CEP-Subsea Pipeline -Gas Plant Process StudyGMEC – BEN WEI M.SC. P.ENG.

Purpose of Hysys Process Simulation Study1.0 To predict the production rates

2.0 To provide technical support to operations

3.0 To forecast the future production yields at gas plant

4.0 To estimate the gas shrinkage for future gas field development

5.0 To identify the bottle-necks for gas flow rate and composition changes

6.0 To predetermine process flow and major equipment's change requirements

Process Study Basis1.0 Six Well Stream Compositions and flow rates from LW 3-1

2.0 Reservoir operating conditions in typical six years of 2017, 2018, 2020, 2023, 2026 & 2029

3.0 The process model of matching 2014 operating conditions of CEP-Subsea pipeline- gas plant

4.0 Existing Process Flow Diagrams of Central Platform, Subsea Pipeline& Gas Processing Facilities

5.0 The built model based on operating parameters of Daily Production Report in October 2014

6.0 Fuel gas consumption of Daily Production Report in Oct. 2014

7.0 Existing Equipment Capacity.

Process Study Methodologies1.0 Built the HYSYS model based on the existing facilities and operating conditions of Oct 2014

2.0 Prorated the fuel gas consumption of 2014 based on flow rates of six typical well streams

3.0 Performed process HYSYS simulation to obtain commercial production yields.

4.0 Adjusted TEG, MEG for gas and condensate dehydration conditions at CEP to obtain hydro-formation point to meet the subsea pipeline requirement – 15°C.

5.0 Revised propane recirculation flow rate to meet the condensate stabilization requirements

6.0 Recomputed amine recirculation flow rate to meet the CO2 removal requirements

7.0 Adjusted turbo- Expander refrigeration and deep cuts fractionation to produce commercial sales gas, propane, butane, as well as condensate hydrocarbon.

Unit Flow Diagram (UFD)

Central Platform Gas Plant Terminal Facilities

261 Km- 30 inches Subsea Pipeline

Major Process Facilities at CEP 1.0 TEG Gas Dehydration

TEG Contactor TEG Dehydration for natural gas TEG Regenerator

Natural Gas In

Natural Gas Out TEG In

TEG Solution out

Vapor

Major Process Facilities at CEP 2.0 EG Condensate Dehydration

EG Condensate Dehydration EG Regenerator

Natural Gas with Condensate In

Natural Gas Out

EG In

EG Solution out

Vapor

Condensate Separator

Major Process Facilities at CEP 3.0 Subsea Pipeline

Dehyed Gas and condensate FeedFrom CEP to Subsea Pipeline

261 Km- 30 –Inches Subsea Pipeline

To Gas Plant

PFD of CEP and Subsea Pipeline

Major Process Units at Gas Plant 1.0 Condensate Stabilization

Condensate Stabilization Condensate Stabilizer

Natural Gas with condensate In

Natural Gas Out

Condensate to

Vapor

Condensate Separator

Propane Cooler

Condensate Out

Major Process Units at Gas Plant 2.0 Propane Refrigeration

Propane inlet Scrubber

Propane Vapor

Propane Surge Tank

Propane Compressor

Propane Cooler

Propane Liquid

PFD - Condensate Stablization & Propane Refrigeraion

Major Process Units at Gas Plant 3.0 MDEA Gas Treating

Amine Contactor MDEA Amine Sweetening Amine Regenerator

Natural Gas In

Natural Gas Out Lean Amine In

Rich Amine out

Sour Gas

PFD- Amine Treating unit

Major Process Units at Gas Plant 4.0 Mole Sieve Dehydration

Mole Sieve TowerWet Natural Gas In

Dry Natural Gas Out Regen. Hot Gas in

Regen. Wet Gas in

Regen. Gas Compressor

Regen. Gas HeaterHot Oil

Major Process Units at Gas Plant 5.0 Refrigeration- Cold Box and Expander

Cold Box

Natural Gas in

LTSExpander-Compressor

Contacting Column

Compressor After coolerFeed to Deethanizer

Dry Gas to Sale Gas Compressor

Major Process Units at Gas Plant 6.0 Refrigeration- Cold Box and Deethanizer

Cold Box

Deethanizer

DeethanizerReflux Drum

Contacting Column Bottom to

Depropannizer

LTS bottom from Cold box

Major Process Units at Gas Plant 7.0 Fractionation - Deep Cuts

De-propanizer De-Butanizer

Mixed condensate

Propane

Butane

Condensate H.C.

PFD-Refrigeration & Fractionation

Major Process Units at Gas Plant 8.0 Sale Gas Compressor

Natural Gas in

Sale Gas Compressor

Sale Gas

PFD-Sale Gas Compression

Process Study Results:1.0 Major Sale Gas Flow Rate & Shrinkage Factor

2.0 Major Liquid Production Rates

3.0 Subsea Pipeline Operating conditions- Hydro-formation

4.0 Subsea Pipeline Operating conditions- Slug Flow Conditions

5.0 Gas Plant Operating conditions

1.0 Only One Train Capacity is adequate to process natural gas flow rates for the six years.

2.0 The major equipment will be running within design capacity, no overload

circumstances will take place in the typical six years.