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ksf 2006 Resume
SIDNEY KENNETH FORWARDNote: Pages 1 & 2 are suitable for a 2 page CV if desired
U.K Passport:10 Years/Expiry 2024Date of Birth:24th Aug 1967Marital Status:Married Last Medical:OGUK 22nd Sep 2015 until, 2017Nationality:British Citizen from Birth
Tel: London, Landline +44 20 7246 2990 Tel: Thailand, Chonburi +66 89 236 1412 present.Email: [email protected] UK Address: Westmoreland Terrance, London. SW1V Thailand Address: Bang-Lamung, Chonburi District Languages: German-Good / Russian-Fair / Spanish-Fair
Qualifications (Attested by British Government) all ORIGINAL, including Professional Membership.BSc 2:2Bachelor of Science: Mechanical Engineering, UK with Original Transcript (UK Government attested)B.TECHSE - Business Technical Educational Council, now replaced with NEBOSH Diploma part-1 Technical SafetyTechnical Safety + HSEIA six years (6) yrs. experience in Oil & Gas recently, LNG downstream 2008/10LNG CoachingCoach Nigerian (LNG) engineers 'on liquefaction, refrigerant, mercury removal, fractionation, acid-gas removal.O&G CoachingMentor CONOCOPHILLIPS Operators on units: BOC, NHT, FCCU, PLF, ATU, CDVDU/HSF/N2, 1994-98 periodsTraining Focal point for; ConocoPhillips for their New Graduates familiarisation using; API/ASME/ANSI codes. PipelinesMany years experience on both, above and subsea pipelines from FEED/DED through to const/commissioning. SoftwareAwareness of HYSYS, PRO-II and ASPENPLUS for process plants, PIPESIM, PIPES StandardsGood Overview knowledge of International Safety Standards IEC-61508/ 61511, in U.S.A ANSI/S84.01 LNG/LPG`Very experienced in Gas Processing Plants and LNG/LPG Terminals eight (8) years experience. Trained in.API Spec 6D/6DSS, API 510, API 570, API 620, API 650 standards and recommended practices in petrochemical SpecialityChange Management > Strong knowledge of upstream, midstream and downstream performance management LNG APCI Liquefaction processes > Oil & Gas/LNG Operational Optimisation > Thermal Gas Unit Philosophy > Polypropylene (PP) & Propylene (PO) > Operations Management > Technical Safety and Risk Based Analysis > Systems & Equipment, Analysis & Design > HAZOP, HAZID, FMEA, QRA, ALARP Demonstrations, SIL assessments > Fire & Explosion Risk Analysis (FERA), Safety Case Development > Experienced in Maximo progress monitoring, forecasting and reporting > Competent in commercial contractual and administrative aspects of engineering Refinery Operations & Reconfigurations > Project Management Best Practices > Fuel Optimization > Process Re-Engineering > Throughput Maximization > EPA Standards/Compliance Risk, Crisis and Disaster Management > Managing engineering teams in FEED/DED > Loss Prevention Studies and mitigation. Profile + Skills
Proven and responsible Project Maintenance Manager, providing dedication and accountability to deliver Oil & Gas / LNG projects professionally and on schedule. Thirty years plus international engineering leadership (ten years with a Major Refinery Operator) on LSTK and reimbursable packages; upstream, midstream and downstream, with multiple interfacing contractors providing value engineering. Familiar with FEED/DED endorsement including, all fiscal budget reviews for project execution (segmentation priorities) planning (PEP) on multi-billion dollar projects. Managed engineering teams on; Oil Refining, Gas-Oil Facilities, LNG/GTLs, Steam Assisted Oil Drainage in Yenagoa-Odroma Africa and earlier, Thermal Gas Production in the Joslyn Field Canada. Chair and review the following: SIMOPS (simultaneous operations) HAZID, EIA, HAZOP, SIL Reviews, RAM Studies, High Integrity Pressure Protection (HIPPS) for gas & liquid loss-prevention encompassing, integrity corrosion optimization.
Corporate career profile, leading to current project
Started my career on oil refinery production with CONOCOPHILLIPS 1987-97 consecutively to include oil refining and offshore upstream oil separation, jackets, platforms and hook-up commissioning. Company exposure programs to Viking Gas Plant design and later build, during my Senior/Lead Engineer experience. LSTK and reimbursable Budget Reviews based on Contractor CTR submissions and measurement to achieve Milestone Payment. Lead and write-up Project Execution Planning (PEP) Operating and Control Philosophies as to align Project Delivery deliverables with Primavera Levels 1-5 Schedules. Burullus Gas Company (1998-2001) STOLT Offshore AS (2001-2003) Paris/Egypt for, Burullus Gas Company (1998-2001) for the design and procurement of the onshore facilities for Phase 7 under ENPPI contract. Petrojet carried out the construction works, while Allseas carried out the deepwater pipe-lay and Technip performed the hot-taps tie-in and commissioning of the offshore pipeline. Design & Installation of; Three SGT-300 gas turbine generators for the power plant under Phase 7 were supplied by Siemens while the compressors were supplied by GE. Joined STOLT Offshore (2001-2003) for the, Paris-Scarab/Saffron Development FEED and Detail Design and EPC construction of the whole (end-to-end) $240M project facility endorsement. The project involved the FEED development of a sub-sea field offshore Egypt in 600m of water to include the design of sub-sea valve assemblies and onshore processing. The facilities included 36, 24 and 20 trunk lines, a 300T sub-sea PLEM, two 80T manifolds with suction pile foundations, a 50T SDA with suction pile foundation, eight 10 infield flow lines with PLETS, infield jumpers, and infield and main umbilical lines and all shore approach works. Chiyoda Corporation 2004-2006 Gas Processing Plants (Trains 1+2) LNG/LPG Terminal Prigorodnoye, Sakhalin Russia. Managing a multidisciplinary team carrying out the Pre-FEED, FEED and Post-FEED of LNG Trains 1 +2, integrating with specialist downstream Task Force Team, to carry out technical evaluations/discussion with contractors for the EPCI project. Responsible & accountable for: Gas Processing Plants (Trains 1+2) with a capacity of 4.8mtpa downstream including, LNG/LPG offshore loading Terminals. Nigeria Liquefied Natural Gas 2006-09 operations support for upstream LNG/GTL unstable condensate, and downstream Front End Engineering Design (FEED) and Detail Engineering Design (DED) stabilization& fractionation packages. HAZOP, HAZID, FMEA, QRA, ALARP Demonstrations, SIL assessments to include, Fire and Explosion Risk Analysis (FERA), Safety Case Development, etc.Planning, progress monitoring, forecasting and reporting on Technical Safety Documents and support commercial, contractual and administrative aspects ofengineering for Vendor equipments, selection, and purchase. Team player working with other disciplines and sections to meetdelivery dateswhilst focused on design safety / environmental requirements. TAKREER 2010- 2011 Grassroots Refinery design for TAKREER Abu-Dhabi in Seoul Korea. Seven (7) package(s) design for TAKREER 400,000bopd grass root refinery project at a total cost of about US$20 billion, where my deliverables and team where assigned to the package 3 (offsite and loading) facilities. Leading a multi-discipline specialist engineers PMC team in Abu-Dhabi prior to transferring to Korea with TAKREER-UAE. Prioritize the support process & technical safety reviews at the existing Ruwais Refinery, including Major& Minor Accident Risk, QRA, HAZID, and HAZOP. Project HSE Stage Gate Reviews with Samsung Contractor (phase 3) and othertechnical safety related audits and reviews of existing Ruwais plant Plot Plans and possible Model Clash mitigations. Produce various safety engineering (and legislative compliance) studies as part of TAKREER Safety Team and attend kick-off meetings leading to, progress and designreview meetings for the project and monitor change proposal designs. ADMA-OPCO 2012-2013 Front End Engineering Development (FEED) for processing storage and export of 100,000 BPD of SARB production to include 105,000 BPD of Umm Lulu production through associated subsea pipelines and attached cables. Interface with degassed drilling and upstream facilities team from Umm Lulu offshore division providing downstream conditioning and process, to oil storage facilities at Zirku Island. Lead Technical Safety FEED Validation & Endorsement covering nine (9) EPC Contractor Bidders and correlate their clarifications, exceptions, and deviations assessments for EPC Contract Award. Interface with drilling and reservoir Corporate teams during their selection of drilling package contractors for drilling 86 wells (X2 Artificial Islands) to lift Plateau oil using Crestal-Gas-Injection & Peripheral Water Injection (300 MBD Crude Processing Capacity SARB + Umm Lulu) and future spare. PEMEX 2013-2015 Consultant (Refinery Revamp) Project Engineer, representing PEMEX Mexico offices as Consultant to assess, overhaul and commission low-capacity-performance refineries. Over a period of two (2) years assigned to review, shut-down, revamp, commissioning the following facilities: Antonio Dovali Jaime facility, at Salina Cunits (CDUs) and many of its downstream units to include, gasoline-making fluidic catalyst cracker (FCC) replacement of process/mechanical equipment, de-bottlenecking piping installation, after completing Gas-balancing/Line-Sizing detail design. Examination of the plants, two (2) CDUs also under review for external fatigue, he refinery has capacity of approximately 160,000 bpd resulting in the shutdown on one of its two crude distillation columns. Miguel Hidalgo facility in Tula, near Hidalgo, general scope-of-work required shutting down the FCC units with replacement of the following process trains: LPG Gasoline, Distillation- Kerosene, Heavy Kerosene, Regeneration-Column, Stripper, Reactor, and Steam-Combustion-Generation. The unit's capacity is 40,000 bpd Expansion on - Antonio Dovali Jaime facility, at Salina Cunits (CDUs) and many of its downstream units to include, gasoline-making fluidic catalyst cracker (FCC) replacement of process/mechanical equipment, de-bottlenecking piping installation, after completing Gas-Balancing/Line-Sizing detail design after examination of the plants, two (2) CDUs also under review for external fatigue that resulted the refinery (capacity of approximately 160,000 bpd) shutdown on one of its two crude distillation columns, later refit & commissioned. ADGAS Italy 2015-20015 leading a Detail Design scope of IGD-E Package 1 TEG Dehydration including, reclamation of additional land and site preparation along the western coast of Das Island for the New 42 IGD-E1 Gas Pipeline Scraper Launcher and Interconnecting Pipe racks. Myanmar Oil & Gas Enterprise (MOGE) 2016-Present expansion design of existing Zawtika Field Development offshore field Myanmar, controlled by PTTEP Thailand. Participate with upstream team interface for the development of; Madan/Metagun gas field development wells campaign in the; Yetagun Field heading team review of Detail Design (DED) for offshore platform network, pipelines, and onshore receiving facilities
GENERAL Technical Safety experience reviewing FEED and DED endorsement encompassing PFDs, P&IDs, HAZOP, HAZID, SIL. ALARP, LOPA demonstration, Essential Systems Survivability Assessment (ESSA), Identification of Safety Critical Elements, and development of performance standards as a minimum project criteria.
2016-Now: FEED Study and optimizations studies of Topside/Pipeline network - Myanmar Oil & Gas Enterprise (MOGE)
YETAGUN partial shutdown on both, Yet-A (Wellhead-Platform) and Yet-B (Processing)-Platform) for debottlenecking and implementing MOGE/PTTEP 2008 maintenance under CMMR leakage report. Follow up with QRA Teams to evaluate fatigue inspection programs, and set-up replacement of equipments. Maintenance Lead on; base-line-inspections, covering piping, valves, pumps, as to provide guidance between a multi-disciplines team replacing equipment or component, fault finding reports/vibration analysis and logged for replacement and later service testing and commissioning. This programmed is also an upgrade on both, condensate and oil production Inspection on all piping, static-vessels, ESDV/PRVs, pumps, X3 turbine, X6 generators Prepare and obtain approval for operation and Shore Base budgets. Manage and update the, Computerized Maintenance Management Systems (CMMS) for all maintenance deliverables covering engineering replenish, replacement (like-for-like) service orders with attached scope-of-work, delivery and execution data as a minimum. All supported with full cycle of Reliability-Centered-Maintenance (RCM) activities in the context of equipment criticality assessment, equipment hierarchy development, data gathering, defining maintenance schedules and tasks. Review monthly financial forecasts for operation and Shore Base costs and delegate corrective actions where potential budget overruns are identified. Lead Baseline-Inspections on inline-equipment and intelligent-pigging on 200km p/l offshore (wet-gas-condensate) and 40km p/l and fittings. Project Values USD 490 million
2015-2015: ADGAS-UAE - IDE-Package 1 & Gas Dehydration Unit (GDU) Maier Tecnimont Office, Milan ITALY
PMC Engineering Lead for Mott MacDonald overseeing PMC Maire-Tecnimont (Italy) for new design EDDR execution:Process & utilities group for Gas Compression, Fuel Gas Treating, Gas Dehydration, HAP-IGL Receiving and Inlet Separation.Interface with Prosernat (France) Vendor for the GDU 3D Modeling and30/60/90% modularization package closeout.
TEG Dehydration. Inclusive of the scope of IGD-E Package 1 includes reclamation of additional land and site preparation along the western coast of Das Island for the New 42 IGD-E1 Gas Pipeline Scraper Launcher and Interconnecting Pipe racks.Responsible for the day-to-day running of Phase-1 Detail Design and AD interface with operations team (for data of equipment selection like-for-like and present functionality, wet gas and associated Natural Gas Liquids off take, and their compatibility curves.Reliability Based Maintenance (RBM) Using Key Performance Indicators (KPIs) To Drive Proactive Decommissioning of old unit-facilities, and align new Construction phase.
Assigning tasks, establishing and enforcing standards of conduct and performance in the work environment.Inspecting and auditing in-process and completed work, to ensure work meets SOW and quality standards.Plan, organize, prioritize and perform multiple tasks under austere conditions, to perform functions in an orderly manner.Company focal point for detail engineering design (DED) encompassing, coordination and management issues related to construction and implementation of, DE-E Packages pertaining to, Field Development constructability Strategy.Feed endorsing main technical (i.e. Upstream and Infrastructure) focal point responsible for all contracting activities relating to the FEEDs and coordination of all technical input to these activities. Ensure that Company Policy related to Health, Safety and the Environment are complied with at all times. Provide support to and interface with HES Management & Safety representatives to ensure corporate and in country initiatives are implemented Take leadership role in HAZID & HAZOP, VIP, IPA, RAM analysis and Gap analysis with 3rd Party Facilitators & Contractors. Estimated cost: USD 490 million.
2012-2015 PEMEX Oil Refinery expansions at; Salina Cunits, Hidalgo, Salamanca, Nuevo Leon state, Tamaulipas - Mexico
Consultant Maintenance Lead for, (Refinery Revamp) Project Engineer, representing PEMEX Mexico offices as Consultant to assess, overhaul and commission low-capacity-performance refineries. Over a period of two (2) years assigned to review, shut-down, revamp, commissioning the following facilities: Antonio Dovali Jaime facility, at Salina Cunits (CDUs) and many of its downstream units to include, gasoline-making fluidic catalyst cracker (FCC) replacement of process/mechanical equipment, de-bottlenecking piping installation, after completing re-line-sizing detail design. Set-up individual stand-alone area maintenance programs (per unit) and assigns maintenance & replacement philosophies with a work-timeframe for ordering/delivering leading to completing the work Examination of the plants, two (2) CDUs also under review for external fatigue, this has raised for a like-for-like equipment procurement register with ETA site dates. Brainstorm with operations and discipline head for best-practices based on the equipment operability, material class, and its criticality in-line function. Review equipments procedures prior lifting, pre-installation, hydro testing, service testing, and all kinds of inspection before commissioning. Provided PEMEX appraisal evaluation on team members and set-up additional training where required.
Review all (HSEIA) and other impact/emission studies with relevant Client personnel prior giving authority to go ahead with the work.Always use the what-if safeguarding philosophy and have a back-up plan to use additional safety features (after Discipline consultation) and recommend changes.
The refinery has capacity of approximately 160,000 bpd resulting in the shutdown on one of its two crude distillation columns. Miguel Hidalgo facility in Tula, near Hidalgo, general scope-of-work required shutting down the FCC units with replacement of the following process trains: LPG Gasoline, Distillation- Kerosene, Heavy Kerosene, Regeneration-Column, Stripper, Reactor, and Steam-Combustion-Generation. The unit's capacity is 40,000 bpd
Antonio Dovali Jaime facility at Salina Cunits (CDUs) and many of its downstream units (gasoline-making fluidic catalyst cracker (FCC) process/mechanical equipment and de-bottlenecking) mechanical/piping) installation. Interfacing with RBI and QA Inspection as to define cause-and-effects and use lessons-learnt therefore, make changes to the replacement as to provide a better functionality. Examination of the plants, two (2) CDUs also under review for external fatigue that resulted the refinery (capacity of approximately 160,000 bpd) shutdown on one of its two crude distillation columns and refits & commissioning to be completed Revamp of; Miguel Hidalgo facility in Tula, near Hidalgo thus, prepare scope-of-work required shutting down the FCC units with replacement of the following process trains: LPG Gasoline, Distillation- Kerosene, Heavy Kerosene, Regeneration-Column, Stripper, Reactor, and Steam-Combustion-Generation. The unit's capacity is 40,000 bpd. Keep daily log of area-by-area activities and revisit work permits for updates, change of environment/service, and closure
Major maintenance turnaround carried out at the; Antonio M. Amor facility in Salamanca. Shutdown on the crude unit as well as a reformer and other units for inspection, vessel entry and test/commissioning on this unit's capacity 95,000 bpd after FAT-tests and Reliability runs. HS&E implementation and daily round-table discussions with engineers prior to setting out to work in the morning ethicizing safety are paramount! Keep a safety activity log, document near misses, non-isolation or no pressure-relief where there should be a requirement interface with disciplines and report to Client focal-point Witness equipment removals, inspections, photograph fatigue, identify cause-& effect and make a spreadsheet for later lessons. Set-up a Performance Management meeting with the Client, sharing daily, weekly work-scopes, problems, late delivery of equipment, shut-down schedules etc.
Revamp of their, 275,000 bpd Hector R. Lara Sosa refinery in Cadereyta, in northern Nuevo Leon state. Process piping with Base-Line-Inspection (BLI) including, review of all pumps and control/flow systems + ESDV/PRVs
Turnaround and de-bottlenecking on; Francisco I. Madero in Ciudad Madero, in the northeastern state of Tamaulipas, to include, included, crude unit and a coker. detailed engineering, procurement, construction, training, commissioning and start up for the recondition of the combustion gases system of the No. 1 catalytic plant (FCC) of the refinery. Technip's operating centre in Mexico City, Mexico, was awarded to execute the project with the support of Construcciones Industriales Tapia for construction work.
2012-2013 Abu-Dhabi ADMA-OPCO for their (FEED/DED) Satha-Al-Razboot (SARB) Field Development Project.
Project Engineering Manager for processing storage and export of 100,000 BPD of SARB production to include 105,000 BPD of Umm Lulu production through associated subsea pipelines and attached cables. Interface with degassed drilling and upstream facilities team from Umm Lulu offshore division providing downstream conditioning and process, to oil storage facilities at Zirku Island. Lead Technical Safety FEED Validation & Endorsement covering nine (9) EPC Contractor Bidders and correlate their clarifications, exceptions, and deviations assessments for EPC Contract Award. Interface with drilling and reservoir Corporate teams during their selection of drilling package contractors for drilling 86 wells (X2 Artificial Islands) to lift Plateau oil using Crestal-Gas-Injection & Peripheral Water Injection (300 MBD Crude Processing Capacity SARB + Umm Lulu) and future spare. Provide ADMA compliance with Abu-Dhabi Authority Regulatory that governs contractual, design, and construction requirements regarding technical safety compliance. Assigned tasks for the technical safety and HSE disciplines for each project phase (artificial islands and Zirku Facilities) on time. Lead my team and follow-up of contractor technical safety procedures for the engineering, construction and installation phases. Team participation with other ADMA Groups and Identify key safety aspects for the project and involve relevant shareholders. Regular meetings to manage and follow-up the ALARP process in the project philosophy that has been focused on inherent safety in design and operations. Interface with UMM LULU team and align overall project technical reviews to ensure that technical safety content of the project is adequately addressed, as to identify and control risks and regularly update the project risk register and risk analysis. Develop power sharing and New Jetty loading/unloading system for follow-up given in Flour Pre-FEED and ADMA Safety Philosophy and contribute to establishing test and operational procedure philosophies and align barriers between ADMA and ZADCO on Zirku Island. Commenced this project from Pre-FEED, FEED, and Post-FEED, presently monitoring on-offshore packages (2-4) during the DED stages with contractors worldwide. Project Value $4.5 billion
2010 2011 Abu-Dhabi / Seoul Korea TAKREER (Post FEED/DED) Ruwais Refinery Expansion Project
Senior Project Engineering Manager or Grassroots Refinery design for TAKREER Abu-Dhabi in Seoul Korea. Seven (7) package(s) design for TAKREER 400,000bopd grass root refinery project at a total cost of about US$20 billion, where my deliverables and team where assigned to the package 3 (offsite and loading) facilities. Leading a multi-discipline specialist engineers PMC team in Abu-Dhabi prior to transferring to Korea with TAKREER-UAE. Prioritize the support process & technical safety reviews at the existing Ruwais Refinery, including Major& Minor Accident Risk, QRA, HAZID, and HAZOP. Project HSE Stage Gate Reviews with Samsung Contractor (phase 3) and othertechnical safety related audits and reviews of existing Ruwais plant Plot Plans and possible Model Clash mitigations. Produce various safety engineering (and legislative compliance) studies as part of TAKREER Safety Team and attend kick-off meetings leading to, progress and designreview meetings for the project and monitor change proposal designs. Prepare change estimates for the safety engineering studies. Participated in (what-if) investigations and provide root cause analysis support particularly where technical and/or process safety issues could be involved. Support Safety Case Maintenance on existing Refinery and take lessons learnt as a carryover for the expansion interface. Interface with other (packages X7) project management teams for the completeness of the DED in Samsungs offices in Seoul, South Korea. Set-up meeting with Project Managers and review to approval, process design documents; (technical safety, cause & effects, mass balance, power requirements) during post FEED/DED that were first developed in FEED by Bechtel under Flour PMC in London. Provide engineering management for all disciplines and select suitable project PFD/P&ID reviews for coaching Emirati Graduate Engineers. Approved and appointed TAKREER leading management-authority for the approvals of specifications, PFDS/P&IDS/SLDs/ and DED Project Close-outs during measurement of deliverables completion aligned with scheduled completion prior milestone payments to contractors. Experienced deputizing and multi-tasking as Project Engineering Director (in his absence) in Seoul Korea, especially whilst facilitating Samsung Contractor execution of the reliability management system approval for use at Ruwais Abu-Dhabi site during commissioning through to operations and start-up philosophy phase. Heading a team to evaluate Contractor potential capability prior awards for; desalination, WWTP, boilers, seawater intake, tanks and numerous other deliverables, to include support to SANSUNG to develop pre commissioning/commissioning documents/procedures. Oversea management of, pipeline hydraulics, development of interface naphtha, condensate pipeline tie-ins, PFD, P&IDs, equipment packages, data-sheets, specification and preparation of Design Engineering Basis Memorandum for project close-out in both, Seoul and Abu-Dhabi home Office. Project Value $7.3 billion for offsites content.
2006-2009 Nigerian Liquefied Natural Gas Corporation, Abuja HQ & Bonny Island, NIGERIA
Senior Maintenance Lead later, Head of Maintenance for implementing, New Fields Development and lead Technical Safety Authority (debottlenecking phases) and integrate equipment like-for-like with maintenance teams. Debottlenecking and upgrading piping and mechanical equipment, processing mediums for Trains Five & Six with emphasis on interfacing SevenPluss (under Foster Wheeler design) in reading near London. Review NLNG Main & Subcontractors documents that relates to Technical Safety and finalize all safety studies done so far in the project and sign-off. Participate in Corporate audits/verification studies to ensure compliance on site challenges, leading to the close out of Technical Safety Engineering action reports. Demonstrate ALARP, critical to project Statement (Real Time) Technical Safety Engineering support/input in Safety Risk Studies and closeout. Implementing post-detail design on train six with 6 Nigerian Managers, 15 indigenous Lead Engineers to include, process, mechanical, electrical, controls, instrumentation, piping, rotational leads. Daily interface with the Clients representative sharing area-by-area work-scopes, manpower loading, reviewing the CMMS and RCM status, and add/omit as deemed necessary.Diagnose and rectify faults to enhance maximum availability of equipment. Liaise with site operators and Project Engineers as to maintenance criticality issues. Provide multi-discipline technical input in to plant-equipment modification work plans. Discuss raised technical queries and provide guidance to onsite personnel and sub-contractors to identify best practices during preventive and active maintenance. Provide downstream FEED/DED engineering upgrades as to expedite higher production by the introducing Hazard & Effect Management Process [HEMP] parallel to, Environmental, Social & Health [impact] Assessment [ESHA] to encompass the overall, Health Risk Assessment [HRA] at sites. Upon acceptance to HEMP / ESHA, main responsibilities were in operations, specifically to gas treating process trains 4/5/6 and reboil heat and regeneration gas heat transfer. Pressurising gas from NGL extraction units prior cooling against HHP/MP/and LP propane splitting with Cryogenic Heat Exchangers [MCHE] checking temperature/liquefying super cooling to minus 150c. All liquid expansion and recombined end flashing vessels were a major inspection facture during periodic noise, and acoustic vibration tests, due to their variations in pressure and cooling sequencing. Review inspection reports, risk assessment matrix [RAM] for maintenance on - GE Frame 7EA Gas Turbines, propane compressor, booster compressors, extraction units for MR recycling [in parallel] off spec gas to inlets.
Head of Maintenance for Train Six interfacing with SevenPluss interface required high level management capital spending of $349 million and a new team and skill-sets for the upgrade and interface of propane refrigerant circuits, propane [liquid filling] accumulator and maintaining the loop compressor, electrical variable speed starters, de-superheating, condensation and sub cooling the propane in air coolers. Accountable mechanical technical authority at site on behalf of PMCT Provide diagnostics reports with QA/QC personnel and rectify faults to enhance maximum availability of equipment.
Liaise with Project Engineers on maintenance issues. Provide technical input in process/mechanical modification work packs. Answer technical queries and guide Local Team and Sub-contract personnel on maintenance and best practices Manage all operations loss prevention studied, engineering / maintenance review [as not to disrupt booster compression] on the propane loop serving and maintaining all processes after the compressor of the main propane loop MR cooling and GE Frame 7EA Gas Turbine driver sparing sequencing. Corrosion monitoring and change-out mechanical equipment [two stage compressor + secondary propane piping and equipment loops) sharing the GE Frame 7EA Gas Turbine, and lean booster compressor of unit 1500 with spare-parts. Upgrade C3/MR process with end flashing [1500 capacity unit], large condensate stabilize 1 & 5 (1100 capacity units], two pressure relive systems and one liquid disposal system A-6206. Upgrade of fire and gas detection [active & passive] including, process ESDVs. HSEIA Manger reports to myself for updated permits/approvals + NAPIMS, [DPR] quality assurance philosophies. Upgrade GE-Frame [7EA DN-1] 80MW turbine with efficiency 21k BTU/and all ANSI/ASME PTC 36 testing to include, X2 8mtpa liquefaction trains for processing both, associated and non-associated gas streams. Attend meetings with my Lead Engineers as to determine actions and schedules for Major [6yrs] Hot Gas Path [3yrs] Combustion [6mths] inspections. Implement team maintenance planning schedules and cost time resources [CTRs] for contractors deliverables pertaining to LPG Recovery plant facilities and offshore pipelines NNPC /Shell facilities to onshore processing. Project value $2.6 billion
2004-2006 Chiyoda Corporation (4 years) - Gas Processing Plants (Trains 1+2) LNG/LPG Terminal Prigorodnoye, Sakhalin Russia
Integrity Manager for multidisciplinary team carrying out the Pre-FEED, FEED and Post-FEED of LNG Trains 1 +2, integrating with specialist downstream Task Force Team, to carry out technical evaluations/discussion with contractors for the EPCI project. Responsible and accountable for; Gas Processing Plants, (Trains 1+2) with a capacity of 4.8mtpa downstream, including, LNG/LPG offshore loading Terminals. This was a new DMR (Dual Mixed Refrigerant) process in this project to provide a base-load LNG plant. Lead the technical feasibility study for process selection to upgrade sulphur recovery from 96% to 99% to comply with Gazprom requirements. Preparation for SOR / FEED study and technical support during FEED and EPC phases and Boil Off Gas Compressor and preparation of technical study to recover boil off gas during ship loading. Interface with senior site construction engineer leads for installation optimizations for constructing two (2) 100,000 cubic -meter LNG tanks, fractionation/stabilization, acid-gas recovery all piping (mass balance and VOC) during constructability at the LNG loading jetty. Prepared constructability roadmap for action plans and budget expenditure for Package-1 (including 4 schemes for excess fuel gas recovery, Carbonate/DEA flash drums gas recovery, defrost gas recovery and continuous flare gas recovery). Package-2 for CO2 emission gas reduction contains 3 schemes and package-4 for SO2 emission reduction contains 10 schemes. Process Gas absorbers installation 1 sulphur plant third reactor bypass. Tr.3 LNG rundown pumps, MP/HP carbonate pumps in; Tr.1/2 Tr.1/2 critical PSVs duplication, including Tr.3 Cryo leak to the LNG flash drum. Managed relevant Vendors during the commissioning and start up of the process trains units installed (HSRGS, Desalt units, Polishing systems, Waste water treatment unit). Prepare (walk-downs) on piping, piping, off sites and mechanical equipment, for their completeness. Later, offshore Head of Maintenance focal point: Review precommissioning procedures and line-fill and pneumatic/hydro test acceptance prior LNG trains performance and plant reliability test. Upgrade development ofthe Astokhskoye block for year-round operation atthe Piltun-Astokhskoye-A (PA-A) platform that included process gas trains optimization and installation, to include pumps and automation transmission, increase 12MW of power (GTG) turbine generation prior commissioning ofthe Piltun-Astokhskoye-B (PA-B) platform inthe Piltun block ofthe Piltun-Astokhskoye field. In addition, the same optimization was completed through to commissioning ofthe first Russian offshore gas production platform Lunskoye-A (LUN-A) atthe Lunskoye field.Upgrade of current hydrocarbons treatment atthe Onshore Processing Facility (OPF) tobelinked with pipelines coming from all three offshore platforms to include, oil and gas transportation from the north tothe south ofthe island through 800-kilometer onshore pipelines Project value 2.7 billion. 1998-2001 Burullus Gas Company, a Joint-venture (JV) of EGPC (50%), BG Egypt (25%) and Petronas (25%) Later, (2001-2003) Stolt Offshore, Paris-Scarab/Saffron Development-Sub-Sea Pipelines
Delivery Engineeing Manager for, Burullus Gas Company (1998-2001) for the design and procurement of the onshore facilities for Phase 7 under ENPPI contract. Petrojet carried out the construction works, while Allseas carried out the deepwater pipe lay and Technip performed the hot-taps tie-in and commissioning of the offshore pipeline. Siemens supplied three SGT-300 gas turbine generators for the power plant under Phase 7 while GE supplied the compressors. Joined STOLT Offshore (2001-2003) for the, Paris-Scarab/Saffron Development FEED and Detail Design and EPC construction of the whole (end-to-end) $240M project facility endorsement. The project involved the FEED development of a sub-sea field offshore Egypt in 600m of water to include the design of sub-sea valve assemblies and onshore processing. The facilities included 36, 24 and 20 trunk lines, a 300T sub-sea PLEM, two 80T manifolds with suction pile foundations, a 50T SDA with suction pile foundation, eight 10 infield flow lines with PLETS, infield jumpers, and infield and main umbilical lines and all shore approach works. Lead all technical safety measures with the process department therefore, conducting/participating in process hazards analysis (PHA) within all segments of on-offshore activities and gathering installations whilst recognizing client specific methodologies. Chair engineering teams and brainstorm/debottleneck ideas encompassing closeout safety analysis risk actions after workshops for HAZID, HAZOP, and SIL/LOPA, Safety MOC Reviews. Responsible and accountable for Scarab/Saffron Action Tracking Registers and ensure their managed effectively by each discipline lead engineer, and final close-out documentation provided for each project phase. Onshore (Facility) works comprised of installation of pipelines, jackets, MSF topsides, and tie-ins to pig receivers with inlet well stream manifolds cooling for primary gas/liquids separation. In addition, CO2 removal plant with associated pre-treatment, condensate dewatering and stabilization, flash gas recompression. Designed, procured, and commissioned, 4 Solar Taurus gas turbine power generators with waste heat recovery units 3 separate types of heat exchange systems, for the numerous heat exchangers. Lead the engineering downstream reliability and Vendor implementation and write as the team implemented commissioning Operating & Maintenance Action and Execution Plans. Prepare commissioning plan as to track tie-ins into VENDOR equipment and critical piping systems and sub-systems. Upon approval, proceeded to draft and prepare the commissioning procedures, operating and training manuals. Project value 4.8 billion
1987-1997 ConocoPhillips Operator from Graduation, Killingholme Humber-Refinery, England. (Humber Oil Refinery, Licenced (process) units 400-600 CDVDU/HFA Outsourced training in Scotland/USA/Canada).
Senior Operations Manager (earlier Operations Engineer) covering 10 years from post University leading to an assignment on; Humber Refinery, South Killingholme, Viking Terminal, St Helens, Aberdeen, LOGGs Offshore, Canada. Leading a team of multi-discipline engineers for offshore oily liquids API Grade 35 with GOR medium into the refinery separation and downstream processing during normal operations encompassing, turnaround, pre & post shutdowns in reediness for start-up. Daily operations and inspections on; CDVDU, flares, amine, boilers, naphtha, HFA, condensate, WWTP, desalination, compressors, separation units (stages 1&2) filters, hydrotreaters. Periodic removal and reinstatement during post-shutdowns of reactor, heaters, deiseltreater units, check boot water analysis of effluent separators, main fractionators columns, and overhead vessel in hydrocracker. Later during the years, assigned to Alison Philips and Viking Gas Terminal in St. Helens Theddlethorpe overseeing FEED/DED upgrade trains for Scotland/North England trans-flow pipeline treating. Assigned to Aberdeen Scotland for Corporate training, carry out studies on process plant and equipment for production operability, and reliability for refinery Alkylation process. Lead operations engineer working on trains; propylene, butylenes, C3 and C4 olefins, Catalytic Cracking Unit, Fluidized Catalytic Cracking, LPG, and gasoline systems. Sequence start-up of, Crude Distillation Unit, Vacuum Distillation Unit (CDU / VDU) to separate crude into primarily fractions of LPG, Naphtha, Kerosene, Gasoil, Vacuum Gas Oil and Vacuum Residue. Implementation of Technical Safety system and mitigate using technical/process safety tools ranging from modification of existing assets, offshore operations, remote pipeline installations, and operations. Distillation Unit (CDU / VDU) to separate the crude oil into primarily fractions of LPG, Naphtha, Kerosene, Gasoil, Vacuum Gas Oil and Vacuum Residue. Reforming and Cracking processing upgrades were under refurbishment prior my departure in 1998. Facilitate technical HSE discussions/risk based decision, HSEIA risk decisions/mitigations derived from documented changes in Plans/Organization Charts/Facility Plot Plan (debottlenecking) that required Risk Assessment workshops. Lead HAZIDs/HAZOPs, Quantitative Risk Assessments (QRAs), HEMP & ALARP concepts throughout all live and shutdown/startup activities. Attended many corporate courses as to evaluate process and mechanical integrity thus, mitigate process safety and material selections to enhance safe practices, operability and reliability.
Phillips 66 Cross Posting to assignments overseas for familiarization of new process trains, overseas USA/CANADA
Optimisation studies of North American and Canadian assets for downstream operations licence processing, off-sites production. Optimise small GOSPs and marginal fields that are under drilling work-overs therefore, measure the downstream throughputs and pipeline, piping and equipment sizing. Reliability (RAM) studies on existing facilities and tie-in philosophies for addition throughput enhancement using regular HAZOP/HAZID walks downs through unit trains and offshore facilities on both, oil & gas facilities. Report failed equipments and evaluate/challenge optimisation of process and plant equipments with recommendation on sizing and sparing philosophies. Overseas training posting to Head Quarters Office in Pasadena (3 years) USA office, receiving mentoring from DUPONT engineers during application licencing technology and pour-point-depressant (de-waxing) impulse-flooding in high viscosity and waxy oils. Optimization studies for the removal of API Grade 8-10 heavy (bitumen) crude with Phillip 66 Canada team for the design of well upstream/downstream 500C heat recovery steam. Optimize heavy-oil extraction using Thermal Assisted Oil Production in the Roslyn Field to achieve fluid control of 340-400 using Solar Steam Generators and THERMAX power generation.
Phillips 66 - Offshore Viking and Theddlethorpe Viking Gas Terminal - from 1990 -1992 (2years)
Offshore Platforms to downstream Gas Plant Facilities assigned to review all project work scope for gas compressor plant, CDS- Central Degassing Station and 3 existing RDS-Remote Degassing Stations in support for upgrading of water supply wells, NAG injection wells, existing gas injection wells, and booster oil wells. Review and provide Input with Lead Engineers during pre-commissioning of pipelines and their relevant procedures and all physical Rotating and Static equipment, punch listing / clearing through to reliability and FAT tests. Interface daily/weekly planning during the Final Commissioning Acceptance lube-oil & seal-oil-flushing, lube-oil-cooler start-up, gas compressor, and centrifugal pumps. Preparing with the engineering teams for pre-commissioning/commissioning with Vendors on, Alstom Gas Compressor, and Dresser Rand X2, Flowserve Controls, and Weir pumps. Witnessing, reliability runs on, thermomeccanica, Novo Pignouni, Seko Bono & Abionnetta Pumps. Commissioning of (API 686 and API 614) Static Equipment Vessels and internals e.g. inlet device, vane packs, plate packs, and weir plate in 1st& 2nd stage Production Separators. Perform, pressure leakage, bearing wear, acoustic vibration monitoring for safe operation, pre-commissioning and commissioning and start-up on the following as a minimum: process piping, valves, motors, turbines and HP/LP process equipment.
Phillips 66 - Offshore drilling England - (Phillips 66) downstream only from 1994 - 1995 (1 years)
Offshore Lead Facilities Engineer monitor the award contractors Brown and Root, Energy Services, AMEC Process, Det Norske VERITAS Integrity Management interfacing with Viking Phoenix drilling section on blocks 49/12-49/16 and 49/17-detail design development, fabrication hook-up of Viking KD, in block 49/12a. The platform Viking LD, in block 49/17, mainly produces the Wx and Gn reservoirs hence; gas from Viking KD has a capacity length 13.5km, 16in diameter pipeline to the Viking B platform.