Difference between revisions of "Category: FracDesign"

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:<math>M</math> = mass, kg
 
:<math>M</math> = mass, kg
 
:<math>V</math> = volume, m<sup>3</sup>
 
:<math>V</math> = volume, m<sup>3</sup>
 +
:<math>t_e</math> = total pumping time, sec
  
 
optiFrac
 
optiFrac

Revision as of 11:23, 10 October 2018

Brief

pengtools fracDesign

fracDesign is a tool for designing a hydraulic fracture treatment in pengtools.

For the given set of reservoir, fluid and proppant properties fracDesign calculates the pumping schedule which will create the optimal fracture geometry to achieve maximum well’s productivity.

fracDesignis available online at www.pengtools.com.

Main features

  • PKN and KGD fracture geometry models
  • optiFrac workflow on fracture geometry optimization
  • Slurry concentration versus time pumping schedule as plot and table
  • Fracture length and width profiles vs time plots
  • Net pressure profiles vs time as plot and table
  • Practical pumping constrains and Fracture tuning options
  • Detailed output table with calculated fracture design parameters
  • Sensitivity option with benchmark to potential
  • Simulation mode: calculating the fracture geometry from the given pumping schedule

Interface features

  • "Default values" button resets input values to the default values.
  • Switch between Metric and Field units.
  • Save/load models to the files and to the user’s cloud.
  • Export pdf report containing input parameters, calculated values and the chart.
  • Share models to the public cloud or by using model’s link.
  • Continue your work from where you stopped: last saved model will be automatically opened.
  • Download the chart as an image or data and print (upper-right corner chart’s button).

Math & Physics

w_{f,hydr,max,PKN}=9.15^{\frac{1}{(2 + 2 n)}}\ 3.98^{\frac{n}{(2 + 2 n)}}\ \left ( \frac{1+2.14n}{n}\right )^{\frac{n}{(2 + 2 n)}}\ K^{\frac{1}{(2 + 2 n)}}\ \left ( \frac{q_i^n h_f^{1-n} x_f}{E'} \right )^{\frac{1}{(2 + 2 n)}} - hydraulic maximum fracture width PKN (ref[1] eq 9.53)
w_{f,hydr,max,KGD}=11.1^{\frac{1}{(2 + 2 n)}}\ 3.24^{\frac{n}{(2 + 2 n)}}\ \left ( \frac{1+2n}{n}\right )^{\frac{n}{(2 + 2 n)}}\ K^{\frac{1}{(2 + 2 n)}}\ \left ( \frac{q_i^n x_f^2}{h_f^n E'} \right )^{\frac{1}{(2 + 2 n)}} - hydraulic maximum fracture width KGD (ref[1] eq 9.55)
E'=\frac{E}{1-\nu^2} - plain strain modulus
w_{f,hydr,avg} = w_{f,hydr,max} * \gamma - hydraulic average fracture width
\gamma_{PKN}=\frac{\pi}{5} - shape factor PKN (ref[1] eq 9.10)
\gamma_{KGD}=\frac{\pi}{4} - shape factor KGD (ref[1] eq 9.24)
w_{f,prop}=\frac{M_{prop}}{2 x_f h_f (1-\phi_{prop}) \rho_{prop}} - propped fracture width
V_i = V_f + V_L - mass balance equation (ref[1] eq 8.1)
V_i = q_i t - injected volume into one fracture wing
A_f = x_f h_f - the area of one face of one wing for rectangular fracture shape
A_f = x_f h_f \frac{\pi}{4} - the area of one face of one wing for elliptic fracture shape
V_f = A_f w_{hydr,avg} - volume of fluid contained in one fracture wing
V_L = K_L 2 A_f C_L \sqrt{t} + 2 A_f S_p - volume of fluid leak-off to formation through the two created fracture surfaces of one wing
q_i t = A_f w_{hydr,avg} + K_L 2 A_f C_L \sqrt{t} + 2 A_f S_p - mass balance equation (ref[2] eq 4.6)
\eta = \frac{V_f}{V_i} - fluid efficiency

Opening time distribution factor KL

Nolte opening time distribution factor KL

2 K_L=\frac{8}{3} \eta + ( 1 - \eta) \pi - (ref[1] eq 8.36)

Carter opening time distribution factor KL

K_L=-\frac{S_p}{C_L \sqrt{t_e}} - \frac{w_{f,hydr,avg}}{2C_L\sqrt{t_e}} + \frac{w_{f,hydr,avg}}{2 \eta C_L \sqrt{t_e}} (ref [2] eq 4.8)

where:

\eta=\frac{w_{f,hydr,avg}(w_{f,hydr,avg}+2S_p)}{4\pi {C_L}^2 t_e} \left ( exp(\beta^2) erfc(\beta) + \frac{2\beta}{\sqrt\pi} - 1 \right )(ref [2] eq 4.9)

and:

\beta=\frac{2C_L \sqrt{\pi t_e}}{w_{f,hydr,avg} + 2S_p}(ref [2] eq 4.9)

Nolte G-function for opening time distribution factor KL

g_0(\alpha)=\frac{2 + 2.06798 \alpha + 0.541262 \alpha^2 + 0.0301598 \alpha^3}{1 + 1.6477 \alpha + 0.738452 \alpha^2 + 0.0919097 \alpha^3 + 0.00149497 \alpha^4}(ref [2] eq 4.12)

where:

\alpha_{PKN} =\frac{2n+2}{2n+3}
\alpha_{KGD} =\frac{n+1}{n+2}

Pumping schedule

According to Nolte[3] the schedule is derived from the following assumptions:

  • the whole length created should be propped
  • at the end of pumping, the proppant distribution in the fracture should be uniform
  • the proppant schedule should be of the form of a delayed power law with the Nolte's exponent and the fraction of pad being equal
\epsilon= \frac{1-\eta}{1+\eta} - Nolte exponent
t_{pad}=\epsilon t_e - pad pumping time
c_e=\frac{M_{prop}}{2\eta V_i} - proppant concentration at the end of pumping
c=c_e \left ( \frac{t-t_{pad}}{t_e-t_{pad}} \right )^{\epsilon} - slurry concentration vs time
dt_{stage}=\frac{t_e - t_{pad}}{N_{stages}} - ramping stage duration
c_{stage} = \frac {\int \limits_{t_{start}}^{t_{end}} c_e \left ( \frac{t-t_{pad}}{t_e-t_{pad}} \right )^{\epsilon} dt}{t_{end}-t_{start}} - ramping stage slurry concentration
c_a=\frac{c}{1-\frac{c}{\rho_{prop}}} - conversion form slurry concentration (proppant mass per unit of injected slurry) to clean concentration (proppant mass per unit of injected clean/base/"neat" fluid)

Flow Diagram

Comparison study

Nomenclature

w = width, m
n = rheology flow behavior index, dimensionless
K = rheology consistency index, Pa*sn
q = slurry injection rate for one wing, m3/sec
h = height, m
x_f = fracture half-length, m
E = Young's Modulus, Pa
E' = plain strain modulus, Pa
M = mass, kg
V = volume, m3
t_e = total pumping time, sec

optiFrac

C_{fD} = dimensionless fracture conductivity, dimensionless
C_A = shape factor, dimensionless
E = Young's Modulus, psia
f = f-function, dimensionless
Gel Damage = proppant permeability reduction due to gel damage, %
I_x = penetration ratio, dimensionless
J_D = dimensionless productivity index, dimensionless
k = permeability, md
N_p = dimensionless proppant number, dimensionless
\bar{P}_D = dimensionless pressure (based on average pressure), dimensionless
P_{net} = net pressure, psia
SG = specific gravity, dimensionless
V = volume, ft3
x_e = drainage area, ft2


Greek symbols

\delta = dry to wet width ratio at the end of pumping, usually 0.5-0.7
\gamma = geometric factor in vertical direction, dimensionless
\nu = Poisson's ratio, dimensionless
\phi = porosity, fraction
\pi = 3.1415
\rho = density, kg/m3

Superscripts

opt = optimal
pss = pseudo-steady state
ss = steady state

Subscripts

e = external
f = fracture
gross = gross
max = maximum
net = net
prop = propped or proppant
r = reservoir
hydr = hydraulic
prop = propped
PKN = Perkins-Kern-Nordgren geometry
KGD = Khristianovic-Geertsma-de Klerk geometry
avg = average
i = injected
L = leak-off

References

  1. ↑ 1.0 1.1 1.2 1.3 1.4 1.5 Valko, Peter; Economides, Michael J. (1995). Hydraulic fracture mechanics. Texas A & M University: John Wiley and Sons. 
  2. ↑ 2.0 2.1 2.2 2.3 2.4 Economides, Michael J.; Oligney, Ronald; Valko, Peter (2002). Unified Fracture Design: Bridging the Gap Between Theory and Practice. Alvin, Texas: Orsa Press. 
  3. ↑ Nolte, K.G. (1986). "Determination of Proppant and Fluid Schedules From Fracturing-Pressure Decline"Free registration required (SPE-13278-PA). Society of Petroleum Engineers. 
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