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Well Performance Calculators

Use 144 well performance petroleum engineering calculators with formulas, inputs, outputs, units, and source references.

Well performance calculations support tubing and nodal checks, artificial lift, separator sizing, perforation diagnostics, completion-fluid planning, and production-system constraints.

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Production EngineeringWell Performance

Additional Pressure Drop in the Skin Zone

ΔPskin=141.2QoBoμoSkh\Delta P_{skin} = \frac{141.2 Q_o B_o \mu_o S}{k h}
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Production EngineeringWell Performance

Adsorption Unit Bed Length from Mass Transfer Zone

hb=0.45hzxsxs−xh_b=\frac{0.45h_zx_s}{x_s-x}
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Production EngineeringWell Performance

Adsorption Unit Mass Transfer Zone Length

hz=375q0.7895vg0.5506RS0.2646h_z=\frac{375q^{0.7895}}{v_g^{0.5506}RS^{0.2646}}
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Production EngineeringWell Performance

API RP 14E Actual Mixture Velocity

Vm=4qvπ(Di/12)2V_m=\frac{4q_v}{\pi(D_i/12)^2}
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Production EngineeringWell Performance

API RP 14E Erosional Velocity

Ve=CρmV_e=\frac{C}{\sqrt{\rho_m}}
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Production EngineeringWell Performance

API RP 14E Erosional Velocity Utilization

Ue=VmVeU_e=\frac{V_m}{V_e}
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Production EngineeringWell Performance

API RP 14E Gas-Liquid Mixture Density

ρm=12409SLP+2.7RSgP198.7P+RTZ\rho_m=\frac{12409S_LP+2.7RS_gP}{198.7P+RTZ}
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Production EngineeringWell Performance

API RP 14E Minimum Flow Area per 1000 Barrels Liquid

A1000=9.35+RTZ21.25PVeA_{1000}=\frac{9.35+\frac{RTZ}{21.25P}}{V_e}
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Production EngineeringWell Performance

API RP 14E Minimum Velocity Ratio

Rmin=VmVminR_{min}=\frac{V_m}{V_{min}}
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Production EngineeringWell Performance

API RP 14E Required Pipe Inside Diameter

Dmin=4A1000qL1000πD_{min}=\sqrt{\frac{4A_{1000}q_L}{1000\pi}}
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Production EngineeringWell Performance

API RP 14E Total Wellstream Weight Flow Rate

W=3180QgSg+14.6qLSLW=3180Q_gS_g+14.6q_LS_L
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Production EngineeringWell Performance

API RP 14E Two-Phase Flowline Pressure Drop

ΔP100=0.000336fW2Di5ρm\Delta P_{100}=\frac{0.000336fW^2}{D_i^5\rho_m}
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Production EngineeringWell Performance

Approximate Ideal Counterbalanced Load

AICB=PPRL+MPRL2AICB=\frac{PPRL+MPRL}{2}
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Production EngineeringWell Performance

ASME Separator Pressure Criterion - External Radius

P=SEtRo−0.4tP=\frac{SEt}{R_o-0.4t}
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Production EngineeringWell Performance

ASME Separator Pressure Criterion - Internal Radius

P=SEtRi+0.6tP=\frac{SEt}{R_i+0.6t}
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Production EngineeringWell Performance

ASME Separator Wall Thickness from External Radius

t=PRoSE+0.4Pt=\frac{PR_o}{SE+0.4P}
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Production EngineeringWell Performance

ASME Separator Wall Thickness from Internal Radius

t=PRiSE−0.6Pt=\frac{PR_i}{SE-0.6P}
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Production EngineeringWell Performance

ASME Spherical Separator Shell Thickness

t=PR2SE−0.2Pt=\frac{PR}{2SE-0.2P}
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Production EngineeringWell Performance

Average Downstroke Load - Sucker Rod Pump

ADL=CAlowerLADL=C\frac{A_{lower}}{L}
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Production EngineeringWell Performance

Average Liquid Specific Gravity for Mixed Liquid Stream

SL=qoSo+qwSwqo+qwS_L=\frac{q_oS_o+q_wS_w}{q_o+q_w}
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Production EngineeringWell Performance

Average Upstroke Load - Sucker Rod Pump

AUL=CAupper+AlowerLAUL=C\frac{A_{upper}+A_{lower}}{L}
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Reservoir EngineeringWell Performance

Bournazel Jeanson Vertical Well Water Breakthrough Dimensionless Time

td=(ρw−ρo)gkvtBTfmμoϕeht_d=\frac{(\rho_w-\rho_o)gk_vt_{BT}f_m}{\mu_o\phi_eh}
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Production EngineeringWell Performance

CaCl2 and CaBr2 Salt Addition for Two-Salt Brine

m95=V8.33C95Wim_{95}=\frac{V_{8.33}C_{95}}{W_i}
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Production EngineeringWell Performance

Choke Discharge Coefficient

Cd=dcd+0.3167(dc/d)0.6+0.025(log⁡10NR−4)C_d=\frac{d_c}{d}+\frac{0.3167}{(d_c/d)^{0.6}}+0.025\left(\log_{10}N_R-4\right)
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Production EngineeringWell Performance

Choke Outlet Temperature

Tdn=Tuzuzo(PoPu)(k−1)/kT_{dn}=T_u\frac{z_u}{z_o}\left(\frac{P_o}{P_u}\right)^{(k-1)/k}
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Production EngineeringWell Performance

Close-Ended Displacement Volume of Pipe

Vc=0.7854Do2L808.5V_c=\frac{0.7854D_o^2L}{808.5}
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Production EngineeringWell Performance

Correct Counterbalance - Sucker Rod Pump

CCB=AUL+ADL2CCB=\frac{AUL+ADL}{2}
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Reservoir EngineeringWell Performance

Craft and Hawkins Vertical Well Critical Coning Rate

qo=0.007078koh(pws−pwf)μoBoln⁡(re/rw)PRq_o=\frac{0.007078k_oh(p_{ws}-p_{wf})}{\mu_oB_o\ln(r_e/r_w)}PR
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Reservoir EngineeringWell Performance

Critical Rate for Horizontal Wells in Edge-Water Drive Reservoirs

qo=(4.888×10−4)⋅Δρ⋅h⋅kh⋅kv⋅L⋅qcμoq_o = (4.888 \times 10^{-4}) \cdot \Delta\rho \cdot h \cdot \sqrt{k_h \cdot k_v} \cdot L \cdot \frac{q_c}{\mu_o}
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Production EngineeringWell Performance

Darcy-Weisbach Tubing Friction Pressure Drop

ΔPf=fDρLv22gcD⋅144\Delta P_f=\frac{f_D\rho Lv^2}{2g_cD\cdot144}
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Reservoir EngineeringWell Performance

Deliverability Equation for Shallow Gas Reservoirs

C=k⋅h1422⋅T⋅μg⋅z⋅(ln⁡(rerw)−0.5)C = \frac{k \cdot h}{1422 \cdot T \cdot \mu_g \cdot z \cdot \left(\ln\left(\frac{r_e}{r_w}\right) - 0.5\right)}
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Production EngineeringWell Performance

Density of Brine (Completion and Workover Fluids)

ρs=ρm[1+Cte(Tm−Ts)]\rho_s=\rho_m\left[1+C_{te}(T_m-T_s)\right]
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Reservoir EngineeringWell Performance

Dimensionless Fracture Conductivity

FCD=kfwfkXfF_{CD}=\frac{k_fw_f}{kX_f}
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Production EngineeringWell Performance

Effective Wellbore Radius from Skin Factor

rwa=rwe−sr_{wa} = r_w e^{-s}
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Reservoir EngineeringWell Performance

Effective Wellbore Radius of a Horizontal Well – Method 1 (Anisotropic Reservoirs)

rwd=reh⋅L2a⋅(1+1−(L2a)2)⋅(βh2rw)βhLr_{wd} = \frac{r_{eh} \cdot \frac{L}{2}}{a \cdot \left(1 + \sqrt{1 - \left(\frac{L}{2a}\right)^2}\right) \cdot \left(\frac{\beta h}{2r_w}\right)^{\frac{\beta h}{L}}}
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Reservoir EngineeringWell Performance

Effective Wellbore Radius of a Horizontal Well – van der Vlis et al. Method

rwe=L4⋅(0.454⋅sin⁡(360⋅rwh))hLr_{we} = \frac{L}{4} \cdot \left( 0.454 \cdot \sin\left(360 \cdot \frac{r_w}{h} \right) \right)^{\frac{h}{L}}
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Reservoir EngineeringWell Performance

Effective Wellbore Radius of a Well in Presence of Uniform Flux Fractures

rw=Xfer_w = \frac{X_f}{e}
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Reservoir EngineeringWell Performance

Efros Horizontal Well Critical Rate

qo=4.888×10−4khh2(ρw−ρo)LBoμoGEq_o=4.888\times10^{-4}\frac{k_hh^2(\rho_w-\rho_o)L}{B_o\mu_oG_E}
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Production EngineeringWell Performance

Entrance Hole Size from Casing Yield Strength

d=(σyrσy)0.5drd=\left(\frac{\sigma_{yr}}{\sigma_y}\right)^{0.5}d_r
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Production EngineeringWell Performance

ESP BEP Operating Ratio

RBEP=QdesignQBEPR_{BEP}=\frac{Q_{design}}{Q_{BEP}}
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Production EngineeringWell Performance

ESP Brake Horsepower from TDH and Efficiency

BHP=QgpmTDHSGf3960ηpBHP=\frac{Q_{gpm}TDHSG_f}{3960\eta_p}
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Production EngineeringWell Performance

ESP Brake Horsepower Speed Correction

BHP2=BHP1(N2N1)3BHP_2=BHP_1\left(\frac{N_2}{N_1}\right)^3
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Production EngineeringWell Performance

ESP Flow Rate Speed Correction

Q2=Q1N2N1Q_2=Q_1\frac{N_2}{N_1}
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Production EngineeringWell Performance

ESP Head Speed Correction

H2=H1(N2N1)2H_2=H_1\left(\frac{N_2}{N_1}\right)^2
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Production EngineeringWell Performance

ESP Net Lift from Pump Intake Pressure

Hlift=Dpump−Pintake0.433SGfH_{lift}=D_{pump}-\frac{P_{intake}}{0.433SG_f}
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Production EngineeringWell Performance

ESP Stages Required with Safety Margin

Nstages=⌈TDHHstageSF⌉N_{stages}=\left\lceil\frac{TDH}{H_{stage}}SF\right\rceil
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Production EngineeringWell Performance

ESP Total Brake Horsepower from Stage Curve

BHPtotal=NstagesBHPstageBHP_{total}=N_{stages}BHP_{stage}
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Production EngineeringWell Performance

ESP Total Dynamic Head from Components

TDH=Hlift+Hfriction+HwhpTDH=H_{lift}+H_{friction}+H_{whp}
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Production EngineeringWell Performance

ESP Total Pump Head from Stages

Htotal=NstagesHstageH_{total}=N_{stages}H_{stage}
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Production EngineeringWell Performance

ESP Wellhead Pressure Head

Hwhp=Pwhp0.433SGfH_{whp}=\frac{P_{whp}}{0.433SG_f}
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Reservoir EngineeringWell Performance

Finite-Conductivity Fracture Effective Wellbore Radius

rwe=0.2807kfbfkr_{we}=\frac{0.2807k_fb_f}{k}
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Production EngineeringWell Performance

Flow Efficiency with Skin Pressure Drop

E=p−pwf−141.2qBμskhp−pwfE = \frac{p-p_{wf}-\frac{141.2qB\mu s}{kh}}{p-p_{wf}}
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Production EngineeringWell Performance

Foamless Separator Length-Diameter Correction Factor

K=(L/D5)0.56K=\left(\frac{L/D}{5}\right)^{0.56}
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Production EngineeringWell Performance

Fuel Gas Wobbe Index

W=GHVγgW=\frac{GHV}{\sqrt{\gamma_g}}
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Production EngineeringWell Performance

Gas Conditioning Relative Humidity

RH=PwPsatRH=\frac{P_w}{P_{sat}}
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Production EngineeringWell Performance

Gas Conditioning Stripping Factor

S=KVLS=\frac{KV}{L}
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Reservoir EngineeringWell Performance

Gas Flow Rate into the Wellbore

Q=0.007kΔPLuln⁡(Re/Rw)1440Q=\frac{0.007k\Delta PL}{u\ln(R_e/R_w)1440}
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Production EngineeringWell Performance

Gas Mass Velocity in an Adsorption Unit

w=162vgγgPTzw=\frac{162v_g\gamma_gP}{Tz}
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Production EngineeringWell Performance

Gas Mass Velocity in Separator

mg=0.785wd2Fgm_g=0.785wd^2F_g
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Production EngineeringWell Performance

Gas Pressure Testing Time for Unsteady Gas Flow

tm=3d2LPt_m=\frac{3d^2L}{P}
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Production EngineeringWell Performance

Gas Separator Internal Diameter from Mass Flow

d=0.0188(mg/(FgKs))0.5((ρl−ρg)/ρg)0.25d=\frac{0.0188\left(m_g/(F_gK_s)\right)^{0.5}}{\left((\rho_l-\rho_g)/\rho_g\right)^{0.25}}
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Production EngineeringWell Performance

Gas-Lift Valve Opening Casing Pressure

P1=Pbt−P2(Ap/Ab)1−(Ap/Ab)P_1=\frac{P_{bt}-P_2\left(A_p/A_b\right)}{1-\left(A_p/A_b\right)}
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Production EngineeringWell Performance

Gas-Liquid Ratio from Gas and Liquid Rates

R=1000000QgqLR=\frac{1000000Q_g}{q_L}
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Reservoir EngineeringWell Performance

Generalized Reservoir Gas Flow Deliverability

W=C(pˉ2−pwf2)nW=C(\bar p^2-p_{wf}^2)^n
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Reservoir EngineeringWell Performance

Giger-Karcher Horizontal Well Critical Rate

qc=khh2gΔρBμL[1−16(hL)2]q_c=\frac{k_hh^2g\Delta\rho}{B\mu L}\left[1-\frac{1}{6}\left(\frac{h}{L}\right)^2\right]
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Production EngineeringWell Performance

Gilbert Critical Choke Liquid Rate

qL=PwhD641.89435GLR0.546q_L=\frac{P_{wh}D_{64}^{1.89}}{435GLR^{0.546}}
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Production EngineeringWell Performance

Glycol Dehydration Still Column Diameter

d=9.1qgd=9.1\sqrt{q_g}
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Reservoir EngineeringWell Performance

High-Pressure Region Gas Flow Rate

Qg=7.08×10−6kh(Pr−Pwf)μgavgBgavg[ln⁡(re/rw)−0.75+S]Q_g=\frac{7.08\times10^{-6}kh(P_r-P_{wf})}{\mu_{gavg}B_{gavg}[\ln(r_e/r_w)-0.75+S]}
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Production EngineeringWell Performance

Horizontal Separator Length for Liquid Retention

Lreq=4(5.615)VreqπFLD2L_{req}=\frac{4(5.615)V_{req}}{\pi F_LD^2}
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Production EngineeringWell Performance

Horizontal Separator Liquid Volume from Geometry

VL=FLπD2L4(5.615)V_L=\frac{F_L\pi D^2L}{4(5.615)}
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Production EngineeringWell Performance

Horizontal Separator Maximum Vapor Velocity from Droplet Settling

Vh,max=LSETVtHSETV_{h,max}=\frac{L_{SET}V_t}{H_{SET}}
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Reservoir EngineeringWell Performance

Horizontal Well Breakthrough Dimensionless Flow Rate

qd=325.86μoqoBokvkhh(ρo−ρg)q_d=\frac{325.86\mu_oq_oB_o}{\sqrt{k_vk_h}h(\rho_o-\rho_g)}
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Reservoir EngineeringWell Performance

Horizontal Well Breakthrough Dimensionless Time

tdbt=kv(ρo−ρg)tbt364.72hϕμot_{dbt}=\frac{k_v(\rho_o-\rho_g)t_{bt}}{364.72h\phi\mu_o}
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Reservoir EngineeringWell Performance

Hoyland Papatzacos Skjaeveland Isotropic Vertical Well Critical Rate

Qoc=(ρw−ρo)koBoμo10822[1−(hph)2]1.325h2.238(ln⁡re)−1.99Q_{oc}=\frac{(\rho_w-\rho_o)k_o}{B_o\mu_o10822}\left[1-\left(\frac{h_p}{h}\right)^2\right]^{1.325}h^{2.238}(\ln r_e)^{-1.99}
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Production EngineeringWell Performance

Incremental Density in Wellbore Interval - Completion and Workover Fluids

Δρi=BgpΔD−AgTΔD\Delta\rho_i=B g_p\Delta D-A g_T\Delta D
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Production EngineeringWell Performance

Intermediate Law Droplet Settling Velocity

Vt=2.94g0.71Dp1.14(ρp−ρc)0.71ρc0.29μc0.43V_t=\frac{2.94g^{0.71}D_p^{1.14}(\rho_p-\rho_c)^{0.71}}{\rho_c^{0.29}\mu_c^{0.43}}
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Reservoir EngineeringWell Performance

Joshi Horizontal Well Critical Rate for Gas Coning

qo=1.535×10−3(ρo−ρg)kh[h2−(h−lv)2]Boμoln⁡(re/rw)q_o=1.535\times10^{-3}\frac{(\rho_o-\rho_g)k_h[h^2-(h-l_v)^2]}{B_o\mu_o\ln(r_e/r_w)}
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Reservoir EngineeringWell Performance

Joshi Horizontal Well Drainage Ellipse Area

Aac=πrehrev43560A_{ac}=\frac{\pi r_{eh}r_{ev}}{43560}
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Reservoir EngineeringWell Performance

Joshi Horizontal Well Productivity Index

Jh=0.00708khhμoBo[ln⁡Rh+βhLln⁡(βh2rw)+s]J_h=\frac{0.00708k_hh}{\mu_oB_o\left[\ln R_h+\frac{\beta h}{L}\ln\left(\frac{\beta h}{2r_w}\right)+s\right]}
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Reservoir EngineeringWell Performance

Joshi Isotropic Horizontal Well Effective Radius

rwd=rehL/2a(1+1−(L2a)2)(h2rw)h/Lr_{wd}=r_{eh}\frac{L/2}{a\left(1+\sqrt{1-\left(\frac{L}{2a}\right)^2}\right)\left(\frac{h}{2r_w}\right)^{h/L}}
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Reservoir EngineeringWell Performance

Laminar Gas Flow Rate from Real-Gas Pseudopressure

Qg=kh(φr−φwf)1422T[0.5ln⁡(4A/(1.781CArw2))+S]Q_g=\frac{kh(\varphi_r-\varphi_{wf})}{1422T[0.5\ln(4A/(1.781C_Ar_w^2))+S]}
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Production EngineeringWell Performance

Liquid-Liquid Vessel Retention Time

Tr=Aμγb−γtT_r=\frac{A\mu}{\gamma_b-\gamma_t}
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Reservoir EngineeringWell Performance

Low-Pressure Non-Circular Gas Flow Rate

Qg=kh(Pr2−Pwf2)1422μgavgTZavg[0.5ln⁡(4A/(1.781CArw2))+S]Q_g=\frac{kh(P_r^2-P_{wf}^2)}{1422\mu_{gavg}TZ_{avg}[0.5\ln(4A/(1.781C_Ar_w^2))+S]}
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Reservoir EngineeringWell Performance

Meyer Gardner Pirson Vertical Gas-Coning Critical Rate

qo=0.001535ρo−ρgln⁡(re/rw)koμoBo[h2−(h−hp)2]q_o=0.001535\frac{\rho_o-\rho_g}{\ln(r_e/r_w)}\frac{k_o}{\mu_oB_o}\left[h^2-(h-h_p)^2\right]
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Reservoir EngineeringWell Performance

Meyer Gardner Pirson Vertical Well Critical Coning Rate

qo=0.001535ρw−ρoln⁡(re/rw)koμoBo(h2−hp2)q_o=0.001535\frac{\rho_w-\rho_o}{\ln(r_e/r_w)}\frac{k_o}{\mu_oB_o}(h^2-h_p^2)
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Production EngineeringWell Performance

Minimum Polished Rod Load - Sucker Rod Pump

MPRL=CdMPRL=Cd
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Production EngineeringWell Performance

Multiphase Wellhead Pressure Across Choke

Pwh=CRmqLSnP_{wh}=C R^m\frac{q_L}{S^n}
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Production EngineeringWell Performance

Newton Law Droplet Settling Velocity

Vt=1.74gDp(ρp−ρc)ρcV_t=1.74\sqrt{\frac{gD_p(\rho_p-\rho_c)}{\rho_c}}
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Production EngineeringWell Performance

Oil-Well Perforation Pressure Drop

Δpp=A(qoN)+B(qoN)2\Delta p_p=A\left(\frac{q_o}{N}\right)+B\left(\frac{q_o}{N}\right)^2
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Production EngineeringWell Performance

Packed Column Actual Height

h=HTU NTUh=HTU\,NTU
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Production EngineeringWell Performance

Peak Polished Rod Load - Sucker Rod Pump

PPRL=CDPPRL=CD
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Production EngineeringWell Performance

Perforation Friction Pressure

ΔPpf=22.335Q2ρn2C2Dp4\Delta P_{pf}=22.335\frac{Q^2\rho}{n^2C^2D_p^4}
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Production EngineeringWell Performance

Perforation Hole Size from Brinell Hardness

d=(2250+4.2xr2250+4.2x)0.5drd=\left(\frac{2250+4.2x_r}{2250+4.2x}\right)^{0.5}d_r
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Production EngineeringWell Performance

Perforation Length in Formation

Lp=Lpc−0.5(dwb−dci)L_p=L_{pc}-0.5\left(d_{wb}-d_{ci}\right)
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Production EngineeringWell Performance

Perforation Skin Factor

sp=sH+sv+swb+spds_p=s_H+s_v+s_{wb}+s_{pd}
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Production EngineeringWell Performance

Pipe Volume Capacity

V=0.7854Di2L808.5V=\frac{0.7854D_i^2L}{808.5}
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Production EngineeringWell Performance

Polished Rod Horsepower - Sucker Rod Pump

PRHP=CSNA33000⋅12LPRHP=\frac{CSNA}{33000\cdot12L}
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Reservoir EngineeringWell Performance

Prats High-Conductivity Fracture Effective Wellbore Radius

rwe=Xf2r_{we}=\frac{X_f}{2}
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Production EngineeringWell Performance

Pressure Drop Across Perforations in Gas Wells

psf=pwb2+A(qgn)+B(qgn)2p_{sf}=\sqrt{p_{wb}^2+A\left(\frac{q_g}{n}\right)+B\left(\frac{q_g}{n}\right)^2}
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Production EngineeringWell Performance

Productivity Ratio

PR=JJswPR = \frac{J}{J_{sw}}
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Production EngineeringWell Performance

Progressive Cavity Pump Flow Rate

Qe=7.12DEPsN−QsQ_e=7.12DEP_sN-Q_s
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Production EngineeringWell Performance

Progressive Cavity Pump Head Rating

ΔP=(2np−1)Δp\Delta P=(2n_p-1)\Delta p
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Production EngineeringWell Performance

Progressive Cavity Pump Mechanical Resistant Torque

Tm=144VoΔPepT_m=\frac{144V_o\Delta P}{e_p}
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Production EngineeringWell Performance

Pseudo-Skin Factor Due to Partial Penetration - Papatzacos Correlation

sp=1−bbln⁡(πhd2)+1bln⁡[bb+2Ap−1Bp−1]s_p=\frac{1-b}{b}\ln\left(\frac{\pi h_d}{2}\right)+\frac{1}{b}\ln\left[\frac{b}{b+2}\sqrt{\frac{A_p-1}{B_p-1}}\right]
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Reservoir EngineeringWell Performance

Pseudo-Steady State Horizontal Well Productivity Method 3

Jh=khh70.6μo(F+h0.5Lkhkvsx)J_h=\frac{k_hh}{70.6\mu_o\left(F+\frac{h}{0.5L}\sqrt{\frac{k_h}{k_v}}s_x\right)}
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Production EngineeringWell Performance

Range of Load - Sucker Rod Pump

ROL=PPRL−MPRLROL=PPRL-MPRL
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Production EngineeringWell Performance

Raoult's Law Water Fraction in Glycol Dehydration

xw=PPvywx_w=\frac{P}{P_v}y_w
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Production EngineeringWell Performance

Recommended Underbalanced Perforation Pressure

pu=103.46055−0.3812log⁡10kp_u = 10^{3.46055 - 0.3812\log_{10}k}
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Production EngineeringWell Performance

Refrigeration Outlet Temperature for Gas Conditioning

To=Ti+Ti[(PoPi)m−1]ET_o=T_i+T_i\left[\left(\frac{P_o}{P_i}\right)^m-1\right]E
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Production EngineeringWell Performance

Required Oil Section Length in Separator

Lo=toqoAoL_o=\frac{t_oq_o}{A_o}
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Production EngineeringWell Performance

Required Water Section Length in Separator

Lw=twqwAwL_w=\frac{t_wq_w}{A_w}
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Production EngineeringWell Performance

Safety Relief Valve Vapor Flow Capacity

w=BCKoAP(MZT)0.5w=BCK_oAP\left(\frac{M}{ZT}\right)^{0.5}
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Production EngineeringWell Performance

Separator Actual Gas Velocity

VG=4qaπFGD2V_G=\frac{4q_a}{\pi F_GD^2}
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Production EngineeringWell Performance

Separator Droplet Reynolds Number

Rep=1000DpVtρcμcRe_p=\frac{1000D_pV_t\rho_c}{\mu_c}
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Production EngineeringWell Performance

Separator Gas Capacity at Standard Conditions

qs=67824Ksd2Fg1zPPsTsT(ρl−ρgρg)0.5q_s=67824K_sd^2F_g\frac{1}{z}\frac{P}{P_s}\frac{T_s}{T}\left(\frac{\rho_l-\rho_g}{\rho_g}\right)^{0.5}
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Production EngineeringWell Performance

Separator Gas Capacity from Diameter

qa,max=VGmaxFGπD24q_{a,max}=V_{Gmax}F_G\frac{\pi D^2}{4}
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Production EngineeringWell Performance

Separator Gas Capacity Utilization

UG=VGVGmaxU_G=\frac{V_G}{V_{Gmax}}
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Production EngineeringWell Performance

Separator Liquid Retention Utilization

UL=VreqVavailableU_L=\frac{V_{req}}{V_{available}}
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Production EngineeringWell Performance

Separator Minimum Diameter from Gas Capacity

Dmin=4qaπFGVGmaxD_{min}=\sqrt{\frac{4q_a}{\pi F_GV_{Gmax}}}
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Production EngineeringWell Performance

Separator Required Liquid Retention Volume

Vreq=WLtret1440V_{req}=\frac{W_Lt_{ret}}{1440}
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Production EngineeringWell Performance

Shape Factor Expressed as Skin Factor for Vertical Wells

sCA=ln⁡[(31.62CA)0.5]s_{CA}=\ln\left[\left(\frac{31.62}{C_A}\right)^{0.5}\right]
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Production EngineeringWell Performance

Single-Phase Gas Flow Subsonic

qsc=1248CdAPuk(k−1)γgTu[(PdPu)2/k−(PdPu)(k+1)/k]q_{sc}=1248C_dAP_u\sqrt{\frac{k}{(k-1)\gamma_gT_u}\left[\left(\frac{P_d}{P_u}\right)^{2/k}-\left(\frac{P_d}{P_u}\right)^{(k+1)/k}\right]}
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Production EngineeringWell Performance

Single-Phase Liquid Flow Through Choke

q=CdA2gcΔPρq=C_dA\sqrt{\frac{2g_c\Delta P}{\rho}}
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Production EngineeringWell Performance

Single-Salt Brine Density Increase Salt Addition Method II

ms=CsfVf−CsiVim_s=C_{sf}V_f-C_{si}V_i
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Skin Factor Due to Reduced Crushed-Zone Permeability

sc=(kkdp−kkd)12hpNLpln⁡(rdprp)s_c=\left(\frac{k}{k_{dp}}-\frac{k}{k_d}\right)12\frac{h_p}{NL_p}\ln\left(\frac{r_{dp}}{r_p}\right)
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Production EngineeringWell Performance

Skin Factor for a Deviated Well

sθ=−(θw41)2.06−(θw56)1.865log⁡10(hd100)s_\theta=-\left(\frac{\theta_w}{41}\right)^{2.06}-\left(\frac{\theta_w}{56}\right)^{1.865}\log_{10}\left(\frac{h_d}{100}\right)
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Skin Factor from Damaged Zone Permeability

s=(kks−1)ln⁡(rsrw)s = \left(\frac{k}{k_s} - 1\right)\ln\left(\frac{r_s}{r_w}\right)
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Reservoir EngineeringWell Performance

Sobocinski Cornelius Vertical Well Breakthrough Dimensionless Time

tD=0.00137(ρw−ρo)kh(1+Mα)tμoϕh(kh/kv)t_D=\frac{0.00137(\rho_w-\rho_o)k_h(1+M^\alpha)t}{\mu_o\phi h(k_h/k_v)}
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Reservoir EngineeringWell Performance

Sobocinski Cornelius Vertical Well Cone Height Ratio

Z=0.00307(ρw−ρo)khhhtμoqoBoZ=\frac{0.00307(\rho_w-\rho_o)k_hhh_t}{\mu_oq_oB_o}
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Production EngineeringWell Performance

Souders-Brown Maximum Gas Velocity for Separator

VGmax=KSρL−ρGρGV_{Gmax}=K_S\sqrt{\frac{\rho_L-\rho_G}{\rho_G}}
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Stokes Law Droplet Settling Velocity

Vt=1000gDp2(ρp−ρc)18μcV_t=\frac{1000gD_p^2(\rho_p-\rho_c)}{18\mu_c}
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Stokes Region Maximum Droplet Diameter

Dp,max=KCR[μc2gρc(ρp−ρc)]1/3D_{p,max}=K_{CR}\left[\frac{\mu_c^2}{g\rho_c(\rho_p-\rho_c)}\right]^{1/3}
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Suspension Property of Static Fluids (Completion and Workover Fluids)

v=d2(ρp−ρf)gμ(4.5×106)v=\frac{d^2(\rho_p-\rho_f)g}{\mu(4.5\times10^6)}
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Production EngineeringWell Performance

TEG Weight Percent in Glycol Dehydration Unit

wtTEG=100mTEGmTEG+wabs+wleanwt_{TEG}=\frac{100m_{TEG}}{m_{TEG}+w_{abs}+w_{lean}}
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Production EngineeringWell Performance

Three-Phase Separator Liquid Retention Volume

Vreq=Woto+Wwtw1440V_{req}=\frac{W_ot_o+W_wt_w}{1440}
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Production EngineeringWell Performance

Total Skin in Partially Depleted Wells for a Buildup Test

S=34.7rewϕμctk[ps−pwm+1Δt]−1S=34.7r_{ew}\sqrt{\frac{\phi\mu c_t}{k}}\left[\frac{p_s-p_w}{m}+\frac{1}{\sqrt{\Delta t}}\right]-1
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Tubing Bottomhole Pressure from Wellhead Pressure and Losses

Pwf=Pwh+ΔPh+ΔPf+ΔPaccP_{wf}=P_{wh}+\Delta P_h+\Delta P_f+\Delta P_{acc}
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Turner Critical Gas Rate for Liquid Loading

qgc=3.067PvgcATRzq_{gc}=3.067\frac{Pv_{gc}A}{T_Rz}
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Production EngineeringWell Performance

Velocity of Fluid in Pipe

vp=Q2.448Di2v_p=\frac{Q}{2.448D_i^2}
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Production EngineeringWell Performance

Water Volume to Dilute Brine in Two-Salt Systems

V8.33=Vdρi−ρdρi−ρ8.33V_{8.33}=V_d\frac{\rho_i-\rho_d}{\rho_i-\rho_{8.33}}
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Production EngineeringWell Performance

Well Flowing Pressure Line-Source Solution by Including Skin Factor

Pwf=Pi+70.6qμBkh[ln⁡(1688ϕμctr2kt)−2S]P_{wf}=P_i+\frac{70.6q\mu B}{kh}\left[\ln\left(\frac{1688\phi\mu c_tr^2}{kt}\right)-2S\right]
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Production EngineeringWell Performance

Wellbore Storage Due to Fluid Level

CFL=144Aa5.615ρC_{FL}=\frac{144A_a}{5.615\rho}
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Production EngineeringWell Performance

Wellstream Volumetric Flow Rate from Weight Flow

qv=W3600ρmq_v=\frac{W}{3600\rho_m}
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Workover Operations Maximum Allowed Tubing Pressure

MATP=FGH−PtMATP=FGH-P_t
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