Sr.Process Eng with +10 years experiences in oil&gas engineering company


Last Updated: 18th August 2018 (over 4 years ago)

Address
Indonesia

E-mail
Locked

Phone Number
Locked

Gender
Male

Age Range
35 to 44

Qualification Level
Degree

Languages
English, Indonesian, Malay

Summary

ACADEMIC QUALIFICATIONS:
• Bachelor of Engineering in Chemical Engineering from Universitas Indonesia (UI), Depok/Jakarta, Indonesia, in July 2005, in first/regular class.
 Received an invitation from Universitas Indonesia (UI) to study in first/regular class without university entrance test/examination.
 Received an invitation from 2 (two) other universities to study in first/regular class without university entrance test/examination (Chemical Engineering-Universitas Sumatera Utara and Electrical Engineering-Universitas Brawijaya).
• Senior High School (SMU) 2 Payakumbuh, Indonesia, July 2001, 8 times earned the first rank and 1 time earned the second rank of total of 9 quarterly at SMU 2 Payakumbuh.

PROFESSIONAL EXPERIENCE:
• Worked with Singgar Mulia Engineering and Consultant, from March 2014 to March 2016, as Senior Process Engineer.
• Worked with WorleyParsons, from July 2008 to March 2014, as Process Engineer II.
• Worked with Saipem, from February 2008 to July 2008, as Junior Safety Engineer.
• Worked with Rekayasa Industri (under Koperasi Reka Sejahtera), from December 2007 to February 2008, as Process Engineer.
• Worked with Tripatra Engineering, from December 2005 to November 2007, as Process Engineer.

PRESENT PROFILE:
A Chemical Process Engineer with a strong background in oil and gas engineering design and process improvements. Experienced in engineering Oil & Gas sectors more than 10 years.
The current areas of focus lie in process engineering related to New and Existing plant expansion projects during conceptual study, FEED, Engineering detail and construction phase, Process optimisation, proposal and bid.

KEYSKILL:
Process Engineering:
 Conceptual Study, FEED & Detail Design of Offshore/Onshore Oil & Gas plant & equipment
 A goal-oriented professional B. Eng. degree in Chemical Engineering & extensive experience in Basic & Detail Process Design Engineering jobs. Possess the drive and ability to work with all levels of an organization.
 Technical Specialist in designing, checking work flow with expertise in setting up coordination with various engineering disciplines and 3th party company.
 The recommendation of conceptual study is ranked based on reliability (weight factor 40%), CAPEX & OPEX cost (weight factor 30%) and Maintainability & constructability (weight factor 30%).
 Implementation of International standard and company standard for process engineering jobs.
 Submit document before due date with consider the quality of document output. Submission shall be late in case of any technical issue which need the other/client clarification or waiting from other/client supplied data.
 Hands on experience of various Design software tools like HYSYS, FLARENET, FLARESIM, PIPENET, INSTRUCALC, Safety valve sizing (In house), etc. Proven expertise in preparing & checking P&IDs, preparing Data sheets for equipment and packages.
 Hands on experience of engineering-process calculation, sizing and HAZOP.
 Possess knowledge prepare engineering deliverables and man hour estimations in tendering and bids.
 Possess excellent written, oral and interpersonal and communication skills, with proficiency in English, Bahasa Indonesia and Bahasa Malaysia.

Summary of Experiences, Projects and Few Examples:
1. Complete recommend to pressurize the downstream of choke valve using nitrogen or produced gas, and inject MEG in the upstream of choke valve to prevent the operating temperature in the downstream choke valve lower than MDMT and to prevent hydrate form during well start up in the EPCI for MDA & MBH Field development (Offshore)
2. Successfully part of engineering proposal team which win at least 6 (six) proposal (small to large-scale project) (Onshore and Offshore). Example win of proposal: HCML EPCI project, the project is to install two (2) new wellhead platforms (110 MMSCFD MDA Platform, and 55 MMSCFD MBA Platform) (Offshore).
3. Successfully responsibilities to drive, control and manage (act as lead) process engineers and 3th party company for new 365 MMSCFD gas processing facility in the Tiung Biru project. Process Engineers and 3th party company success issue around hundreds of Shutdown Hierarchy and Cause and Effect less than 1 month (less than the target due date). The Shutdown Hierarchy and Cause and Effect cover Separation unit, Acid Gas Removal unit, Gas Dehydration Unit, Sulphur Removal and Recovery Unit, Tail Gas Unit, Thermal Oxidizer, Condensate Stabilization unit and any utilities (Onshore).
4. Successfully complete to give recommendation to solve the increase of the water/oil ratio during midterm and long term production in the ESP Study 2014 project. The recommendation are (Offshore):
a) Recommend to replace the existing pipeline PCP-MM with a new one, since the existing PCP-MM back pressure will be higher than existing MAWP during midterm and long term period.
b) Recommend to utilize existing shipping/booster pumps until November 2017, during the operation, the impeller of existing pump will be replaced to match between flowrate and head.
c) Recommend for PCP Repumping at year 2019.
d) Recommend to configure 2 booster pumps (400 hp) and 2 shipping pump (400 hp) during Midterm operation (2019). 1 booster pump and 1 shipping pump operate and another 1 booster pump and 1 shipping pump standby. 2 pumps (400 hp) are existing, and another 2 new pumps (400 hp).
e) Recommend to configure 3 booster pumps (400 hp) and 3 shipping pump (400 hp) during long term operation (2023). 2 booster pump and 2 shipping pump operate and another 1 booster pump and 1 shipping pump standby. 4 pumps (400 hp) is existing (from current and midterm), and 2 pumps (400 (hp) is new one.
f) Recommend to install a new GTG to cover power consumption from 1 booster pumps (400 hp) and 1 shipping pumps (400 hp) running during midterm operation.
g) Recommend to install a new GTG to cover power consumption from 2 booster pumps (400 hp) and 2 shipping pumps (400 hp) running during long term operation.
h) Recommend to install a New FG Scrubber to cover buffering time due to additional fuel gas consumption from new GTG. Since there is no available space area in the existing platform to fulfil the FG Scrubber buffering time 30 minutes (criteria). Recommend the dimension of a new FG Scrubber based on maximum available space (area and height).
5. Complete to recommend the dimension and location of new ground flare pit and new ground flare pit pump size in the ORF ground Flare Relocation Project (Onshore).
6. Successfully complete to recommend for VRB infill well project (Offshore):
a) Complete recommend to inject methanol at the upstream of the VRB 10/11 Choke valve to prevent hydrate before and during VRB10/11 well start up. The methanol injection is stopped after downstream VRB-10/11 reach normal operating condition (P and T).
b) Complete recommend to pressurize the downstream choke valve before well VRB 10/11 start up to prevent mechanical failure due to the temperature downstream of choke valve can be lower than MDMT (-20 C) in the VRB infill project.
c) Complete to recommend to immediate depressurization of flowline for maintenance purpose and avoid prolong containment of gas in the flowline to prevent hydrate.
7. Complete to recommend the design capacity of Flare of SP Tegal Pacing Plant is 16.16 MMSCFD (based on PSV Block discharge) in the SP Tegal Pacing Project (Onshore).
8. Successfully complete to recommend for PCI BCD5 project (Offshore):
a) Complete recommend for all modification of JT Plant, NGL plant, Glycol injection in the presentation form (power point form).
b) Complete recommend to inject MEG during normal operation to prevent hydrate.
c) Complete recommend to install new MEG injection and new MEG regeneration unit to suppress the hydrate, since the existing Glycol reconcentration system package is insufficient for additional new Geragai Receiving facilities with a new operating condition in JT and Hammilton plant in the FEED Geragai Modification for BCD-5. The recommendation is selected based on reliability (weight factor 40%), CAPEX & OPEX cost (weight factor 30%) and Maintainability & constructability (weight factor 30%) of 3 options (MEG injection, TEG dehydration and TEG injection).
d) Complete recommend to utilize the existing glycol regeneration as a backup of new MEG regeneration.
e) Complete estimate the cost of new MEG injection and MEG regeneration is USD 620,535.
f) Complete recommend to modify the JT Plant and Hammilton Plant to reach C3+ recovery 65% (JT Plant) - 70% (NGL Plant) and gas dew point is decrease to -20 F. the example of modification are:
i. Recommend to install a new Chiller, new refrigerant unit and new separator in the downstream of Low Temperature Separator (JT Plant)
ii. Recommend to replace the existing HE in JT Plant.
iii. After meeting between PTSM and PCI, all existing JT Plant will be replaced with a new dew point control system. The new dew point control system shall follow existing NGL Hammilton configuration.
iv. Recommend to install new Chiller and new refrigerant unit in the upstream of existing Cold Separator (NGL Plant)
v. Complete estimate the cost modification for liquid recovery around US$ 1,168,677.
g) Complete recommend flare design flowrate is 50.6 MMSCFD. (based on BDV Fire case).
9. Successfully complete to recommend the location of new Tanks, location of new pumps, location of new line, location of tie-in point, location of any associated instrumentation, size of new tanks, new pumps, new line and new instrumentation, in the Waterflood and Water Injection projects (Onshore and Offshore).
10. Complete recommend in the SLS Gas Tank Blanketing system to install 2” gas blanketing line with breather valve in the Tank which contain HC. Recommend inbreathing breather valve flowrate shall be handle maximum flowrate at Tank liquid outlet plus thermal effect (condensation). Recommend outbreathing breather valve flowrate shall be handle on maximum inlet flowrate to Tank plus thermal effect (heat) (Onshore).
11. Successfully complete to response, closed and implemented all HAZOP response sheet in the PID and any related documents in the HAZOP/HAZID Follow Up at Mike Mike Flowstation (WO#119) (PHE ONWJ). The example case of hazop response is shown below (Offshore):
System Case:
The current design at the 2 phase Production Separator have a level transmitter, a liquid control valve, a SDV inlet and no SDV at liquid outlet and no LLLL. Based on HAZOP recommendation, requirement to add LLLL shall be reviewed.
Solve:
In that case above, complete to recommend to install a new LLLL and a new SDV at Production Separator liquid outlet to prevent potential loss of level and potential gas blowby in case liquid control valve stuck open. It is recommended the location of new SDV shall be as closed as the Production Separator liquid outlet nozzle and level setting of LLLL shall be follow company criteria and shall consider for the operator response time between low level alarm and LLLL.
12. Successfully complete to SisiNubi Phase 2B and Peciko Phase 7B development project. For example recommendation for one platform (WPN3) (Offshore):
a) Complete recommend the Flare Design Flowrate, and Material of flare header line in the SisiNubi Phase 2B and Peciko Phase 7B development project. Example recommendation for one platform (WPN3):
i. Complete recommend Production Manifold system volume, Test Manifold system volume, and 16” Departure Trunkline system volume required BDV. Fuel Gas system volume is not required BDV since PV

Education

Universitas Indonesia (UI)
Chemical Engineering

   Sep 2001
— Jul 2005

Experience

Singgar Mulia
Senior Process Engineer

   Mar 2014
— Mar 2016

Few Examples of Projects:
1. Successfully part of engineering proposal team which win many proposals (small to large-scale project). Example win of proposal: HCML EPCI project, the project is to install two (2) new wellhead platforms (110 MMSCFD MDA Platform, and 55 MMSCFD MBA Platform).
2. Successfully responsibilities to control (act as lead) the 3th party company and process engineers for new 365 MMSCFD gas processing facility in the Tiung Biru project. Process Engineers and 3th party company success issue around hundreds of Shutdown Hierarchy and Cause and Effect less than 1 month. The Shutdown Hierarchy and Cause and Effect cover Separation unit, Acid Gas Removal unit, Gas Dehydration Unit, Sulphur Removal and Recovery Unit, Tail Gas Unit, Thermal Oxidizer, Condensate Stabilization unit and any utilities.
3. Successfully complete to recommend for PCI BCD5 project:
a) Complete recommend for all recommendation to modify in the power point form.
b) Complete recommend for MEG is injected to prevent hydrate during normal operation.
c) Complete recommend to install new MEG injection and new MEG regeneration unit to suppress the hydrate, since the existing Glycol reconcentration system package is insufficient for additional new Geragai Receiving facilities with a new operating condition in JT and Hammilton plant in the FEED Geragai Modification for BCD-5. The recommendation is selected based on reliability (weight factor 40%), CAPEX & OPEX cost (weight factor 30%) and Maintainability & constructability (weight factor 30%).
d) Complete recommend to utilize the existing glycol regeneration as a backup of new MEG regeneration.
e) Complete estimate the cost of new MEG injection and MEG regeneration is USD 620,535.
f) Complete recommend to modify the JT Plant and Hammilton Plant to reach C3+ recovery 65% (JT Plant) - 70% (NGL Plant) and gas dew point is decrease to -20 C. the example of modification are:
i. Recommend to install a new Chiller, new refrigerant unit and new separator in the downstream of Low Temperature Separator (JT Plant)
ii. Recommend to replace the existing HE in JT Plant.Recommend to install new Chiller and new refrigerant unit (NGL Plant)
iii. Complete estimate the cost modification for liquid recovery around US$ 1,168,677.
g) Complete recommend flare design flowrate is 50.6 MMSCFD.

4. Successfully complete to response, closed and implemented all HAZOP response sheet in the PID and any related documents in the HAZOP/HAZID Follow Up. The example case of hazop response is: Complete to recommend to install a new LLLL and a new SDV at Production Separator liquid outlet to prevent potential loss of level and potential gas blowby in case liquid control valve stuck open. It is recommended the location of new SDV shall be as closed as the Production Separator liquid outlet nozzle and level setting of LLLL shall be follow company criteria and shall consider for the operator response time between low level alarm and LLLL.

WorleyParsons
Process Engineer II

   Jul 2008
— Mar 2014

Few Examples of Projects:
1. Successfully part of engineering process team which win many proposals (small to large-scale project). Example win of proposal: Petapahan Waterflood Project (Chevron).
2. Successfully complete to recommend the location of new Tanks, location of new pumps, location of new line, location of tie-in point, location of any associated instrumentation, size of new tanks, new pumps, new line and new instrumentation, in the Waterflood and Water Injection projects (Onshore and Offshore).
3. Complete recommend in the SLS Gas Tank Blanketing system to install 2” gas blanketing line with breather valve in the Tank which contain HC. Recommend inbreathing breather valve flowrate shall be handle maximum flowrate at Tank liquid outlet plus thermal effect (condensation). Recommend outbreathing breather valve flowrate shall be handle on maximum inlet flowrate to Tank plus thermal effect (heat) (Onshore).
4. Successfully complete to response, closed and implemented all HAZOP response sheet in the PID and any related documents in the HAZOP/HAZID Follow Up. The example case of hazop response is shown below:
System Case:
The current design at the 2 phase Production Separator have a level transmitter, a liquid control valve, a SDV inlet and no SDV at liquid outlet and no LLLL. Based on HAZOP recommendation, requirement to add LLLL shall be reviewed.
Solve:
In that case above, complete to recommend to install a new LLLL and a new SDV at Production Separator liquid outlet to prevent potential loss of level and potential gas blowby in case liquid control valve stuck open. It is recommended the location of new SDV shall be as closed as the Production Separator liquid outlet nozzle and level setting of LLLL shall be follow company criteria and shall consider for the operator response time between low level alarm and LLLL.
5. Successfully complete to SisiNubi Phase 2B and Peciko Phase 7B development project. For example recommendation for one platform (WPN3) (Offshore):
a) Complete recommend the Flare Design Flowrate, and Material of flare header line in the SisiNubi Phase 2B and Peciko Phase 7B development project. Example recommendation for one platform (WPN3):
i. Complete recommend Production Manifold system volume, Test Manifold system volume, and 16” Departure Trunkline system volume required BDV. Fuel Gas system volume is not required BDV since PV <100 bara.m3 in the Fuel Gas System Volume (Total Standard GS-SAF-228).
ii. Complete recommend MDMT at flare header and downstream RO/BDV -29 C. Although in Hysys-depressuring, minimum temperature in the downstream RO/BDV is -19.47 C and as per Total standard, MDMT is taken based on minimum calculated operating temperature with 15 C margin. After check with the other software (LNG DYN), the minimum operating temperature in downstream RO is not as lower than hysys-depressuring. After send TQ for company/client acceptance, with the reason, hysys-depressuring result too conservative for minimum operating temperature at downstream of RO, and 15 C margin is too conservative and it will be impact to material change and cost, and company should make decision, between too conservative rules or cost. And company acceptance the recommendation MDMT -29 C and take tolerance for the margin.
b) Complete recommend to inject Methanol in the upstream of choke valve before and during well start-up to prevent hydrate during well start up in. the recommendation is also cover doses, concentration and flowrate.

Saipem
Junior Safety Engineer

   Feb 2008
— Jul 2008

Responsibility :
• Learning Safety Philosophy
• Learning SIL Study
• Learning Fire& Gas Detection Philosophy
• Learning Specification for safety equipment
• Learning Escape, Evacuation and Rescue Assessment
• Learning Flare Radiation Study
• Learning Fire& Gas Detection Philosophy
• Learning Fire Water Hydraulic Calculation
• Learning Escape Route and Safety Equipment Layout
• Learning Hazardous Area drawing and Hazardous Area Schedule
• Learning Fire and Gas Detection Layout.

Saipem
Junior Safety Engineer

   Feb 2008
— Jul 2008

Responsibility :
• Learning Safety Philosophy
• Learning SIL Study
• Learning Fire& Gas Detection Philosophy
• Learning Specification for safety equipment
• Learning Escape, Evacuation and Rescue Assessment
• Learning Flare Radiation Study
• Learning Fire& Gas Detection Philosophy
• Learning Fire Water Hydraulic Calculation
• Learning Escape Route and Safety Equipment Layout
• Learning Hazardous Area drawing and Hazardous Area Schedule
• Learning Fire and Gas Detection Layout.

Rekayasa Industri (under Koperasi Reka Sejahtera)
Process Engineer

   Dec 2007
— Feb 2008

Project : Gasohol Project
Client : Medco Ethanol Lampung
Responsibility :
• Preparation of PFDs/PID’s/HMB,
• Any Process Studies,
• Hazop Preparation.
Project : Proposal of MM&L/KLA Rehabilitation
Client : BP West Java
Responsibility :
• Preparation of PFDs/PID’s/HMB,
• Preparation of Hysys Simulations,
• Preparation of Process Datasheet (Equipment & Instrument)
• Performed & preparation of Utility Demand (Fuel Gas system, Instrument Air system, Heating Medium System, Nitrogen System, Potable Water, Corrosion Inhibitor and other utility)
• PSV Calculation
• Control Valve Calculation
• Vessel Sizing
• Tank Sizing

Tripatra Engineering
Process Engineer

   Dec 2005
— Nov 2007

Project : Gasohol Project
Client : Medco Ethanol Lampung
Responsibility :
• Preparation of PFDs/PID’s/HMB,
• Any Process Studies,
• Hazop Preparation.
Project : Proposal of MM&L/KLA Rehabilitation
Client : BP West Java
Responsibility :
• Preparation of PFDs/PID’s/HMB,
• Preparation of Hysys Simulations,
• Preparation of Process Datasheet (Equipment & Instrument)
• Performed & preparation of Utility Demand (Fuel Gas system, Instrument Air system, Heating Medium System, Nitrogen System, Potable Water, Corrosion Inhibitor and other utility)
• PSV Calculation
• Control Valve Calculation
• Vessel Sizing
• Tank Sizing

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