 Effective weight during drilling

106

(1)

2.74 Effective wellbore radius for finite-conductivity fractures

106

(1)

2.75 Effective wellbore radius in infinite-conductivity fractures

107

(1)

2.76 Efficiency of block and tackle system

107

(1)

2.77 Equivalent area of pipe subject to uniform axial force

108

(1)

2.78 Equivalent circulating density

108

(1)

2.79 Equivalent density of a wellbore fluid

109

(1)

2.80 Equivalent formation water resistivity from SP log

109

(1)

2.81 Equivalent mud weight-Deviated well

109

(1)

2.82 Equivalent mud weight-Vertical well

110

(1)

2.83 Evaluation of centrifuge

110

(1)

2.84 Evaluation of hydrocyclone

111

(1)

2.85 Fluid volume required to spot a plug

111

(1)

2.86 Force applied to stretch material

112

(1)

2.87 Force exerted by the fluid on the solid surface of flow through an annulus

112

(1)

2.88 Friction factor in drill pipe

113

(1)

2.89 Front displacement of a particle in the reservoir-Formation invasion

113

(1)

2.90 Gas migration velocity

114

(1)

2.91 Gas solubility in a mud system

114

(1)

2.92 Gas/mud ratio

114

(1)

2.93 Gel strength-Optimal solid removal efficiency

115

(1)

2.94 Gel strength-Solid control efficiency

115

(1)

2.95 Gel strength-Solids build-up in system

116

(1)

2.96 Height of cement in the annulus

116

(1)

2.97 Hydraulic horsepower

116

(1)

2.98 Hydraulics analysis

117

(1)

2.99 Hydromechanical specific energy

118

(1)

2.100 Hydrostatic pulling

118

(1)

2.101 Hydrostatic pulling wet pipe out of the hole

119

(1)

2.102 Hydrostatic pressure in annulus due to slug

119

(1)

2.103 Hydrostatic pressure decrease at total depth caused by gas-cut mud

119

(1)

2.104 Impact force-Nozzle hydraulic analysis

120

(1)

2.105 Impringing jet

120

(1)

2.106 Increase mud density by barite

121

(1)

2.107 Increase mud density by calcium carbonate

121

(1)

2.108 Increase mud density by hematite

121

(1)

2.109 Increase volume by barite

122

(1)

2.110 Increase volume by calcium carbonate

122

(1)

2.111 Increase volume by hematite

122

(1)

2.112 Initial volume required to achieve a volume with barite

123

(1)

2.113 Initial volume required to achieve a volume with calcium carbonate

123

(1)

2.114 Initial volume required to achieve a volume with hematite

124

(1)

2.115 Injection/casing pressure required to open valve

124

(1)

2.116 Input power of a pump-Using fuel consumption rate

124

(1)

2.117 Jet velocity-Nozzle hydraulic analysis

125

(1)

2.118 Kick analysis-Influx

125

(1)

2.119 Kick analysis-Formation pressure with well shut-in on a kick

126

(1)

2.120 Kick analysis-Maximum pit gain from a gas kick in water-based mud

126

(1)

2.121 Kick analysis-Maximum surface pressure from a gas kick in water-based mud

126

(1)

2.122 Kick analysis-Shut-in drill pipe pressure

127

(1)

2.123 Kick analysis-Height of influx

127

(1)

2.124 Kill weight mud determination-Moore equation

127

(1)

2.125 Kinetic friction

128

(1)

2.126 Laser specific energy

128

(1)

2.127 Lateral load imposed on a casing centralizer- Cementing

129

(1)

2.128 Lateral load imposed on a casing centralizer with a dogleg-Cementing

129

(1)

2.129 Linear annular capacity of pipe

129

(1)

2.130 Linear capacity of pipe

130

(1)

2.131 Load to break cement bond-Cementing

130

(1)

2.132 Mass rate of flow through annulus

131

(1)

2.133 Matching conditions at the cake-to-rock interface-Formation invasion

131

(1)

2.134 Maximum allowable mud weight

131

(1)

2.135 Maximum drilling rate-Larger holes

132

(1)

2.136 Maximum equivalent derrick load

132

(1)

2.137 Maximum length of a slanted well in a given reservoir thickness

133

(1)

2.138 Maximum length of drillpipe for a specific bottomhole assembly

133

(1)

2.139 Maximum recommended low-gravity solids

133

(1)

2.140 Maximum recommended solids fractions in drilling fluids

134

(1)

2.141 Maximum weight on bit

134

(1)

2.142 Mechanical energy balance for wellbore fluids

134

(1)

2.143 Mechanical specific energy

135

(1)

2.144 Mud rheology-Herschel and Buckley law

135

(1)

2.145 Mud rheology-Power-law model-Consistency index

136

(1)

2.146 Mud rheology-Power-law model-Power-law index

136

(1)

2.147 Mud rheology-Power-law

136

(1)

2.148 Mud rheology calculations-Bingham plastic model

137

(1)

2.149 Mud weight increase required to balance pressure

137

(1)

2.150 Mud weight reduction by dilution-Water/diesel/any liquid

137

(1)

2.151 Mudcake growth equation-Formation invasion

138

(1)

2.152 Mudcake growth equation-2-Formation invasion

138

(1)

2.153 Mudcake permeability-Formation invasion

139

(1)

2.154 New pump circulating pressure

139

(1)

2.155 Nozzle area calculation

139

(1)

2.156 Number of sacks of cement required

140

(1)

2.157 Number of sacks of cement required for a given length of plug

141

(1)

2.158 Number of sacks of lead cement required for annulus

141

(1)

2.159 Number of sacks of tail cement required for casing

141

(1)

2.160 Open-ended displacement volume of pipe

142

(1)

2.161 Overall efficiency-Diesel engines to mud pump

142

(1)

2.162 Overall power system efficiency

143

(1)

2.163 Penetration rate-Drill-rate model-Alternative equation

143

(1)

2.164 Penetration rate-Drill-rate model-Basic equation

143

(1)

2.165 Percentage of bit nozzle pressure loss

144

(1)

2.166 Plastic viscosity-Bingham plastic model

144

(1)

2.167 Plug length to set a balanced cement plug

145

(1)

2.168 Polar moment of inertia

145

(1)

2.169 Polished rod horsepower-Sucker-rod pump

145

(1)

2.170 Pore-pressure gradient-Rehm and McClendon

146

(1)

2.171 Pore-pressure gradient-Zamora

146

(1)

2.172 Pressure analysis-Pressure by each barrel of mud in casing

147

(1)

2.173 Pressure analysis-Surface pressure during drill stem test

147

(1)

2.174 Pressure gradient

147

(1)

2.175 Pressure required to break circulation-Annulus

148

(1)

2.176 Pressure required to break circulation-Drill string

148

(1)

2.177 Pressure required to overcome gel strength of mud inside the drill string

148

(1)

2.178 Pressure required to overcome mud's gel strength in annulus

149

(1)

2.179 Pump calculation-Pump pressure

149

(1)

2.180 Pump calculations-Power required

149

(1)

2.181 Pump displacement

150

(1)

2.182 Pump flow rate

150

(1)

2.183 Pump head rating

151

(1)

2.184 Pump output-gpm

151

(1)

2.185 Pump output triplex pump

151

(1)

2.186 Pump pressure/pump stroke relationship

152

(1)

2.187 Radial force related to axial load-Cementing

152

(1)

2.188 Range of load-Sucker-Rod pump

152

(1)

2.189 Rate of fuel consumption by a pump

153

(1)

2.190 Rate of gas portion that enters the mud

153

(1)

2.191 Relationship between traveling block speed and fast line speed

153

(1)

2.192 Rock removal rate

154

(1)

2.193 Rotating horsepower

154

(1)

2.194 Side force at bit in anisotropic formation

155

(1)

2.195 Sinusoidal buckling

155

(1)

2.196 Slurry density for cementing calculations

155

(1)

2.197 Solids analysis-High-salt content muds

156

(1)

2.198 Solids analysis low-salt content muds

157

(1)

2.199 Spacer volume behind slurry required to balance the plug

157

(1)

2.200 Specific gravity of cuttings by using mud balance

158

(1)

2.201 Stripping/snubbing calculations-Breakover point between stripping and snubbing

158

(1)

2.202 Stripping/snubbing calculations-Height gain and casing pressure from stripping into influx

159

(1)

2.203 Stripping/snubbing calculations-Maximum Allowable surface pressure governed by casing burst pressure

159

(1)

2.204 Stripping/snubbing calculations-Maximum allowable surface pressure governed by formation

160

(1)

2.205 Stripping/snubbing calculations-Minimum surface pressure before stripping

160

(1)

2.206 Stripping/snubbing calculations-Constant BHP with a gas bubble rising

161

(1)

2.207 Stroke per minute required for a given annular velocity

161

(1)

2.208 Stuck pipe calculations-Method-1

161

(1)

2.209 Stuck pipe calculations-Method-2

162

(1)

2.210 Subsea considerations-Adjusting choke line pressure loss for higher mud weight

162

(1)

2.211 Subsea considerations-Casing burst pressure-subsea stack

162

(1)

2.212 Subsea considerations-Choke line pressure loss

163

(1)

2.213 Subsea considerations-Maximum allowable mud weight-Subsea stack from leakoff test

163

(1)

2.214 Subsea considerations-Casing pressure decrease when bringing well on choke

164

(1)

2.215 Subsea considerations-Velocity through choke line

164

(1)

2.216 Surface test pressure required to frac the formation

164

(1)

2.217 Total amount of solids generated during drilling

165

(1)

2.218 Total heat energy consumed by the engine

165

(1)

2.219 Total number of sacks of tail cement required

166

(1)

2.220 Total water requirement per sack of cement

166

(1)

2.221 Triplex pump factor

166

(1)

2.222 Upward force acting at the bottom of the casing shoe

167

(1)

2.223 Vertical curvature for deviated wells

167

(1)

2.224 Viscous shear stress at the outer mudcake boundary

167

(1)

2.225 Volume of cuttings generated per foot of hole drilled

168

(1)

2.226 Volume of dilution water or mud required to maintain circulating volume

168

(1)

2.227 Volume of fluid displaced for duplex pumps

168

(1)

2.228 Volume of fluid displaced for single-acting pump

169

(1)

2.229 Volume of fluid displaced for triplex pump

169

(1)

2.230 Volume of liquid (oil plus water) required to prepare a desired volume of mud

170

(1)

2.231 Volume of slurry per sack of cement

170

(1)

2.232 Volumes and strokes-Annular volume

171

(1)

2.233 Volumes and strokes-Drill string volume

171

(1)

2.234 Volumes and strokes-Total strokes

171

(1)

2.235 Weight of additive per sack of cement

172

(1)

2.236 Weighted cementing calculations

172

(2)

3 Well test analysis formulas and calculations

3.1 Analysis of a flow test with smoothly varying rates

174

(1)

3.2 Analysis of a post-fracture-Constant-rate flow test with boundary effects

174

(1)

3.3 Analysis of a post-fracture pressure buildup test with wellbore-storage distortion

175

(1)

3.4 Analysis of a well from a PI test

176

(1)

3.5 Analysis of DST flow data with Ramey type curves

177

(1)

3.6 Average fracture permeability (pseudo-steady state case for pressure build-up test)

178

(1)

3.7 Bottomhole flowing pressure during infinite-acting pseudoradial flow

178

(1)

3.8 Calculation of pressure beyond the wellbore (line-source solution)

179

(1)

3.9 Conventional DST design without a water cushion (collapse pressure calculation)

179

(1)

3.10 Diffusion depth in a geothermal well

180

(1)

3.11 Dimensionless buildup pressure for field calculations

180

(1)

3.12 Dimensionless buildup pressure for liquid flow

180

(1)

3.13 Dimensionless buildup pressure for steam or gas flow

181

(1)

3.14 Dimensionless buildup time

181

(1)

3.15 Dimensionless cumulative production (radial flow constant-pressure production)

182

(1)

3.16 Dimensionless drawdown correlating parameter by Carter

182

(1)

3.17 Dimensionless length (linear flow constant rate production/hydraulically fractured wells)

183

(1)

3.18 Dimensionless length (linear flow/constant-rate production/general case)

183

(1)

3.19 Dimensionless pressure (linear flow/constant rate production/general case)

183

(1)

3.20 Dimensionless pressure (linear flow/constant rate production/hydraulically-fractured wells)

184

(1)

3.21 Dimensionless pressure (radial-flow/constant pressure production)

184

(1)

3.22 Dimensionless pressure (radial-flow/constant rate production)

185

(1)

3.23 Dimensionless pressure drop across a skin at the well face

185

(1)

3.24 Dimensionless pressure drop during pseudo-steady state flow for a fractured vertical well in a square drainage area

186

(1)

3.25 Dimensionless pressure drop during pseudo-steady state flow for a horizontal well in a bounded reservoir

186

(1)

3.26 Dimensionless production time

187

(1)

3.27 Dimensionless rate (radial flow/constant pressure production)

187

(1)

3.28 Dimensionless shut-in time for MDH method

188

(1)

3.29 Dimensionless storage constant for gases

188

(1)

3.30 Dimensionless storage constant for liquids

188

(1)

3.31 Dimensionless time (linear flow/constant rate production/general case)

189

(1)

3.32 Dimensionless time (linear flow/constant rate production/hydraulically fractured wells)

189

(1)

3.33 Dimensionless time (radial flow/constant rate production)

190

(1)

3.34 Dimensionless time function (transient heat transfer to the formation)

190

(1)

3.35 Dimensionless wellbore storage coefficient (compressible fluids for pressure build-up test)

191

(1)

3.36 Flow period duration (hydraulically fractured wells)

191

(1)

3.37 Fracture conductivity (bilinear-flow regime in gas wells)

191

(1)

3.38 Fracture conductivity during bilinear flow

192

(1)

3.39 Inflow performance relationship (IPR) for horizontal wells in solution gas-drive reservoirs (Fetkovich)

192

(1)

3.40 Inflow performance relationship (IPR) for horizontal wells in solution gas-drive reservoirs (Vogel)

193

(1)

3.41 Interporosity flow coefficient in pressure build-up test

193

(1)

3.42 Minimum shut-in time to reach pseudo-steady state for tight gas reservoirs being hydraulically fractured

194

(1)

3.43 Permeability and reservoir pressure from buildup tests

194

(1)

3.44 Permeability and skin factor from a constant-rate flow test

195

(1)

3.45 Pressure buildup equation (Horner equation)

196

(1)

3.46 Radius of investigation

196

(1)

3.47 Radius of investigation (flow time)

196

(1)

3.48 Radius of investigation (shut-in time)

197

(1)

3.49 Raymer hunt transform (porosity/transit time relationship)

197

(1)

3.50 Reservoir permeability

198

(1)

3.51 Shut-in time for pressure build-up test (Dietz method)

198

(1)

3.52 Skin during infinite-acting pseudoradial flow for vertical wells

199

(1)

3.53 Skin estimation type-1 (pressure buildup test)

199

(1)

3.54 Slope of Horner plot in pressure buildup test

200

(1)

3.55 Slope of pseudo-steady state flow in pressure buildup test

200

(1)

3.56 Time to pseudo-steady state (single well-circular reservoir)

200

(1)

3.57 Time to reach the semi-steady state for a gas well in a circular or square drainage area

201

(1)

3.58 True wellbore storage coefficient (pressure build-up test)

201

(1)

3.59 Well flow efficiency (geothermal well)

202

(1)

3.60 Well shut-in pressure during buildup (Homer plot)

202

(2)

4 Production engineering formulas and calculations

4.1 Acid penetration distance (acidizing)

204

(1)

4.2 Additional pressure drop in the skin zone

205

(1)

4.3 Additive crystalline salt amount to increase the density-Method I (single-salt systems)

205

(1)

4.4 Additive crystalline salt amount to increase the density-Method II (single-salt systems)

206

(1)

4.5 Additive crystalline salt and water amount to increase the density-Method I (two-salt systems)

206

(1)

4.6 Annulus pressure loss due to friction during hydraulic fracturing (laminar flow)

207

(1)

4.7 Annulus pressure loss due to friction during hydraulic fracturing (turbulence flow)

207

(1)

4.8 Approximate ideal counterbalanced load

208

(1)

4.9 Average downstroke load (sucker-rod pump)

208

(1)

4.10 Average fracture width (acidizing)

208

(1)

4.11 Average permeability of a hydraulically fractured formation

209

(1)

4.12 Average specific weight of the formation (hydraulic fracturing)

209

(1)

4.13 Average upstroke load (sucker-rod pump)

210

(1)

4.14 Average wellbore fluid density (completion and workover fluids)

210

(1)

4.15 Capacity ratio of a hydraulically fractured surface

210

(1)

4.16 Choke discharge coefficient

211

(1)

4.17 Close-ended displacement volume of pipe

211

(1)

4.18 Convective mass transfer for laminar flow (acidizing)

212

(1)

4.19 Convective mass transfer for turbulent flow (acidizing)

212

(1)

4.20 Correct counterbalance (sucker-rod pump)

213

(1)

4.21 Corresponding reciprocal rate (post-fracture production-Constant Bottomhole flowing conditions)

213

(1)

4.22 Damaged/undamaged zone productivity comparison (acidizing)

214

(1)

4.23 Density of brine (completion and workover fluids)

214

(1)

4.24 Dimensionless fracture width for linear vertical fracture (Geertsma & Klerk)

214

(1)

4.25 Downhole operating pressure (hydraulic fracturing)

215

(1)

4.26 Entrance hole size (perforation)

215

(1)

4.27 Equivalent skin factor in fractured wells

216

(1)

4.28 Filter cake on the fracture (acidizing)

216

(1)

4.29 Flow coefficient during drawdown

217

(1)

4.30 Flow rate through orifice

217

(1)

4.31 Flow through fracture in response to pressure gradient

217

(1)

4.32 Formation fluid compressibility (acidizing)

218

(1)

4.33 Fracture area of a hydraulically fractured formation

218

(1)

4.34 Fracture coefficient of a hydraulically fractured reservoir

219

(1)

4.35 Fracture fluid coefficient for reservoir-controlled liquids

219

(1)

4.36 Fracture fluid coefficient for viscosity-controlled liquids

220

(1)

4.37 Fracture geometry (acidizing)

220

(1)

4.38 Fracture gradient (hydraulic fracturing)

220

(1)

4.39 Fracture-fluid invasion of the formation (acidizing)

221

(1)

4.40 Frictional pressure drop (Economides and Nolte)

221

(1)

4.41 Gas velocity under sonic flow conditions (through choke)

222

(1)

4.42 Hydraulic fracture efficiency

222

(1)

4.43 Hydraulic horse power for a hydraulic fracturing operation

223

(1)

4.44 Ideal fracture conductivity created by acid reaction (acidizing)

223

(1)

4.45 Incremental density in any wellbore interval (completion and workover fluids)

223

(1)

4.46 Initial rate following a hydraulic fracturing operation

224

(1)

4.47 Injection pressure for hydraulic fracturing

224

(1)

4.48 Lifetime of a hydraulically fractured well

225

(1)

4.49 Mass of rock dissolved per unit mass of acid (acidizing)

225

(1)

4.50 Mass transfer in acid solutions by Fick's law (acidizing)

225

(1)

4.51 Maximum treatment pressure (hydraulic fracturing)

226

(1)

4.52 Mechanical resistant torque (PCP)

226

(1)

4.53 Minimum polished rod load (sucker rod pump)

226

(1)

4.54 Peclet number for fluid loss (acidizing)

227

(1)

4.55 Perforation friction factor

227

(1)

4.56 Perforation friction pressure

228

(1)

4.57 Perforation hole size (perforation)

228

(1)

4.58 Perforation length in formation

228

(1)

4.59 Perforation penetration ratio (formation of interest/reference formation)

229

(1)

4.60 Perforation skin factor

229

(1)

4.61 Pore growth function (acidizing)

230

(1)

4.62 Pressure drop across perforations in gas wells

230

(1)

4.63 Pressure drop across perforations in oil wells

231

(1)

4.64 Pressure loss due to perforations during hydraulic fracturing

232

(1)

4.65 Pressure loss due to perforations during hydraulic fracturing-2

232

(1)

4.66 Principal stress due to petro-static pressure (hydraulic fracturing)

232

(1)

4.67 Productivity index (for generating composite IPR curve)

233

(1)

4.68 Productivity ratio

233

(1)

4.69 Productivity ratio calculation of a hydraulically-fractured formation

234

(1)

4.70 Pseudo skin factor due to partial penetration (Brons and Marting method)

234

(1)

4.71 Pseudo-skin factor due to partial penetration (Yeh and Reynolds correlation)

235

(1)

4.72 Pseudo-skin factor due to partial penetration (Odeh correlation)

236

(1)

4.73 Pseudo-skin factor due to partial penetration (Papatzacos correlation)

236

(1)

4.74 Pseudo-skin factor due to perforations

237

(1)

4.75 Quantifying formation damage and improvement

238

(1)

4.76 Recommended underbalanced environment for perforation

239

(1)

4.77 Reynolds number for acid flow into the fracture (acidizing)

239

(1)

4.78 Reynolds number for fluid loss (acidizing)

239

(1)

4.79 Sand weight needed to refill a hydraulically fractured reservoir volume

240

(1)

4.80 Shape factor expressed as skin factor for vertical wells

240

(1)

4.81 Single-phase gas flow (subsonic)

240

(1)

4.82 Single-phase liquid flow through choke

241

(1)

4.83 Skin factor

241

(1)

4.84 Skin factor by Hawkins method

242

(1)

4.85 Skin factor due to partial penetration

242

(1)

4.86 Skin factor due to reduced crushed-zone permeability

243

(1)

4.87 Skin factor for a deviated well

243

(1)

4.88 Slope of Semilog plot for bottom-hole flowing pressure vs time for drawdown test

244

(1)

4.89 Sucker rod-Peak polished rod load

244

(1)

4.90 Suspension property of static fluids (completion and workover fluids)

245

(1)

4.91 Tangential annular flow of a power law fluid

245

(1)

4.92 Temperature at choke outlet

246

(1)

4.93 The z component of the force of the fluid on the wetted surface of the pipe

246

(1)

4.94 Total skin in partially depleted wells for a buildup test

246

(1)

4.95 Velocity distribution in the annular slit of a falling-cylinder viscometer

247

(1)

4.96 Velocity distribution in the narrow annular region in annular flow with inner cylinder moving axially

247

(1)

4.97 Velocity distribution of flow through an annulus

248

(1)

4.98 Velocity of fluid in annulus

248

(1)

4.99 Velocity of fluid in pipe

249

(1)

4.100 Viscous force acting on the rod over the narrow annular region

249

(1)

4.101 Volume capacity of pipe

250

(1)

4.102 Volume of fluid loss per unit area measured in a dynamic test (acidizing)

250

(1)

4.103 Volume of fluid loss per unit area measured in a static test (acidizing)

250

(1)

4.104 Volume of rock dissolved per unit volume of acid (acidizing)

251

(1)

4.105 Water quantity that dilutes the original brine with assumed density (two-salt systems)

251

(1)

4.106 Weight of crystalline CaCl2 and CaBr2 salt addition to brine (two-salt systems)

252

(1)

4.107 Well flowing pressure (line-source solution by including skin factor)

252

(1)

4.108 Well flowing pressure under Pseudo-steady state flow for non-circular reservoirs

253

(1)

4.109 Wellbore pressure loss due to friction during hydraulic fracturing (laminar flow)

253

(1)

4.110 Wellbore pressure loss due to friction during hydraulic fracturing (turbulence flow)

254

(1)

4.111 Wellbore storage

254

(1)

4.112 Wellbore storage due to fluid level

254

(1)

4.113 Wellhead pressure (multiphase flow across the choke)

255

(1)

4.114 Workover operations (maximum allowed tubing pressure)

255

(1)

4.115 Young Modulus by using sonic travel time (acidizing)

256

(2)

5 Fluid flow and transport phenomena formulas and calculations

5.1 Archimedes number

258

(1)

5.2 Average number of collisions to reduce neutron energy

259

(1)

5.3 Average velocity of a falling film with variable viscosity

259

(1)

5.4 Average velocity of flow through a circular tube

260

(1)

5.5 Average velocity of flow through an annulus

260

(1)

5.6 Average velocity of fluids in flow of two adjacent immiscible fluids

261

(1)

5.7 Average velocity over the cross section of a falling film

261

(1)

5.8 Blowdown time in unsteady gas flow

262

(1)

5.9 Boltzmann equation

262

(1)

5.10 Boussinesq approximation-Buoyancy

262

(1)

5.11 Brinkman number

263

(1)

5.12 Buckingham Reiner equation

263

(1)

5.13 Calculation of mass flow rate

264

(1)

5.14 Calculation of momentum flux

264

(1)

5.15 Combined momentum flux tensor

265

(1)

5.16 Combined radiation and convection

265

(1)

5.17 Compressible flow in a horizontal circular tube

265

(1)

5.18 Compton scattering

266

(1)

5.19 Correction factor for stagnant film according to the penetration model

266

(1)

5.20 Darcy Weisbach equation (head loss form)

267

(1)

5.21 Darcy Weisbach equation (pressure loss form)

267

(1)

5.22 Dean number

267

(1)

5.23 Deborah number

268

(1)

5.24 Decay of thermal neutrons

268

(1)

5.25 Determination of the controlling resistance

269

(1)

5.26 Determination of the diameter of a falling sphere

269

(1)

5.27 Diffusion from an instantaneous point source

270

(1)

5.28 Diffusion in a moving film

270

(1)

5.29 Diffusion in polymers

270

(1)

5.30 Diffusion Into a falling liquid film (gas absorption)

271

(1)

5.31 Diffusion of low-density gases with equal mass

271

(1)

5.32 Diffusion potential

272

(1)

5.33 Diffusion through a non-isothermal spherical film

272

(1)

5.34 Diffusion through a stagnant film

273

(1)

5.35 Diffusion through a stagnant gas film

273

(1)

5.36 Diffusion through cleat spacing in coalbed methane reservoirs

273

(1)

5.37 Diffusion with a heterogeneous chemical reaction

274

(1)

5.38 Diffusion with a homogeneous chemical reaction

274

(1)

5.39 Diffusion, convection, and chemical reaction

275

(1)

5.40 Drag coefficient

275

(1)

5.41 Drag force

275

(1)

5.42 Draining of a cylindrical tank

276

(1)

5.43 Draining of a spherical tank

276

(1)

5.44 Eckert number

277

(1)

5.45 Effective emissivity of a hole

277

(1)

5.46 Effective thermal conductivity for a solid with spherical inclusions

277

(1)

5.47 Efflux time for draining a conical tank

278

(1)

5.48 Ekman number

278

(1)

5.49 Elimination of circulation in a rising gas bubble

279

(1)

5.50 Energy emitted from the surface of a black body

279

(1)

5.51 Estimation of diffusivity of liquids

279

(1)

5.52 Estimation of self diffusivity at high density

280

(1)

5.53 Estimation of the viscosity of a pure liquid

280

(1)

5.54 Euler number

281

(1)

5.55 Fanning friction factor (laminar flow)

281

(1)

5.56 Fanning's friction factor (turbulent flow)

282

(1)

5.57 Fick's law of binary diffusion

282

(1)

5.58 Film condensation on vertical pipes

282

(1)

5.59 Film condensation on vertical tubes

283

(1)

5.60 Film thickness of a falling film on a conical surface

284

(1)

5.61 Flow in a liquid-liquid ejector pump

284

(1)

5.62 Flow in a slit with uniform cross flow

285

(1)

5.63 Flow near a corner

285

(1)

5.64 Flow of power law fluid through a narrow slit

286

(1)

5.65 Fluid kinetic force in conduits

286

(1)

5.66 Fluid kinetic force in flow around submerged objects

286

(1)

5.67 Form drag

287

(1)

5.68 Free air correction-Gravity survey

287

(1)

5.69 Free batch expansion of a compressible fluid

288

(1)

5.70 Free convection heat transfer from a vertical plate

288

(1)

5.71 Friction drag

288

(1)

5.72 Friction factor for creeping flow around a sphere

289

(1)

5.73 Friction factor in flow around submerged objects

289

(1)

5.74 Friction factor in flow through conduits

290

(1)

5.75 Friction factor in packed column (laminar)

290

(1)

5.76 Friction factor in packed column (turbulant)

290

(1)

5.77 Galilei number

291

(1)

5.78 Gas absorption from rising bubbles for creeping flow

291

(1)

5.79 Gas absorption through bubbles

292

(1)

5.80 Gas absorption with chemical reaction in an agitated tank

292

(1)

5.81 Gas absorption with rapid reaction

293

(1)

5.82 Gas mass rate flow in compressible tube flow

293

(1)

5.83 Graetz number

293

(1)

5.84 Graham equation viscosity ratio

294

(1)

5.85 Grash of number

294

(1)

5.86 Hagen number

295

(1)

5.87 Hagen-Poiseuille equation

295

(1)

5.88 Influence of changing interfacial area on mass transfer

296

(1)

5.89 Knudsen flow

296

(1)

5.90 Krieger Dougherty equation viscosity ratio

296

(1)

5.91 Laminar flow along a flat plate (approximate solution)

297

(1)

5.92 Laminar flow of an incompressible power-law fluid in a circular tube

297

(1)

5.93 Laplace number

298

(1)

5.94 Lewis number

298

(1)

5.95 Mach number

298

(1)

5.96 Manning formula

299

(1)

5.97 Marangoni number

299

(1)

5.98 Mass absorption (attenuation) coefficient

300

(1)

5.99 Mass flow rate as a function of the modified pressure drop in a network of tubes

300

(1)

5.100 Mass flow rate in a rotating cone pump

300

(1)

5.101 Mass rate of flow

301

(1)

5.102 Mass rate of flow in a squared duct

301

(1)

5.103 Mass rate of flow of a falling film

302

(1)

5.104 Mass rate of flow through a circular tube

302

(1)

5.105 Mass transfer for creeping flow around a gas bubble

303

(1)

5.106 Mass transfer to drops and bubbles

303

(1)

5.107 Maximum flow rate (Vogel's equation)

303

(1)

5.108 Maximum velocity of a falling film

304

(1)

5.109 Maximum velocity of flow through a circular tube

304

(1)

5.110 Maximum-velocity Vz-maximum of a falling film

305

(1)

5.111 Method for separating helium from natural gas

305

(1)

5.112 Modified capillary number

306

(1)

5.113 Modified Van Driest equation

306

(1)

5.114 Momentum flux distribution of flow through a circular tube

306

(1)

5.115 Momentum flux distribution of flow through an annulus

307

(1)

5.116 Momentum flux profile of fluids in flow of two adjacent immiscible fluids

307

(1)

5.117 Momentum fluxes for creeping flow into a slot

308

(1)

5.118 Mooney equation viscosity

308

(1)

5.119 Non-Newtonian flow in annulus

309

(1)

5.120 Nusselt number

309

(1)

5.121 Ohnesorge number

310

(1)

5.122 Potential flow around a cylinder

310

(1)

5.123 Prandtl number

310

(1)

5.124 Pressure distribution in a creeping flow around a sphere

311

(1)

5.125 Pressure drop per length of the adsorption unit

311

(1)

5.126 Pressure loss due to sudden enlargement

312

(1)

5.127 Reynolds number

312

(1)

5.128 Schmidt number

313

(1)

5.129 Sherwood number

313

(1)

5.130 Slit flow in Bingham fluid

313

(1)

5.131 Smoluchowski equation

314

(1)

5.132 Stanton number

314

(1)

5.133 Stefan number

315

(1)

5.134 Stokes number

315

(1)

5.135 Strouhal number

315

(1)

5.136 Taylor dispersion (axial dispersion coefficient)

316

(1)

5.137 Taylor equation viscosity

316

(1)

5.138 Taylor number

317

(1)

5.139 Theory of diffusion in colloidal suspensions

317

(1)

5.140 Toricelli equation

317

(1)

5.141 Total force of the fluid on the sphere in a creeping flow around a sphere

318

(1)

5.142 Velocity distribution in a creeping flow around a sphere

318

(1)

5.143 Velocity distribution of a falling film with variable viscosity

319

(1)

5.144 Velocity distribution of flow through a circular tube

319

(1)

5.145 Velocity profile of fluids in flow of two adjacent immiscible fluids

319

(1)

5.146 Viscosity by a falling-cylinder viscometer

320

(1)

5.147 Winsauer equation

320

(4)

6 Well log analysis, geophysics, petrophysics formulas, and calculations

6.1 Acoustic transit time

324

(1)

6.2 Amplitude transmission coefficient in seismic reflection and refraction

324

(1)

6.3 Apparent intensity reflected by recorder (gamma ray)

325

(1)

6.4 Apparent resistivity

325

(1)

6.5 Apparent sorption compressibility

325

(1)

6.6 Atlas wireline neutron lifetime log

326

(1)

6.7 Barenblatt-Chorin universal velocity distribution

326

(1)

6.8 Coefficient of reflection

327

(1)

6.9 Compaction correction factor for sonic logs in shale lithology

327

(1)

6.10 Composite capture cross section of the formation (Schlumberger thermal decay time tool)

327

(1)

6.11 Correlation of mud cake resistivity to mud resistivity

328

(1)

6.12 Correlation of mud filtrate resistivity to mud resistivity

328

(1)

6.13 Diffuse-layer thickness

328

(1)

6.14 Effect of clay on conductivity

329

(1)

6.15 Effective photoelectric absorption cross section index

329

(1)

6.16 Electric resistance to a radial current from a wellbore

330

(1)

6.17 Electrochemical potential (SP log)

330

(1)

6.18 Electrokinetic potential (developed across a mud cake)

330

(1)

6.19 Electron density index (GR absorption logging)

331

(1)

6.20 Epithermal neutron diffusion coefficient

331

(1)

6.21 Epithermal neutron distribution (epithermal neutron flux)

332

(1)

6.22 fedi and Hammack equation

6.23 Formation conductivity in dual water model

332

(1)

6.24 Formation factor-Archie's equation

333

(1)

6.25 Formation factor (Archie's equation with resistivity logs)

333

(1)

6.26 Formation resistivity and permeability (Carothers) relation for limestones

334

(1)

6.27 Formation resistivity and permeability (Carothers) relation for sandstones

334

(1)

6.28 Formation resistivity and porosity relations for carbonate rocks

334

(1)

6.29 Formation resistivity and porosity relations from well log data based on Porter and Carothers data

335

(1)

6.30 Fraction of total porosity occupied by clays

335

(1)

6.31 Fresh water-filled porosity (fresh-water-bearing limestones)

336

(1)

6.32 Fxo/Fs approach

336

(1)

6.33 Gamma ray log shale index

336

(1)

6.34 General form of the Archie equation-Water saturation from resistivity logs

337

(1)

6.35 Generalized relationship between formation resistivity factor and porosity (Chevron formula)

337

(1)

6.36 Geometric coefficient for the electrode

338

(1)

6.37 Geometric coefficient for the lateral device

338

(1)

6.38 Geometric coefficient for the normal sonde

338

(1)

6.39 Half thickness value

339

(1)

6.40 Hingle nonlinear-resistivity/linear-porosity crossplot

339

(1)

6.41 Humble equation (formation resistivity factor vs porosity)

340

(1)

6.42 Integrated radial geometric factor

340

(1)

6.43 Lennard Jones potential

340

(1)

6.44 Linear absorption (attenuation) coefficient

341

(1)

6.45 Maximum potential for self-potential (SP) log

341

(1)

6.46 Mean free path (photon absorption)

342

(1)

6.47 Membrane potential

342

(1)

6.48 Neutron lethargy (logarithmic energy decrement)

342

(1)

6.49 Neutron porosity of shale zone

343

(1)

6.50 Oil saturation determination (IE and CDN logs)

343

(1)

6.51 Pair production (gamma ray interactions)

343

(1)

6.52 Phillips equation (sandstones)

344

(1)

6.53 Photoelectric absorption cross sectional area

344

(1)

6.54 Pickett crossplot

345

(1)

6.55 Poisson's ratio (seismic arrival time method)

345

(1)

6.56 Porosity by using density log data

345

(1)

6.57 Porosity corrected for gas effect

346

(1)

6.58 Porosity-neutron flux relationship

346

(1)

6.59 Rate of radioactive decay

346

(1)

6.60 Relation between concentration of K, Th, or U and recorded total gamma ray signal

347

(1)

6.61 Relationship between rock resistivity and water saturation

347

(1)

6.62 Relationship between SSP and Rw (NaCl predominant)

348

(1)

6.63 Relationship between SSP and Rw (non-ideal shale membrane)

348

(1)

6.64 Relationship between SSP and Rw for water containing salts (non-NaCl predominant)

348

(1)

6.65 Resistivity of a partially saturated shaly sand with hydrocarbons (Vsh, models)

349

(1)

6.66 Resistivity of a water-saturated shaly sand (Vsh, models)

349

(1)

6.67 Rock conductivity (relatively clean water bearing rocks)

350

(1)

6.68 Shale index from gamma ray spectrometry

350

(1)

6.69 Simandoux (total shale) equation

351

(1)

6.70 Sonic porosity (Raymer Hunt Gardner method)

351

(1)

6.71 Spacing between transmitter and receiver

352

(1)

6.72 Static self potential

352

(1)

6.73 Time between the initiation of the pulse and the first arrival acoustic energy at the receiver

353

(1)

6.74 Time-average relation in compacted formations (porosity/transit time relationships)

353

(1)

6.75 Time-average relation in uncompacted formations (porosity/transit time relationships)

353

(1)

6.76 Tortuosity (resistivity logs)

354

(1)

6.77 Total rock conductivity

354

(1)

6.78 True porosity from sonic log (corrected for compaction)

355

(1)

6.79 True resistivity-Archie

355

(1)

6.80 Volumetric photoelectric absorption cross section

355

(1)

6.81 Water salinity index ratio

356

(1)

6.82 Water saturation determination (IE and CDN logs)

356

(1)

6.83 Water saturation from neutron tools

356

(1)

6.84 Water saturation-Resistivity logs

357

(1)

6.85 Wavelength equation

357

(1)

6.86 Wellbore electric voltage generation

358

(1)

7 Petroleum economics formulas and calculations

7.1 Acceptable reliability level

359

(1)

7.2 Additional production estimation with new wells

360

(1)

7.3 Annual gross revenue after royalties and wellhead taxes

360

(1)

7.4 Annuity from future value

360

(1)

7.5 Annuity from present value

361

(1)

7.6 Average annual rate of return method

361

(1)

7.7 Average book rate of return method

362

(1)

7.8 Calculation of unknown interest rate

362

(1)

7.9 Compound interest

363

(1)

7.10 Cost depletion

363

(1)

7.11 Cumulative interest on operational expenses during the lifetime of a well

364

(1)

7.12 Effective interest rate for periodic compounding

364

(1)

7.13 Exploration efficiency

364

(1)

7.14 Future value of an annuity

365

(1)

7.15 Future value of present sum

365

(1)

7.16 Generalized expected value calculation

366

(1)

7.17 Growth rate of return for continuous compounding

366

(1)

7.18 Hoskold method for annual rate of return prediction-1

366

(1)

7.19 Hoskold method for annual rate of return prediction-2

367

(1)

7.20 Initial capital needed to survive in a minimum chance scenario

367

(1)

7.21 Meterage model

368

(1)

7.22 Minimum number of jobs to survive in a minimum chance scenario

368

(1)

7.23 Minimum profit ratio per a risky job

369

(1)

7.24 Net cash flow

369

(1)

7.25 Net present value

369

(1)

7.26 Operating cash income

370

(1)

7.27 Payback Period

370

(1)

7.28 Present value of an annuity

370

(1)

7.29 Present value of a deferred annuity

371

(1)

7.30 Present value of future sum

371

(1)

7.31 Present value of profit/investment ratio for an oil well

372

(1)

7.32 Present value of uniform gradient series

372

(1)

7.33 Present worth expectation for a risky job

373

(1)

7.34 Probability of an oilfield discovery

373

(1)

7.35 Profitability index

373

(1)

7.36 Rate of growth per unit of exploration length

374

(1)

7.37 Simple interest

374

(1)

7.38 Total expected additional production discovery

375

(1)

7.39 Total expected additional production discovery in constant production per unit area

375

(1)

7.40 Total new production area estimation expected to be discovered

376

(1)

8 Phase behavior and thermodynamics formulas and calculations

8.1 Amount of heat required to increase the temperature

377

(1)

8.2 Benedict-Webb-Rubin PVT equation

378

(1)

8.3 Critical pressure Cavett relation

378

(1)

8.4 Critical temperature Cavett method

379

(1)

8.5 Effective thermal conductivity of composite solids

379

(1)

8.6 Einstein equation effective viscosity

379

(1)

8.7 Equilibrium vaporization ratio

380

(1)

8.8 Equilibrium vaporization ratio of heptane

380

(1)

8.9 Evaporation loss from an oxygen tank

380

(1)

8.10 Expansion factor for diffuse layer

381

(1)

8.11 Flat-plate boundary layer model

381

(1)

8.12 Freezing of a spherical drop

382

(1)

8.13 General thermal conductivity

382

(1)

8.14 Heat conduction in a cooling fan

382

(1)

8.15 Heat flux distribution in a wall

383

(1)

8.16 Heat loss by free convection from a horizontal pipe

383

(1)

8.17 Heat released during in-situ combustion given by Burger & Sahuquet

384

(1)

8.18 Heat transfer coefficient for condensation-Pure vapors on solid surface

384

(1)

8.19 Heat transfer in packed bed

385

(1)

8.20 Heat transfer rate in laminar forced convection along heated flat plate

385

(1)

8.21 Jacoby aromaticity factor

385

(1)

8.22 Joule Thompson expansion

386

(1)

8.23 Latent heat of hydrocarbon mixture

386

(1)

8.24 Mixing fluids of different densities

387

(1)

8.25 Mole fraction of a component in liquid phase

387

(1)

8.26 Mole fraction of a component in vapor phase

387

(1)

8.27 Necessary inhibitor concentration required in liquid phase to reduce hydrate point

388

(1)

8.28 Peng Robinson characterization factor

388

(1)

8.29 Peng Robinson PVT equation

388

(1)

8.30 Pseudo-reduced conditions

389

(1)

8.31 Radiant heat transfer between disks

389

(1)

8.32 Radiated energy flux

390

(1)

8.33 Radiation across an annular gap

390

(1)

8.34 Radiation shields

391

(1)

8.35 Rayleigh number

391

(1)

8.36 Redlich-Kwong PVT equation

391

(1)

8.37 Reservoir gas density

392

(1)

8.38 Stefan-Boltzmann law

392

(1)

8.39 Surface temperature of a heating coil

393

(1)

8.40 Temperature due to free convection

393

(1)

8.41 Temperature increase due to forced convection

393

(1)

8.42 Temperature profile after viscous heat transfer

394

(1)

8.43 Temperature profile with a nuclear heat source

394

(1)

8.44 Thermal conductivity for pure metals

395

(1)

8.45 Thermal conductivity of polyatomic gases

395

(1)

8.46 Thermal conductivity of liquids

395

(1)

8.47 Thermal conductivity of solids with gas pockets

396

(1)

8.48 Thermal diffusivity

396

(1)

8.49 Thermal energy of a fissionable substance

397

(1)

8.50 Thermoelastic effect on stress

397

(1)

8.51 Unsteady evaporation of a liquid

397

(1)

8.52 Van Der Waals PVT equation

398

(1)

8.53 Wien displacement law

398

(1)

9 Petroleum engineering laboratory formulas and calculations

9.1 Absolute viscosity for Saybolt viscosimeter measurements

399

(1)

9.2 Absolute viscosity for Ubbelohde viscosimeter measurements

400

(1)

9.3 Adhesion tension

400

(1)

9.4 Amott-Harvey wettability index

400

(1)

9.5 Apparent facial tension (De Nouy ring method)

401

(1)

9.6 Average compressibility of oil

401

(1)

9.7 Average gas solubility

401

(1)

9.8 Characterization factor for oil distillation

402

(1)

9.9 Clasius-Clapeyron equation for water vapor

402

(1)

9.10 Clay concentration of drilling mud (methylene blue test)

402

(1)

9.11 Contact angle

403

(1)

9.12 Correction factor for facial tension (De Nouy ring method)

404

(1)

9.13 Drilling mud density (solid content analysis of drilling muds)

404

(1)

9.14 Effective porosity

405

(1)

9.15 Error percentage of porosity measurements

405

(1)

9.16 Facial tension (De Nouy ring method)

405

(1)

9.17 Filtration rate for API fluid loss measurement

406

(1)

9.18 Filtration volume without spurt loss

406

(1)

9.19 Filtration volume with spurt loss

407

(1)

9.20 Gas permeability measurement (lab measurement using Klinkenberg effect)

407

(1)

9.21 Kinematic viscosity for Saybolt viscosimeter measurements

408

(1)

9.22 liquid permeability (permeameter lab measurement)

408

(1)

9.23 Permeability determination using porosity data (Kozeny-Carman equation)

409

(1)

9.24 Pycnometer volume correction

409

(1)

9.25 Relative centrifugal force

409

(1)

9.26 Relative permeability

410

(1)

9.27 Reservoir wettability characterization (rise in core method)

410

(1)

9.28 Resistance

411

(1)

9.29 Resistivity

411

(1)

9.30 Resistivity index-Archie's law

412

(1)

9.31 Solid content ratio of drilling mud

412

(1)

9.32 Specific gravity of air (upper phase) (De Nouy ring method)

412

(1)

9.33 Standard discharge time for Saybolt viscosimeter measurements

413

(1)

9.34 Total porosity

413

(1)

9.35 USBM wettability index

413

(1)

9.36 Yield of clays as drilling fluids

414

(2)

10 Enhanced oil recovery and geothermal formulas and calculations

10.1 Areal extent of heated zone

416

(1)

10.2 Average reservoir temperature in a cyclical steam injection process

416

(1)

10.3 Bottomhole pressure in a static geothermal well

417

(1)

10.4 Chromatographic lag in polymer flooding

417

(1)

10.5 Cumulative heat injected for steam drive-Myhill and Stegemeier

417

(1)

10.6 Depth of carbon dioxide alteration front (Battlet-Gouedard, 2006)

418

(1)

10.7 Depth of carbon dioxide alteration front (Kutchko, 2008)

418

(1)

10.8 Dimensionless heat injection rate (Gringarten and Sauty)

418

(1)

10.9 Dimensionless injection rate of air for in-situ combustion

419

(1)

10.10 Dimensionless ratio of effective volumetric heat capacity of injected steam to that of the steam zone

419

(1)

10.11 Dimensionless time for semi-steady state flow in coal bed methane reservoirs

420

(1)

10.12 Dimensionless time in wet combustion by Kuo

420

(1)

10.13 Dykstra-Parsons coefficient

421

(1)

10.14 Effective (apparent) transmissivity

421

(1)

10.15 Effective oil transmissivity for thermal stimulation

421

(1)

10.16 Equivalent atomic H/C ratio of fuel for in-situ combustion

422

(1)

10.17 Equivalent volume of steam injected-Myhill and Stegemeier

422

(1)

10.18 Equivalent water saturation in burned zone in-situ combustion by Nelson

423

(1)

10.19 Estimates of cumulative oil displacement

423

(1)

10.20 Estimates of oil displacement rate

423

(1)

10.21 Estimating fraction of heat injected in latent form (steam-drive)

424

(1)

10.22 Estimating heat injection rate (steam-drive)

424

(1)

10.23 Estimating performance prediction of steam-drive reservoirs (cumulative oil produced)

425

(1)

10.24 Estimating recovery steam drive (volume of steam in reservoir)

425

(1)

10.25 Estimating steady-state five-spot injection rate (steam-drive)

425

(1)

10.26 Estimating volume of steam injection (steam-drive)

426

(1)

10.27 Fraction of heat injected in latent form-Myhill and Stegemeier

426

(1)

10.28 Fraction of injected heat remaining in reservoir

427

(1)

10.29 Fractional flow of water in hot floods dependent on temperature and saturation in hot water flood

427

(1)

10.30 Growth of steam-heated area-Marx-Langenheim

428

(1)

10.31 Heat loss over an incremental length of a well (two-phase flow)

428

(1)

10.32 Heat ratio of contents in a geothermal reservoir

428

(1)

10.33 Heat released during in-situ combustion-Burger & Sahuguet

429

(1)

10.34 Heat remaining in reservoir-Marx and Langenheim

429

(1)

10.35 Horizontal well breakthrough time in a bottom-water-drive reservoir

430

(1)

10.36 Ignition delay time in in-situ combustion

430

(1)

10.37 Injected air required to burn through unit bulk of reservoir for in-situ combustion by Nelson and McNiel

431

(1)

10.38 Mass of fuel burned per unit bulk reservoir volume combustion-Nelson and McNiel

431

(1)

10.39 Minimum air flux required for advance of fire front-Nelson and McNiel

432

(1)

10.40 Oil breakthrough newly swept zone

432

(1)

10.41 Oil recovery as a function of the fraction of oil displaced from heated zone

432

(1)

10.42 Oil solubilization factor

433

(1)

10.43 Oil volume at breakthrough by Craig, Geffen, and Morse

433

(1)

10.44 Oil-steam ratio-Marx & Langenheim

434

(1)

10.45 Proppant settlement in fracture

434

(1)

10.46 Rate of advancement of combustion front (in-situ combustion)

434

(1)

10.47 Rate of growth of heated zone in hot water heated reservoir

435

(1)

10.48 Rate of oxygen-reacted per unit mass of fuel

435

(1)

10.49 Relationship with real and dimensionless time in hot water floods

436

(1)

10.50 Reservoir flow for gas flow in a formation

436

(1)

10.51 Reservoir flow through the wellbore of a geothermal well

436

(1)

10.52 Saturation of layer under hot water flood

437

(1)

10.53 Slug size in polymer floods

437

(1)

10.54 Temperature increase with time during in-situ combustion process

438

(1)

10.55 Temperature of a producing geothermal well

438

(1)

10.56 Temperature of a single-phase liquid or gas injected geothermal well

439

(1)

10.57 Total heat loss of a geothermal well

439

(1)

10.58 Total oil production from in-situ combustion-Nelson & McNeil

439

(1)

10.59 Total oil production from wet in-situ combustion-Nelson & McNeil

440

(1)

10.60 Total water production from in-situ combustion-Nelson & McNeil

440

(1)

10.61 Volume of burned part of reservoir (in-situ combustion)

441

(1)

10.62 Volume of reservoir burnt by wet combustion

441

(1)

10.63 Volumetric heat capacity

441

(1)

10.64 Wet combustion design (in-situ combustion)

442

(2)

11 Geomechanics and fracturing formulas and calculations

11.1 Axial stress around vertical wellbore

444

(1)

11.2 Axis of a deviated borehole from an arbitrary origin

444

(1)

11.3 Bulk modulus (using Lame)

445

(1)

11.4 Bulk modulus (using Poisson's ratio and Lame's constant)

445

(1)

11.5 Bulk modulus (using Poisson's ratio and shear modulus)

445

(1)

11.6 Change in pore volume due to initial water and rock expansion

446

(1)

11.7 Cohesive strength of rocks

446

(1)

11.8 Compressibility of a coalbed methane formation

446

(1)

11.9 Effect of pore pressure on stress

447

(1)

11.10 Effective stress on individual grains

447

(1)

11.11 Failure criteria (Mohr-Coulomb)

447

(1)

11.12 Formation compressibility by using hydrofrac data

448

(1)

11.13 Fracture conductivity

448

(1)

11.14 Fracture gradient (Eaton)

448

(1)

11.15 Fracture gradient (Holbrook)

449

(1)

11.16 Fracture gradient (Matthews and Kelly)

449

(1)

11.17 Fracture gradient (Zoback and Healy)

449

(1)

11.18 Fracture pressure (Hubert & Willis)

450

(1)

11.19 Fracture volume (GDK method)

450

(1)

11.20 Fracture volume (Perkins and Kern method)

451

(1)

11.21 Fracture width (GDK method)

451

(1)

11.22 Fracture width (Perkins and Kern method)

451

(1)

11.23 Hoek and Brown criteria for principal stress failure

452

(1)

11.24 Horizontal effective stress (assuming no lateral strain as per Lorenz and Teufel)

452

(1)

11.25 Horizontal maximum stress (Bredehoeft)

452

(1)

11.26 Induced fracture dip

453

(1)

11.27 Initial effective horizontal stress

453

(1)

11.28 Isothermal compressibility of limestones (Newman correlation)

454

(1)

11.29 Least principal stress as function of depth in Gulf of Mexico (Hubbert and Willis)

454

(1)

11.30 Least principal stress as function of depth in Gulf of Mexico (Matthew and Kelly)

454

(1)

11.31 Linearized Mohr failure line

455

(1)

11.32 Linearized Mohr coulomb criteria

455

(1)

11.33 M Modulus (using shear modulus and bulk modulus)

455

(1)

11.34 M Modulus (using Young's modulus and Poisson's ratio)

456

(1)

11.35 Maximum anisotropic failure stress

456

(1)

11.36 Maximum compression at vertical wellbore

456

(1)

11.37 Maximum normal stress in tangential direction at wellbore wall (hoop stress)

457

(1)

11.38 Maximum plane tangential stress acting on deviated wellbore

457

(1)

11.39 Maximum principal stress failure (Hoek and Brown)

457

(1)

11.40 Maximum principal stress in normal faulting

458

(1)

11.41 Maximum principal stress in reverse faulting

458

(1)

11.42 Maximum principal stress in strike-slip faulting

459

(1)

11.43 Maximum principal stress calculation using breakout width

459

(1)

11.44 Minimum compression at vertical wellbore

459

(1)

11.45 Minimum normal stress in tangential direction at wellbore wall (hoop stress)

460

(1)

11.46 Maximum plane tangential stress acting on deviated wellbore

460

(1)

11.47 Modified lade criterion

460

(1)

11.48 Normal stress in radial direction near wellbore

461

(1)

11.49 Normal stress in rock at failure

461

(1)

11.50 Normal stress in tangential direction at wellbore wall (hoop stress)

462

(1)

11.51 Normal stress in tangential direction near wellbore (hoop stress)

462

(1)

11.52 Pore pressure increase due to fluid activity (Mody & Hale)

463

(1)

11.53 Pore pressure increase due to given fluid activity contrast (Mody and Hale)

463

(1)

11.54 Pore pressure of shale (Flemings)

464

(1)

11.55 Pore pressure of shale (Traugott)

464

(1)

11.56 Porosity irreversible plastic deformation occurs

464

(1)

11.57 Pressure required to induce a tensile fracture (breakdown pressure)

465

(1)

11.58 Pressure to grow fractures (Abe, Mura, et al.)

465

(1)

11.59 Radial stress around vertical wellbore

466

(1)

11.60 Ratio of pore pressure change to original due to depletion

466

(1)

11.61 Rotation of maximum principal stress near wellbore

467

(1)

11.62 Rotation of maximum principal stress near wellbore (Zoback & Day-Lewis)

467

(1)

11.63 Shale compaction

467

(1)

11.64 Shear modulus

468

(1)

11.65 Shear modulus from Young's modulus

468

(1)

11.66 Shear stress near vertical well

468

(1)

11.67 Slowness of the formation

469

(1)

11.68 Storativity of fractures

469

(1)

11.69 Stress at edge of wellbore breakout

470

(1)

11.70 Stress component near normal faulting in reservoir

470

(1)

11.71 Stress components in original coordinate system in depletion drive

471

(1)

11.72 Stress intensity at tip of mode I fracture

471

(1)

11.73 Stress path (induced normal faulting)

472

(1)

11.74 Stress path of reservoir with changes in production

472

(1)

11.75 Stress perturbation (Segall and Fitzgerald)

472

(1)

11.76 Subsidence due to uniform pore pressure reduction in free surfaces

473

(1)

11.77 Unconfined compressive strength of rock

473

(1)

11.78 Velocity of bulk compressional waves

474

(1)

11.79 Velocity of compression waves

474

(1)

11.80 Velocity of shear waves

474

(1)

11.81 Vp and V5 calculation (Eberhart-Phillips)

475

(1)

11.82 Vp and Vs calculation (geomechanical model)

475

(1)

11.83 Yield strength (Bingham plastic model)

476

(2)

12 Facilities and process engineering formulas and calculations

12.1 Allowable gas velocity through gas separator

478

(1)

12.2 Allowable velocity in downcomer for tray type tower

478

(1)

12.3 Bed diameter of adsorption unit

478

(1)

12.4 Bed length of adsorption unit

479

(1)

12.5 Block efficiency factor

479

(1)

12.6 Bottom distillation column rate

479

(1)

12.7 Breakthrough time in an adsorption unit

480

(1)

12.8 Breathing loss of natural gas

480

(1)

12.9 Capacity coefficient of valves in gas processing

481

(1)

12.10 Column diameter of packed towers

481

(1)

12.11 Cooling of an ideal gas

481

(1)

12.12 Correction factor for foamless separation

482

(1)

12.13 Correlation factor for Benedict-Webb-Rubin equation

482

(1)

12.14 Critical pressure values for pressure in Van Der Waals equation

482

(1)

12.15 Downcomer velocity in tray type tower

483

(1)

12.16 Electrical heating of a pipe

483

(1)

12.17 Energy requirement of single-stage ideal compressor

484

(1)

12.18 Error in thermocouple temperature measurement

484

(1)

12.19 Eykman molecular refraction

485

(1)

12.20 Fenske's method for minimum theoretical plates

485

(1)

12.21 Gas capacity of separator

485

(1)

12.22 Gas mass velocity in an adsorption unit

486

(1)

12.23 Gas mass velocity in separator

486

(1)

12.24 Gas originally adsorbed

487

(1)

12.25 Gas pressure testing time for unsteady gas flow

487

(1)

12.26 Gravitational attraction of a layer (Bouguer correction)

487

(1)

12.27 Heating of a liquid in an agitated tank

488

(1)

12.28 Height of downcomer filling

488

(1)

12.29 Inhibitor injection rate required

489

(1)

12.30 Instrumentation noise control

489

(1)

12.31 Internal diameter of gas separator

489

(1)

12.32 lsostacy-Airy hypothesis

490

(1)

12.33 Lift coefficient

490

(1)

12.34 Mass of steel Shell in adsorption unit

491

(1)

12.35 Mass transfer zone length of adsorption unit

491

(1)

12.36 Modified Clapeyron criteria

491

(1)

12.37 Packed column actual height

492

(1)

12.38 Pan-Maddox equation for density

492

(1)

12.39 Pan-Maddox equation for molecular weight

492

(1)

12.40 Photoelectric effect

493

(1)

12.41 Power requirement for pumping a compressible flow fluid through a long pipe

493

(1)

12.42 Pressure criteria for separator by ASME (external radius)

494

(1)

12.43 Pressure criteria for separator by ASME (internal radius)

494

(1)

12.44 Pressure storage

494

(1)

12.45 Proportional band in pressure controller

495

(1)

12.46 Raoult's law in glycol dehydration unit

495

(1)

12.47 Refrigerator shaft speed

496

(1)

12.48 Relative humidity

496

(1)

12.49 Required oil length in separator

496

(1)

12.50 Required separator liquid section

497

(1)

12.51 Required water length in separator

497

(1)

12.52 Residence time of water in separator

497

(1)

12.53 Residence time oil in separator

498

(1)

12.54 Retention time in a liquid-liquid vessel

498

(1)

Cenk Temizel is a Sr. Reservoir Engineer with Saudi Aramco. Previously, he was a reservoir engineer at Aera Energy LLC (a Shell-ExxonMobil Affiliate) in Bakersfield, California, USA. He has around 15 years of experience in the industry working on reservoir simulation, smart fields, heavy oil, optimization, geomechanics, integrated asset modeling, unconventionals, field development and enhanced oil recovery with Schlumberger and Halliburton in the Middle East, the US and the UK. He was a teaching/research assistant at the University of Southern California and Stanford University before joining the industry. He serves as a technical reviewer for petroleum engineering journals. He has published around 100 publications in the area of reservoir management, production optimization, enhanced oil recovery processes, data driven methods, machine learning and smart fields along with US patents. He holds a BS degree (Honors) from Middle East Technical University Ankara (2003) and an MS degree (2005) from University of Southern California (USC), Los Angeles, CA both in petroleum engineering. Tayfun Tuna is a data scientist and software developer who holds a MS and a PhD Degree in Computer Science from the University of Houston. His graduate research focus was on text mining; applying machine learning techniques to lecture videos in order to segment video content for a better learning experience. He is a co-founder of Videopoints LLC, previously known as ICS Video Project, an interactive educational video platform which have been used more than 50K users across multiple university campuses. While he was the chief operating officer and principal investigator his project is rewarded by National Science Foundation Small Business Innovation Research (NSF SBIR) Phase I Grant.

In his professional career, Tayfun has worked with Halliburton to develop a patented machine learning based web based interface that predicts chance of getting of stuck while drilling for oil. Tayfun Tuna has two patents and 20 research paper publications on educational technology, social networks and oil&gas field. M. Melih Oskay earned his PhD from UT Austin, and he has been in academia and industry as advisors and managerial positions for more than 30 years at Kuwait Oil Company, Shell and Kuwait Gulf Oil Company.

He has represented KOC and KGOC at Joint Operations Committee and Joint Operations Tender Committees. Getty, Texaco, and Chevron have been the Operator for Saudi Arabia at Wafra Joint Operations at various periods. Dr. Oskay has also worked closely with Total experts during Total - KGOC Technical Support Agreement period.

He has taught at University of Texas - Austin, TX, Louisiana Tech University-Ruston, Louisiana, Middle East Technical University Ankara, Turkiye and King Fahd University of Petroleum and Minerals, Dhahran, Saudi Arabia.

Dr. Oskay has hold Organizing Committee, Session Chairmanship positions at many SPE Oil Show and Technical Conferences. Luigi Saputelli is a Reservoir Engineering Expert Advisor to the Abu Dhabi National Oil Company (ADNOC) and Frontender with over 29 years of experience. He has held various positions as reservoir engineer (integrated reservoir modeling, simulation, improved oil recovery projects, field development, researcher), drilling engineer (drilling and well planning projects, drilling rig automation) and production engineer (production modeling, engineering and operations workflow automation projects), in various operators and services companies around the world including PDVSA, Hess and Halliburton. Saputelli is an industry recognized researcher, invited lecturer, and an SPE liaison and committee member. Saputelli serves on the Society of Petroleum Engineers (SPE) JPT Editorial Committee as the data communication and management technology feature editor since 2012, on the SPE Production and Operations Advisory Board since 2010. He is a founding member of the SPE Real-time Optimization Technical Interest Group and the Petroleum Data-driven Analytics technical section. He is the recipient of the 2015 SPE International Production and Operations Award. He has published more than 90 industry papers on applied technologies related to digital oilfield, reservoir management, real-time optimization, and production operations. Saputelli holds a BSc in Electronic Engineer from Universidad Simon Bolivar (1990), with a MSc in Petroleum Engineering from Imperial College (1996), and a PhD in chemical engineering from University of Houston (2003). He is also serving as managing partner in Frontender, a petroleum engineering services firm based in Houston.

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