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PIPELINE NETWORK DESIGN Landon Carroll & Wes Hudkins

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Overview Goals Background Information Conventional Pipeline Optimization Analysis Mathematical Model Analysis Expansion Conventional Comparison Application Conclusion and Recommendations

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Goal Create a program that will design an optimal pipeline network, which is faster and more accurate than conventional design methods

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Natural Gas Industry The US consumes 1.5 to 2.5 million cubic feet (MMscf) per month 97% of this gas is piped from the well all the way to your furnace Large upside due to clean Natural Gas power plants and Compressed Natural Gas CNG automobiles

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Natural Gas Price Breakdown *Standard Heating value Gas of 1000 Btu/scf. Thus, $12/Mscf = $12/MMBtu

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Pipeline Optimization Basics

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Pipeline Optimization Methods Hydraulic Analysis Conventional Various Equations derived from The General Flow Equation New Method General Equation combines constants into two parameters, A and B Economic Analysis Conventional J-Curves New Method Mathematical Programming using a General Algebraic Modeling System (GAMS) interface

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NATURAL GAS HYDRAULICS Landon Carroll Wes Hudkins

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Natural Gas Hydraulics 101 Steady State Mechanical Energy Balance on Pipe: (PE) + (ΔP) + (KE) + (Friction Loss) = 0 In most liquids, density is constant: Natural Gas: Therefore, Integration is slightly more difficult Use average z, T, and P to simplify integration:

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Natural Gas Hydraulics 101 KE: Negligible ∆P: PE: Friction Loss:, Therefore,Combine, solve for Q:

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General Flow Equation Conventional Hydraulic Equations are derived from this equation; just insert different values for the friction factor, f

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Conventional Hydraulic Equations 1. Colebrook-White 2. Modified Colebrook-White 3. AGA 4. Panhandle 5. Weymouth 6. IGT 7. Spitzglass 8. Mueller 9. Fritzsche

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Equation Accuracy Analysis Theoretical Pipe Set the Temperature, Inlet Pressure and Natural Gas Flow Rate Solve ∆P with Equation for various diameters and elevation changes Simulate Pipe: Pro/II Set same conditions Compare Results Natural Gas Composition Used Natural Gas ComponentMole Fraction C1C C2C C3C N2N CO C4C iC C5C iC O2O

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Equation Example Modified-Colebrook

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Modified-Colebrook Results

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Costly Error! One Pipeline Flowing 200 (MMscfd) Operating 350 days/year Averaging $8 per Mcf EIA States 3-5% of gas flow is used for compressor fuel 1% of hydraulic error is $224 wasted Natural Gas per compressor per year!

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Range of Error Equation NameRange of Error Cost of Error ($ of fuel cost/compressor/yr) Panhandle3.5 – 10% 784 – 2,240 Colebrook2.4 – 10% 538 – 2,240 Modified-Colebrook1.0 – 8.8% 224 – 1,971 AGA0.2 – 15% 45 – 3,360 IGT7.6 – 17%1,702 – 3,808 Mueller13 – 20%2,912 – 4,480

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Mathematical Model General Flow Equation: Where,Equation becomes: Rearrange: Where, Thus:

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Mathematical Model Analysis Equation NameRange of Error Cost of Error ($ of fuel cost/compressor/yr) Mathematical Model0 – 0.9% 0 – 200

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THE MATHEMATICAL MODEL VS. J-CURVE ANALYSIS Landon Carroll Wes Hudkins

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J-Curve - Simulator Trials Simulations are used to generate diameter/flowrate/pressure drop correlations for the J-curves Three pressure parameters (P 3 ) were selected discretely– 750, 800, and 850 psig. Both segments will have distinct optimums. P 1 = 800 psig P2P2 P 5 = 800 psig L = 60 mi Q = 100 – 500 MMSCFD L = 60 mi P3P3 P4P4 Q = 50 MMSCFD

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J-Curve - Procedure Simulations are run to generate pressure drop at a given flowrate and diameter Cost calculations are completed for these pressure drops which relate to compressor and operating costs Plot cost vs. flowrate Repeat at various diameters and/or pressures The lowest cost at the desired flowrate ‘wins’

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J-Curve – Segment 1 Optimum The lowest TAC at Q=300 is achieved with NPS = 18 for all three pressures P = 750 gives the lowest overall TAC for NPS = 18 Why so many decimal places? At high flowrates, these fractions of cents per MCF can become millions of dollars.

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J-Curve - Segment 2 Optimum Since P = 750 is the optimum pressure parameter for Segment 1, we then determine the optimum diameter for Segment 2 at P = 750 The optimum diameter is then NPS = 18 Then, optimize the system starting with segment 2

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Order of Optimization Optimizing segment 2 first results in the optimum design

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Overall Optimum & Relevance of Optimum The optimum pressure is 850 psig, and the optimum pipe sizes are 18 inches in both segments. Shown: Optimization of Segment 1 at Segment 2’s optimum pressure.

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# J-Curves Required For un-branched pipeline networks such as this one, the number of J-Curves required for optimization is: As the number of pipes in a pipelines network increases, the number of J-Curves required for optimization increases exponentially. # pipes # discrete pressures # orders # diameters

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Economic Optimums Segment Optimum Pressure Optimum Diameters TAC per MCF Total Annual Cost (millions) & 18$ 0.631$ & 18$ 0.616$ 65 Both*85018 & 18$ 0.616$ 65 Two-Segment Network Optimizing Segment 1 first gave the incorrect solution. All possible combinations must be analyzed to find an overall optimum. In order to analyze both segments at once, 48 J-curves must be analyzed for even this simple two pipe network!

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Mathematical Model Results The mathematical model reached an optimum of $2,000 per MCF less than the J-curve method. Why? The J-curve method ignores volume buildup, time value of money, inflation, and many cost variations over time. Remember, this required 48 J-curves and 432 simulations with the conventional method and the results are not even accurate! Nonlinear Model – 2 Pipe Network Pipe 1Pipe 2 Pipe Diameter (in)22 Compressor Work (hp)10,7400 Pressure Drop (psi)1,8301,490 TAC Model$ TAC J-Curves$ 0.616

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THE MATHEMATICAL MODEL Landon Carroll Wes Hudkins

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Model Expansion Willbros, Inc. Friday, February 20 th, 2008 Diameter Coating cost Transportation cost Quadruple random length joints Dr. Bagajewicz Installation cost Pipe maintenance cost Compressor maintenance cost

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Model Logic Linear Model Generates discrete pressures Minimizes net present total annual cost Gives optimum diameters, compressor locations, compressor installation time, and compressor size Nonlinear model These optimums are then input into the nonlinear model Minimizes net present total annual cost

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Model Logic - Input Model Diameter Options Supplier Temperatures Supplier Pressures Consumer Demands (V/t) Demand Increase (%/yr) Min/Max Operating Pressure Compressor Location Options Elevations Pipe Connections Distances Economics Project Lifetime Operating Cost ($/P*t) Maintenance Cost ($/hp,%TAC) Operating Hours (hr/yr) Interest Rate Consumer Price ($/V) Steel Cost(d) ($/L) Coating Cost(d) ($/L) Transportation Cost(d) ($/L) Installation Cost(d) ($/L) Hydraulics Gas Density Compressor Efficiency Compressibility Factor Compressibility Ratio Heat Capacity

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Model Logic – Economic Calculations Objective Function: Net Present Total Annual Cost Total Annual Cost Compressor Cost Pipe Cost Maintenance Cost Operating Cost TAC(t) Pipe Cost Compressor CostMaintenance Cost Operating Cost Capacities and Works come from hydraulic calculations.

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Model Logic – Linear Hydraulic Calculations Capacities to Compressor Cost and Maintenance Cost Equations Works To Operating Cost Equation Capacity Limits Maximum Capacity Pressure Work Total Demand Compressor Work Hydraulic Equation Part A Hydraulic Equation Part B Discrete Pressures DPDZ Discrete Pressures Pressures Pressure Works Total Demand Max Comp Capacity

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Model Logic – Nonlinear Hydraulic Calculations Works to Operating Cost Equation To Compressor Cost Equation and Maintenance Equation Capacity Limits Compressor Work Hydraulic Equation Pressures

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Model Logic - Output Physical Pipe Locations Pipe Diameters Demand at Each Period Flowrates Inlet and Outlet Pressures Compressor Locations Compressor Capacities Economics Net Present Value Net Present Total Annual Cost Total Annual Cost at Each Period Fixed Capital Investment Revenue Operating Cost Pipe Cost Compressor Cost Maintenance Cost Penalties

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CASE STUDY Landon Carroll Wes Hudkins

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Case Study - Given Fairfield Supply P (kPa) Supply T (°R) MinOP (kPa) MaxOP (kPa)4200 Elevation (km) MavisMayberrySplitBeaumontTravis Initial Demand (Mcmd) Price ($/m 3 ) Elevation (km) % Annual Demand Increase Season Demand Variation 8 Year Project Lifetime

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Case Study - J-Curves # simulations per curve # diameters# discrete pressures # pipes# possible compressor location configurations # possible orders of optimization Optimization of this case study using J-curves would require 293,932,800 simulations! If a person were to run this many simulations 24/7 at 5 minutes per simulation, it would take 2796 years! If this person only worked the standard 40 hours per week, it would take 11,776 years! In order to accomplish the design in 6 months, it would require 23,552 employees! At minimum wage, that’s $153,088,000!

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Case Study - Results Non-Graphical Results Pipe 1 ID (in.)22 Pipe 2 ID (in.)22 Pipe 3 ID (in.)22 Pipe 4 ID (in.)18 Pipe 5 ID (in.)12 NPV ($)4,392,078,000 NPTAC ($)243,706,100 Pipe Cost ($)185,720,700 Supplier Compressor Capacity (hp) 22, Consumer1 Compressor Capacity (hp) 13, Consumer2 Compressor Capacity (hp) 13, Consumer3 Compressor Capacity (hp) 8, This took 1 person about 1 hour! FCI init =$303,036,750

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CONCLUSIONS Landon Carroll Wes Hudkins

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Recommendations Expand model to incorporate more pipeline details (i.e. thickness, friction due to fittings, heat transfer) Make more user friendly GAMS coupled with GAMS data exchanger (GDX) to create user interface Uncertainty added to model

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Conclusion Conventional hydraulic equations inaccurate J-Curve analysis inaccurate and time consuming. Does not allow for complex networks. Mathematical model produces accurate results and when coupled with GAMS saves time and money

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Special Thanks Willbros, Inc. – industry feedback and input Debora Faria – original program author Chase Waite – last year’s group member Vi Pham – teaching assistant Mark Bothamley – industrial feedback and input Miguel Bagajewicz - professor

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Any Questions Please see us at our poster with questions.

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