Nodal analysis. You need to use lift curves /outflow curves assuming your node is the reservoir sand face. The pressure at the sand face is the inlet pressure to your tubing/well. From there, the friction and gravity forces act in the opposite direction of the flow results in pressure reduction. You can use pipesim, wellflo, prosper..etc be careful with the phases of the fluid sice that makes a big difference (use the correct PVT for the fluid at the sand face and not at the surface). 

Good luck. 

From the reservoir, the fluid enters the well bore into the production tubing. Flow from the reservoir through perforation tunnels constitutes the well bore completion pressure drop. Once inside the well bore, and flowing up the tubing, it will be subjected to a ­­Frictional pressure drop.

Hydrostatic head pressure drop due to potential energy.Kinetic energy losses due to expansion, contraction in the fluid area and flow through restrictions.

These combination of pressure constitute the vertical lift pressure drop

On arrival at surface, the fluid passes through the surface wellhead facilities and flow line including passing through the choke. From here fluid can go to the separator units for the separation into gas, oil, water, etc .The productivity of the system is dependent on the pressure loss which occurs in each of the units of system listed. The pressure drops which occur the reservoir, the tubing, and choke are production rate dependent and these relationships define the means by which the production technologist optimizes the production of the fluid from the reservoir.

 Thus there must be a combined optimization of:-

·         Inflow Performance (IPR): Definition of pressure drop versus flow rate relationship across the reservoir

·         Tubing or Vertical Lift Performance (TPR): Definition of pressure drop versus flow rate relationship in tubing and well bore necessary to lift the fluid from reservoir to the surface.

·         Choke Performance (CPR): Definition of pressure drop versus flow relationship involved in choke sizing for flow pressure to separator.

In the development of a hydrocarbon reservoir , otherwise known as reservoir management , the energy stored within the compressed state of the reservoir fluids , in most cases provide the total pressure loss in the entire production system  thus ,

                P =   Res +  PBHC +  PVL + PSURF +  PCHOCK   + PSEP(5. 17)

Where:-

•         P is the initial or average pressure within the reservoir.

•         Res is the pressure loss caused by the flow of flow of fluid within the reservoir to the well bore.

•         PBHC is the total pressure loss generated by the design of fluid entry into the well bore which is dependent on the bottom hole completion details.

•         PVL is the pressure loss caused by the fluid flowing up production tubing string.

•          PSURF is the pressure loss in well bore, Xmas tree, and surface flow lines.

•         PChoke is the pressure loss across the choke designed to cause significant amount of pressure drop in order to provide stability to downstream separator and treatment facility

•         Psep is required operating pressure in separator designed to separate out liquid and gas phases from water and basic sediments. Thus, each pressure drop can be minimized individually or collectively to produce a maximum production rate for the available pressure. This is known as Production system optimization.

Mohamad; I think this paper can be useful, it shows the methodology to find the appropriate vertical flow correlation for a field producing oil crude " Integral Analysis of Artificial Lift System in Heavy Crude Oil."