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TECHNICAL SPECIFICATION Nº: I-ET-3010.1M-1254-321-P4X-001

CLIENT: SRGE SHEET: 1 of 33

JOB: REFERENCE BASIC DESIGN 1001056398 0010

AREA: BÚZIOS

DP&T-SRGE TITLE:

CO2 TURBOCOMPRESSOR NP-1

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MICROSOFT WORD / V. 2010 / I-ET-3010.1M-1254-321-P4X-001_A

I N D E X O F R E V I S I O N

R E V . D E S C R I P T I O N A N D / O R R E V I S E D S H E E T S

0

A

ORIGINAL ISSUE

REVISED WHERE INDICATED

REV. 0 REV. A REV. B REV. C REV. D REV. E REV. F REV. G REV. H

DATE AUG/13/18 15/ABR/19

DESIGN ESUP ESUP

EXECUTION QUINTIERE QUINTIERE

CHECK LBIANCO LBIANCO

APPROVAL RONAN RONAN

INFORMATION IN THIS DOCUMENT IS PROPERTY OF PETROBRAS, BEING PROHIBITED OUTSIDE OF THEIR PURPOSE.

FORM OWNED TO PETROBRAS N-0381 REV.L.

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SUMMARY

1. GENERAL ............................................................................................................ 3

2. CONSTRUCTION FEATURES............................................................................. 4

3. ACCESSORIES AND AUXILIARIES ................................................................... 5

4. AUTOMATION ................................................................................................... 17

5. ELECTRICAL ..................................................................................................... 28

6. OPERATION AND MAINTENANCE REQUIREMENTS .................................... 29

7. INSPECTION AND TESTS ................................................................................ 30

8. ANNEXES .......................................................................................................... 33

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1 GENERAL

1.1. The gas turbine shall be standard combustor aero-derivative or light industrial type. The package shall be designed for minimum 25 years of operation installed on a fixed platform or on a FPU (Floating Production Unit).

1.2. The gas turbine shall be capable, for continuous running duty basis, at site rated conditions after all the mechanical losses for the complete set and the inlet and exhaust losses including air inlet filter and degradation losses for ageing and fouling. Site rated conditions for the gas turbine performance design shall be considered as 30oC ambient temperature, sea level and off-shore tropical environment (80% relative humidity, 1 atm).

1.3. Turbocompressor to be installed in a classified area. Fresh cooling water temperature available 35o C, maximum outlet temperature 55oC and ambient temperature: 14oC minimum / 25 o C mean / 35 o C maximum.

1.4. Centrifugal compressor for CO2 Turbocompressor package units shall be in accordance with API std 617, last edition. Centrifugal compressors for CO2 Turbocompressor package units shall also comply with the additions to, or modifications of API std 617, 7th edition, described in “Annex B” and Comments and Deviations to API 617, described in “Annex D”.

1.5. Gas Turbine for CO2 Turbocompressor package units shall be in accordance with API std 616, last edition.

1.6. Common driver for different compressors services (i.e. between Main, Gas-Lift / exportation, Injection and CO2) is not acceptable.

1.7. PACKAGER shall consider all documents listed in Material Requisition as mandatory. Electrical, automation and safety requirements for CO2 Turbocompressor (package unit) are described in this document.

1.8. All components of the system shall be suitable for offshore environment, throughout the whole platform service life, under all operational conditions and submitted to Unit motions and accelerations described in PURCHASER specifications.

1.9. PACKAGER shall be entirely responsible for material selection on items not specified by PURCHASER and shall inform material of all main parts according to ASTM code. All bolts and nuts shall be supplied with PACKAGER certificates and fully marked according to applicable ASTM standard.

1.10. All shop punch lists shall be cleared before shipment. 1.11. Equipment shall be prepared for outdoor storage according to PURCHASER

specifications. 1.12. PACKAGER shall specify the products to be used for preservation of the

equipment components and spare parts, their removal and reapplication methods and the application date. Such data shall be summarized on two tags to be securely fastened on all equipment and outside of each crate. If rust preventives be required, volatile products shall not be applied.

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1.13. Hazardous and toxic materials with associated adverse health effects shall be avoided or minimized. PACKAGER and sub-suppliers are encouraged to promote their replacement. Asbestos has been identified as detrimental to human health, especially regarding serious and often fatal diseases such as lung cancer, asbestosis and mesothelioma. Therefore, it shall not be used in the materials and equipment supplied for this project or for this plant or facility. As the use of such materials will not be tolerated, PURCHASER strongly recommends PACKAGER and sub-suppliers to take all necessary measures to ensure their use is fully avoided throughout this project. Material safety data-sheets may be required by PURCHASER any time, to demonstrate that a particular material has not been, is not and will not be used throughout all stages of this project.

1.14. Gas Turbine ignition system shall not have radioactive components. 1.15. All equipment, components and panels shall have a nameplate easy to access, to

view and read. Nameplate shall be made in AISI 316 stainless steel and bolted (with stainless steel elements) to the equipment. Layout drawings shall be submitted to PURCHASER approval. Nameplates shall contain the following information, in Brazilian Portuguese language:

• Client name; • Client job; • Client area; • Supplier name; • Series number and model; • Year of manufacturing; • Main design and test data:

pressure, temperature, voltage, rotation, etc.;

• Specific data; • Tag number; • Purchaser’s requisition number

(RM); • Purchaser’s request for quotation

number (RFQ); • Purchaser’s order number (PO); • Empty weight; • Design code.

1.16. All safety signals shall be in Portuguese language.

2 CONSTRUCTION FEATURES 2.1 Aero-derivative or light industrial per API 616, latest edition (with agreed

deviations), manufacturer’s standard combustor, gas fuel configuration, complete with protective bag and transportation stand. Power turbine, if applicable, may be industrial or aero-derivative type.

2.2 Gas turbine design shall enable boroscope inspection of hot gas path and blading, fitted with dedicated plugged holes at the combustion chambers, transition pieces, first and last stage of air compressor, gas generator and power turbine.

2.3 The gas turbine shall be able to restart at any time after an indeterminate period of time with no auxiliary AC power. PACKAGER shall provide all auxiliary systems located within PACKAGER limits, to comply with this requirement and submit them to the PURCHASER in clarification phase, before proposal phase. PURCHASER will not guarantee any facility during time without AC power.

2.4 Devices to sample collection shall be foreseen for analysis of exhaust gases emissions from the gas turbine.

2.5 Centrifugal compressors shall be radialy split case (barrel type) in accordance with API std 617 last edition.

2.6 Compressor tie-bolt type impelers are not acceptable.

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2.7 Compressors with sidestream are not acceptable. 2.8 PACKAGER shall make all efforts in order to select a compressor with none or

less recirculation as possible. 2.9 Compressor and gearbox bearings shall be hydrodynamic tilting pads type. 2.10 Preferably the turbocompressor train shall use one gearbox only. If necessary,

the use of a second gearbox is acceptable provided that dimension limitations for turbocompressor train be accomplished.

2.11 All bearings shall be designed to minimize oil foaming and prevent oil whirl at any operating speed.

2.12 The compressor train center-line is oriented in the fore/aft direction in case of installed on a FPSO (Floating Production Storage and Off-loading).

2.13 Compressor connections and nozzle flanges shall be provided by removable spools to facilitate compressor remove and disassembly.

2.14 Grayloc type flanged connections are not acceptable. If non-standard flanges are approved by PURCHASER, respective companions shall be supplied. Sections nozzles shall be rated to the same class. Studded or Flanged connections are acceptable.

2.15 PACKAGER shall consider all operational cases, gas compositions and corrosive components content (H2S and CO2) for the compressor materials specification. PACKAGER shall also consider the compressor non running, cold and pressurized (with process gas) conditions and the presence of free water (even when not specified in the gas composition).

2.16 The highest compressor bearing surface metal temperature shall not exceed 100o C (212o F) at any operating condition including during MRT at maximum continuous speed

3 ACCESSORIES AND AUXILIARIES

3.1 Piping

3.1.1 Except where indicated, all piping and accessories within equipment package limit shall be in accordance with PACKAGER piping specification and international standards.

3.1.2 All auxiliary piping requiring field connections shall be brought to the skid edge and shall be flanged.

3.1.3 Manual block valves and spectacle / blind flanges shall be provided at all battery limits such as inlet and outlet nozzles, drain lines, etc. . PACKAGER considering piping standards as in I-ET-3010.1M-1200-200-P4X-001 – PIPING SPECIFICATION FOR TOPSIDE.

3.1.4 All equipment shall have sufficient flexibility in all pipe and duct connections. 3.1.5 The interconnecting pipework between auxiliary skid and the main

baseplate shall be provided by PURCHASER. 3.1.6 A temporary basket particulate filter for machine starting, removable without

disassembly of the piping, shall be installed in the suction line, close to each stage of compression.

3.2 Couplings and coupling guards

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3.2.1 PACKAGER is responsible for all couplings within the package, including those for auxiliary equipment.

3.2.2 Coupling for main equipment shall be a stainless steel flexible-element, non-lubricated type.

3.2.3 PACKAGER shall submit to PURCHASER main equipment coupling data sheet according to API 671.

3.2.4 All coupling guards (including those for auxiliary equipment) shall be rigid, fully enclosed, in non-sparking material and solely fitted to equipment baseplates, not fastened. Safety coupling guards (without feet) are also acceptable. In case of failure, guards shall be able to retain broken parts, for personnel protection. Coupling guards shall be designed to allow removal without disassembling the coupling and shall be constructed so that routine inspections are performed by means of strobe light, with the equipment running.

3.2.5 Coupling guard drains shall have sight glasses in horizontal drain lines. The coupling guard shall not be used as a normal operating lube oil drain path.

3.3 Baseplate

3.3.1 Main baseplate shall be capable of supporting the stresses arising from platform motions and shall be provided with three (3) point supports and Anti-Vibration Mounting (AVM).

3.3.2 Baseplate shall be rigid enough to avoid permanent distortion during lifting, shipment and operation. When the baseplate is lifted, with all equipment mounted, beam deflection shall not exceed L/400 (L is the total baseplate length).

3.3.3 Driver, driven machine and transmission shall be mounted on a single baseplate. Other auxiliaries shall be mounted on the same baseplate (preferable) or provided with their own skid. PACKAGER shall submit layout to PURCHASER comments and approval.

3.3.4 The baseplate shall have a removable solid checkered plate or open grating top floor where required for maintenance.

3.3.5 All furnished skids shall be sufficiently stiff to withstand all vibration loads induced by the equipment and transfer them to the deck beams.

3.3.6 Skid mounted assemblies shall be constructed in order to not require equipment or parts to be dismounted for lifting.

3.3.7 No equipment / component shall protrude beyond the skid limits. In cases where it cannot be avoided, required protection against mechanical damage shall be provided.

3.3.8 Each skid shall be provided with facilities (pad-eyes, lugs, bollards and spreader bar) for lifting, having suitable access for rigging. The estimated lifting load and safety factor for each point shall be informed in PACKAGER proposal. Main lifting points shall not be welded to the beam flange, unless the strength level is low enough or if the beam flange has a suitable thickness.

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3.3.9 All equipment to be mounted on skids shall allow on-field leveling and alignment using jacking screws (in both plane directions) and precision type shims. Total shim thickness shall not exceed 6.35mm and the number of shims shall be kept to a minimum. Any additional height shall be made up of solid stainless steel plate.

3.3.10 All skid mounted equipment containing liquids that shall be drained onto the skid area, shall be fitted with drip pan underneath the equipment and provided with flanged nozzle with sufficient slope. Drip pans draining system shall be designed considering the total deluge flow over the skid. A single drain nozzle shall be located at the skid edge with appropriate piping, blocking valve, strainer and water seal.

3.3.11 Fasteners (including washers) and shims shall be constructed in AISI 316L stainless steel.

3.4 Support system

3.4.1 All required supporting system (including spring supports, structure, etc.) shall be supplied (for on-skid elements) or specified with all design requirements (such as loads, position, forces, etc.) by PACKAGER.

3.5 Insulation

3.5.1 All required insulation for personnel protection or machine thermal efficiency shall be applied and provided by PACKAGER.

3.5.2 Insulating shall ensure a temperature below 60˚C over the external surface for personnel protection.

3.5.3 To prevent corrosion under insulation, only non hygroscopic insulation material shall be used.

3.5.4 In order to avoid damages during transportation and erection, insulation shall be carried out after final installation in place.

3.6 Oil system

3.6.1 An independent synthetic oil (lube and control) console shall be designed per API 614 latest edition (with agreed deviations) to supply lubricating oil to gas generator. Control system, shall includes twin filters with changeover valve, duplex plate type heat exchanger and temperature control valve, 316L stainless steel reservoir and piping, vent mist eliminator and all necessary on-skid instrumentation, valves, piping, wiring, controls and transmitter rack preferably installed on main equipment baseplate.

3.6.2 An independent mineral oil (lube) package shall designed per API 614 latest edition (with agreed deviations) to supply lubricating oil to the power turbine (if applicable), gearbox and driven equipment under all FPU vessel motions for continuous satisfactory operation, preferably installed near main equipment baseplate, and shall includes twin filters with changeover valve. Other oil system configuration shall be submitted to PURCHASER approval, but shall follow the philosophy described on project documents concerning dual auxiliaries, instrumentation, alarms, etc.

3.6.3 Special consideration shall be given to the presence of dirt, debris and any foreign matter in sensitive parts (bearings, for instance). Provisions shall be made for by-pass of sensitive parts while system flushing operations are performed.

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3.6.4 PACKAGER shall propose its standard oil system configuration and inform all data and characteristics of electric load (as power, source, etc.) for each pump driver, heater, etc. in proposal phase. PURCHASER will furnish electrical utilities required by PACKAGER, considering platform available voltages as stated in I-ET-3010.00-5140-700-P4X-003 – ELECTRICAL REQUIREMENTS FOR PACKAGES FOR OFFSHORE UNITS.

3.6.5 Emergency system shall have rundown tank or shaft driven pump. Proposed system shall have enough capacity for bearing cooling during cost-down time and shall be monitored with PACKAGER specifications and international standards. DC pumps (125Vdc) are acceptable as an option to the shaft driven pump, since all accessories and auxiliaries (including accumulator batteries and batteries chargers) are provided. Accumulators batteries and batteries chargers shall be optimized for entire system and shall have full redundancy.

3.6.6 PACKAGER shall provide sampling points for oil analysis at reservoir, supply manifold and oil return line of each equipment. Sampling facilities shall be permanent, fitted with valves installed in T-type connections, oil spill and drip collectors and spillback lines to be routed back to oil reservoir. Sampling arrangement shall enable samples taken during operation.

3.6.7 All piping and appurtenances downstream oil filters shall be made of AISI 316L stainless steel.

3.6.8 Socket welds for piping and tubing is prohibited. 3.6.9 Reservoirs:

• Reservoir shall be provided with filling connections (with filter), level indicator sight glass, antifoaming devices, accessible manholes, valve drain at skid edge and include provisions for nitrogen purges.

• All return lines shall be top entry type, extending inlet duct inside the reservoir to below minimum operating level in order to avoid foaming.

• Reservoir shall be designed to facilitate air separation between the bearing return and pump supply.

• Vents shall be fitted with oil vapor separator in order to recover oil due to evaporation losses and environmental protection (PACKAGER shall guarantee maximal oil losses of five (5) ppm). Vents shall be dimensioned with the same size as the oil return header, at least.

• An electric lube oil heater shall be provided, interlocked with a low-level and oil temperature control. This device shall be designed to facilitate removal without having to drain the reservoir or stop the equipment.

3.6.10 Oil coolers shall be multi-plate duplex type oil/fresh water or oil/air heat exchanger with temperature control valve. The material shall be AISI 316L stainless steel, if closed loop cooling water system is provided by PURCHASER. Cooler shall have provision for future increase of the number of plates. The cooling water pressure shall always be lower than oil pressure at heat exchanger interior.

3.6.11 The canisters, transfer valves and piping for oil filter system shall be 316L stainless steel construction. Filter element material shall be corrosion and water resistant. There shall be no by-pass around any filter.

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3.6.12 The expected configuration for pumps are: • Main oil pump: Shaft-driven (preferable) or electric motor driven (AC

power); • Stand-by pump: Electric motor driven (essential AC power).

3.6.13 Batteries voltage (analog signal 4-20mA) and battery bank voltage low voltage alarm (hardwired signal) for remote monitoring will be provided by PURCHASER and shall be available on HMI.

3.6.14 For non shaft-driven pumps, the main and stand-by pumps shall be identical. In all cases, stand-by pumps shall have the same capacity as the main pump.

3.6.15 API data sheets for pumps and heat exchangers shall be included in proposal.

3.6.16 All oil vents shall be interconnected, fitted with flame arrestors and routed to a safe area. All oil drains shall also be interconnected and routed to oil reservoir.

3.6.17 PACKAGER shall provide all data of oil system equipment and fluid as oil consumption, oil complete specification and filter elements life.

3.7 Gearbox

3.7.1 If required, the gearbox shall be double helical, single stage designed in accordance with API613, Latest Edition (with agreed deviations) It shall be included a device to allow manually rotation of the shafts for maintenance purpose (such as shaft mechanical alignment or boroscope inspection).

3.7.2 Gearbox shall be designed as a “stand-alone” unit, whereby no external thrust loads shall be imposed upon the gearbox by other equipment.

3.7.3 The use of one or two gearboxes shall be defined by vendor. However dimension limitations for compressor package defined on I-FD-3010.1M-1254-321-P4X-001 - CENTRIFUGAL COMPRESSOR FOR CO2 TURBOCOMPRESSOR must be accomplished.

3.7.4 Shaft oil seal shall be easily accessible for removal and re-installation without removing couplings.

3.7.5 All bearings shall be pressure lubricated and fully replaceable at field. 3.8 Pressure vessels

3.8.1 In order to avoid categorizing of any pressure vessel (and heat exchanger, where applicable) according the requirements of the Brazilian Labor Ministry regulation NR-13, when possible, the product of pressure (in mega Pascal) multiplied by the volume (in cubic meters) of any equipment shall be lower than 8. Where applicable, NR-13 calculation sheets and specific nameplates shall be provided.

3.8.2 For nozzles less than 2” in nominal diameter, forged steel couplings may be used. Couplings shall be at least class 6000#, for socket weld.

3.8.3 All nozzles having a nominal diameter of 2” or greater, shall be flanged, except when specified for butt weld in the piping.

3.8.4 The minimum nominal diameter of nozzles intended for any purpose shall be 3/4”.

3.8.5 Only full penetration welds are permitted.

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3.8.6 All shell reinforcements, integral or not, shall always have the same shell P-number.

3.8.7 The minimum degree of radiographic examination for weld inspections according table UW-12 shall be full or spot.

3.9 Enclosure

3.9.1 Each gas turbine shall have its own enclosure. 3.9.2 Enclosures shall consist of a series of removable panels and doors

supported on a heavy duty frame. The enclosure shall be fabricated and bolted so that it can be completely disassembled. Roof sections shall also be removable.

3.9.3 Enclosure shall be weather-tight. 3.9.4 Joints between panels, skid, floor, piping, ducts, cabling and shaft

penetrations shall be properly sealed to prevent noise propagation, ventilation problems and for safety according to PURCHASER requirements.

3.9.5 Enclosure shall be provided with wide full-opening side doors to allow adequate maintenance access, assembly and disassembly of all parts of the equipment. Hinges shall be strong enough to withstand constant use and wear.

3.9.6 Enclosure doors shall be fitted with lockable handles and, in service, these doors shall be kept locked. Enclosures shall be fitted with open door alarm devices. PACKAGER shall provide anti-panic catches in order to open the doors anytime from inside. Door locations shall be clearly marked, both inside and outside the enclosure.

3.9.7 Access doors shall be fitted with viewing windows. 3.9.8 Enclosure shall be provided with inspection and internal lighting, adequate

for each maintenance service area. 3.9.9 PACKAGER shall provide electrically driven lifting / handling devices and

internal structure components enabling assembly, disassembly and removal all components inside the enclosure with adequate and certified capacity to handle maximum maintenance weight and / or dimensions.

3.9.10 Ventilation system

• PACKAGER shall propose your standard ventilation system configuration and inform all data and characteristics of electric load (as power, source, etc.) for each fan driver. PURCHASER will furnish all electrical utilities required by PACKAGER, considering platform available voltages as defined in I-ET-3010.00-5140-700-P4X-003 – ELECTRICAL REQUIREMENTS FOR PACKAGES FOR OFFSHORE UNITS;

• PACKAGER shall be responsible to furnish complete enclosure ventilation system, proper for area specification, including all ducts, inertial type vane separator (inlets), coalescent filter (inlets), fire dampers (inlets and outlets), fans, drivers and actuators;

• The enclosure ventilation shall be positive pressure type;

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• At least two full-capacity (2x100%) ventilation fans shall be provided for the gas turbine enclosure. DC motors shall not be used;

• During ESD event, the ventilation fan and all auxilliaries electrical loads shall be supplied by essential AC power;

• The rated electrical power of the ventilation fans shall not exceed 55 kW;

• Fan must be sized to prevent the inside enclosure temperature from exceeding 60°C. Higher temperature may be accepted, if PACKAGER guarantees safety conditions for all equipment functionality;

• The air shall be filtered before reaching the fans and the enclosure;

• The necessary airflow rate shall be calculated and informed by PACKAGER according international standards;

• The control of the ventilation system shall be included at unit control panel.

3.9.11 Fire and gas detection and high pressure water mist fire extinguishing systems shall be designed in accordance with NFPA 750, IMO-SOLAS and I-ET-3010.00-5420-300-P4X-001 – FIRE PROTECTION FOR MACHINERY HOODS. The systems shall be provided complete with audible and visual warning indicators. Fire extinguishing skid may be provided loose for mounting by others. Back up nitrogen bottles shall be applied. The selection of main or back up nitrogen bottles can be carried out by manual valves.

3.9.12 No enclosure is required for gearbox and compressor if the required noise level is achieved.

3.9.13 Enclosure material, bolts, fasteners, nuts, door hinges, locks, latches and ventilation system shall be AISI 316L stainless steel.

3.10 Starting system

3.10.1 The starting system shall be capable of three starts within a one hour period, at least. PACKAGER shall inform the maximum allowable number of starts per hour and the minimum interval between two consecutive starts.

3.10.2 Gas turbine starting system shall be carried out by means of an electric or electric-hydraulic motor.

3.10.3 Driver torque, power, inertia, maximum speed and all starting system requirements and control methods (including acceleration curves, temperature limits, etc.) shall be submitted to PURCHASER during proposal phase.

3.10.4 For electro-hydraulic system, hydraulic part shall be mounted on a small skid immediately adjacent to the baseplate. For electric motor, all system shall be placed inside baseplate. For electric motor and electro-hydraulic system, PACKAGER shall supply electronic soft starter or variable speed drive (VSD) to control of voltage drop and shall comply with I-ET-3010.00-5140-700-P4X-002 - SPECIFICATION FOR ELECTRICAL MATERIAL AND EQUIPMENT FOR OFFSHORE UNITS.

3.10.5 The starting system shall be semiautomatic and controlled from the unit control panel.

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3.10.6 The starting system design shall allow occasional rotation of turbine after shutdown or when not in operation for sustained periods.

3.10.7 The starting sequence shall include sufficient cranking time to purge the exhaust duct system according to API 616.

3.10.8 The starting system shall be able to support off-line cleaning procedure. 3.10.9 In case of an ignitor transformer be necessary, it shall comply with I-ET-

3010.00-5140-700-P4X-002 - SPECIFICATION FOR ELECTRICAL MATERIAL AND EQUIPMENT FOR OFFSHORE UNITS, and PACKAGER shall provide these equipment.

3.11 Fuel system

3.11.1 The fuel system shall include all necessary equipment, instruments and controls for a complete, safe and operable system.

3.11.2 PACKAGER shall confirm acceptance of fuel specified by PURCHASER and clearly state any deviation from specifications and its consequences during the proposal phase, indicating the maximum and minimum variation in each characteristic and / or component.

3.11.3 Control system shall automatically purge trapped fuel gas in order to assure minimum allowable temperature and free-moisture before start-up.

3.11.4 Fire safe block and drain / vent valves outside the enclosure shall isolate the skid from gas fuel supply during fire shutdown. The respective valve assemblies shall be shipped loose.

3.11.5 All fuel system equipment shall be located near the turbine enclosure. 3.11.6 Gas fuel system:

• System shall include dual shutoff valve, vent, bleed and all piping and appurtenances required by international standards, PACKAGER experience and for compliance with Classification Society’s requirements.

• PACKAGER shall furnish a single fuel strainer upstream the fuel package connection point. Gas filter shall be selected for maximum service life (PACKAGER shall indicate this data in proposal).

• Fuel gas coalescer unit is to be installed immediately upstream of the skid fuel gas blocking valve and shall be fitted with a PSV (if required), a continuous flow transfer valve, pressure transmitter, automatic liquid dup facility and level gauge.

• All on-skid fuel piping components and tubing for gas fuel shall be 316L stainless steel.

3.12 Gas turbine cleaning system

3.12.1 PACKAGER shall provide one combined on-line / off-line gas turbine cleaning system with mobile wash water trolley provided with lifting facilities, wheels and brakes. The cart wheels shall have proper locking device to prevent motion.

3.12.2 Equipment shall include a pressurized reservoir with filling, venting and drain connections.

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3.12.3 Requirements for detergent, demineralized water and other utilities (if applicable) shall be specified by PACKAGER and submitted to PURCHASER.

3.12.4 PACKAGER shall inform which parameters are used to define the interval (fired hours) between cleaning operations.

3.12.5 All necessary instrumentation and equipment for a complete, safe and operable cleaning system shall be provided as PACKAGER standard.

3.12.6 PACKAGER shall furnish hoses shipped loose, in accordance with PURCHASER information about distances.

3.12.7 All parts in contact with water shall be in 316L stainless steel, including hose assemblies.

3.12.8 Two tanks shall be provided, one for the water/detergent mixture and one for pure water. Two single tank carts are acceptable instead of one cart with two tanks per FPU.

3.13 Combustion air inlet system

3.13.1 Combustion air inlet system shall include, at least: rain protection with trash screen, weather protection louvers, filter housing, four-stage filter, air intake silencer, all duct sections, support structure, all required mounting parts, plenum chamber and expansion joint and internal AC lighting, complete with lighting switch certified for hazardous area (Ex de).

3.13.2 The air filter system shall be assembled in four-stage and must have high efficiency to remove inlet salt water droplets and filtering dry particles from the air stream. Its shall be designed to cover all operating conditions.

3.13.3 The configuration of air filter system shall be at least: • The first stage shall be filter wall or inertial separator with salt water

drainage collector and to sloped rainwater. It shall be stage-vane separator type in stainless steel AISI 316L;

• The second stage filter coalescers or prefilter range shall pockets type. The pockets shall be self-supporting, welded and foam-sealed to frame complete with welded in spacers for mechanical strength. Class G – 4 according to EN 779. The filter elements standard sized shall be 595 x 595 mm wide. The filter support racks shall in stainless steel, AISI 316L;

• The third stage shall be identical to the first stage; • The fourth or the final stage high efficiency filters shall be a high-

efficiency filter. The filter elements standard sizes shall be 595 x 595 mm wide, double flanged class F - 9 according to EN 779 classification, moisture-resistant up to 100% relative humidity. The filter support racks shall in stainless steel, AISI 316L;

• Differential pressure monitoring on each and overall stages on control panel.

3.13.4 Threaded fastenings shall be wired locked. All components downstream of the last filter shall be constructed with continuous welding and designed to withstand all forces generated at the maximum allowable air intake shutdown differential pressure.

3.13.5 All inlet air system components shall be in AISI 316L stainless steel. Hard points to be provided on the house for mounting to the FPU structure.

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3.13.6 Air Inlet Module, shall include, inlet ducting, inlet silencer and acoustic insulation. Inlet plenum orientation vertical upwards. Material unpainted 316L stainless steel. A door and internal ladders shall be provided for easy and safe personnel access to the gas turbine inlet plenum for maintenance procedures (visual inspection and cleaning).

3.14 Combustion gas exhaust system

3.14.1 Shall be oriented vertically upwards including, exhaust diffuser, transition piece, expansion joint and silencer. Hard points are provided on the silencer for mounting to the FPU structure.

3.14.2 Exhaust system vertical stack height shall be confirmed / updated later by Detail Design.

3.14.3 Exhaust system shall be fitted with all necessary pressure safety valve, pressure and temperature transmitters, vent and drain valves as required by PURCHASER and according to PACKAGER experience.

3.14.4 The exhaust silencer shall also incorporate lifting provisions. 3.14.5 Construction materials: 409 or 321L stainless steel for silencer hot gas path;

casing/ducting per manufacturer standard depending upon hot or cold casing construction. All expansion joint supports shall be in 316L stainless steel.

3.15 Dry Gas Seal (DGS) system

3.15.1 DGS system shall be prepared, calculated and detailed by PACKAGER for all operating and utilities conditions (including start-up, normal and emergency shutdown, settling-out, minimum instrument air pressure, etc.).

3.15.2 PACKAGER shall furnish all technical details about DGS system during proposal phase, including seal leakage detection method.

3.15.3 PACKAGER shall include in proposal a reference list showing his experience with proposed DGS system, highlighting the units with similar services.

3.15.4 DGS system shall always assure that the seal gas pressure is positive in relation to the balance line pressure for all conditions (pressurizing, starting, operation, normal and emergency shutdown, during depressurization or when stopped pressurized – settling-out), except when compressor is stopped and depressurized.

3.15.5 DGS system shall be bi-directional tandem gas seal cartridge for each shaft end, with the following configuration: • Primary and secondary seals rotating faces material shall be made of

silicon carbide, at least. PACKAGER shall use the conditioned discharge process gas as primary seal gas supply and Nitrogen as secondary seal gas supply;

• The buffer gas for the barrier seal shall be Nitrogen or instrument air; • Separation seals shall be carbon ring non-contacting type. The purge

medium for carbon rings shall be Nitrogen and shall result in a lean gas mixture on secondary seal vent line;

• Where different seal designs or pressure ratings are employed in adjacent casings on the same compressor package, the seal cartridge shall be designed to prevent the incorrect mounting in different casings.

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3.15.6 PACKAGER shall provide a dedicated seal gas panel for each compressor casing.

3.15.7 All PSV and check valves on venting piping, downstream each seal, control valves and other necessary valves for DGS system shall be provided by PACKAGER.

3.15.8 All lines connected to flare system shall be capable to be isolated for maintenance of upstream equipment/accessories by means of an isolation valve (locked open) supplied by PACKAGER.

3.15.9 PACKAGER shall supply the DGS system fully fitted with piping and support on main equipment baseplate.

3.15.10 All compressor DGS system piping, valves (including internals), filter bodies and fittings shall be made from 316 stainless steel.

3.15.11 All piping, valves and fittings shall have insulation and / or heating, where applicable.

3.15.12 PACKAGER shall make the necessary provisions to guarantee uninterruptible Nitrogen supply to the compressors sealing system in order to assure a safe shutdown (any case) of all compressor units. A Nitrogen coalescer filter (2x100%) with automatic drain level control shall be provided at each seal gas panel with online changeover capability.

3.15.13 A dual fine mesh coalescers filters (2x100%) with automatic drain level control shall be provided at each seal gas panel with online changeover capability to guarantee a clean and dry seal gas. The automatic drain shall avoid the possibility of back-flow.

3.15.14 DGS system shall be provided with all control, monitoring and safeguarding instrumentation, including monitoring primary vent by pressure or flow (trip) and secondary vent by pressure (alarm only) to identify DGS damage.

3.15.15 PACKAGER shall supply any pressure control valves if necessary to guarantee minimum back-pressure at DGS primary vent line.

3.15.16 A seal gas conditioning system shall be furnished by DGS supplier and shall be designed to remove all particles and liquids from the compressor discharge gas. This conditioned gas will supply primary seal, avoiding any kind of failure. PACKAGER shall guarantee a clean gas flow, at least 20ºC above its dew point and a pressure 15 kPa higher than compressor reference gas pressure. The conditioning skid shall include as a minimum: • Twin filter arrangement (2x100%) for solids retention; • A dual cartridge filter (2x100%), shall be supplied with automatic drain

control and on-line changeover capability; • A dual separator / coalesce filter (2x100%), shall be supplied with

automatic drain control and on-line changeover capability; • Automatic pressure booster (2x100%) shall be provided, for

unpressurized discharge conditions. PACKAGER shall offer AMPLIFLOW or other similar device subject to PURCHASER approval;

• Heat exchanger system (2x100%), with on-line changeover capability and electric heater shall be installed;

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• The seal gas conditioning system components shall be furnished according to the sequence stated above (filters, booster and heat exchangers);

• PACKAGER shall provide a dedicated seal gas conditioning skid for each compressor casing mounted on the main baseplate. In case of pneumatic booster construction type, seal gas migration to the booster drive shall be avoided and vice versa;

3.15.17 The seal gas conditioning system logic control shall be designed to ensure a safe and reliable operation for each compressor casing mounted on the main baseplate for all operating conditions (pressurizing, starting, operation, normal and emergency shutdown, during depressurization or when stopped pressurized - settling out), except when compressor is stopped and depressurized

3.15.18 In order to minimize the DGS system footprint, PACKAGER may propose keeping all the appurtenances described above a solution integrating the seal gas panel with the seal gas conditioning skid to be submitted in the technical proposal to PURCHASER´s approval.

3.15.19 Drains shall be provided for all seal lines, including primary and secondary vent lines, drains shall be placed in proper position.

3.16 Pressure Relief and Drainage

3.16.1 The seal and sealing system design shall withstand the 1.2 PSV set pressure value, as minimum, from compressor suction vessel according to the P&IDs.

3.16.2 PACKAGER shall inform maximum allowable pressure for each shaft-end seal casing. PACKAGER shall provide all necessary means to perform a partial or full depressurization to flare.

3.16.3 O-ring design including material selection shall be sufficiently resistant to explosive decompression taking in account pressurization rate according API 521, large number of compressor start and stops and the minimum time between overhauls required by API and ISO 23936-2.

3.16.4 Drains with valves shall be provided for all compressor stages (impeller-diaphragm cavity), placed in proper position. The drain header shall also be provided with valve in order to configure a drain with double block to closed and opened drain. In case individual stage drains cannot be provided due to design limitations, it shall be demonstrated during the proposal phase (by means of drawings) that all inner parts will have an effective drainage. Drain arrangements shall provide visual access and sight glasses in order to verify flow and leakage and to confirm whether the drainage operation is being accomplished or not.

3.16.5 Drains with valves shall be provided for all seal gas system, placed in proper position at battery limits. The drain shall be provided with valve in order to configure a drain with double block to closed and opened drain. Drain arrangements shall provide visual access and sight glasses in order to verify flow and leakage and to confirm whether the drainage operation is being accomplished or not.

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3.16.6 Coalescers filters drains (Gas Seal Panel and Seal Gas Conditioning System) with valves shall be provided for all seal gas system, placed in proper position at battery limits. The drains shall be provided with valve in order to configure a drain with double block to closed and opened drain. Drain arrangements shall provide visual access and sight glasses in order to verify flow and leakage and to confirm whether the drainage operation is being accomplished or not.

3.16.7 The connections between compressor casing, dry gas seal panel, conditioning seal gas system and seals shall be fitted with low point drains to enable liquid removal during start-up procedures.

3.16.8 PDITs associated with SDVs shall be able to indicate positive and negative values to avoid SDV opening when downstream pressure is larger them upstream pressure.

4 AUTOMATION 4.1 General requirements

4.1.1 Package Automation System (PAS) shall be designed to ensure safe and reliable operation, performing protection, control and monitoring during start-up, operation, normal and emergency shutdown. PAS shall be furnished functionally tested, assembled and ready for connection.

4.1.2 All instrumentation and alarms mentioned in the data sheets are the minimum required by PURCHASER. PACKAGER shall indicate other instrumentation and alarms for general protection and monitoring according to their experience and submit in technical to PURCHASER for approval.

4.1.3 PACKAGER shall provide a local gauge board (rack) installed on the equipment baseplate, as mentioned on data sheets. Oil filled gauges shall be provided for analogical instruments subject to high vibration levels.

4.1.4 PAS shall include all required components to ensure continuous monitoring, functionally tested, assembled and ready connection.

4.1.5 PACKAGER shall supply Unit Control Panels (UCP) shipped loose. UCP shall have IP-42 protection level and will be installed at the Automation and Electrical Panels Room (AEPR) by others.

4.1.6 The unit shall have a specific feature so that the equipment cannot be restarted without manual acknowledgement of the shutdown conditions.

4.1.7 All requirements for PAS shall be checked during Site Acceptance Test, according to IEC 62381.

4.1.8 Package shall be considered as P2S type, according to Technical Specification I-ET-3010.00-1200-800-P4X-002 - AUTOMATION, CONTROL AND INSTRUMENTATION ON PACKAGE UNITS and to I-ET-3010.1M-1200-800-P4X-014 – AUTOMATION INTERFACE OF PACKAGE UNITS.

4.1.9 PACKAGER shall provide to PURCHASER all keys, drivers, manuals, installation media and licenses of all software inside package. No software access restrictions will be accepted by PURCHASER.

4.1.10 PACKAGER shall make the necessary provisions for interconnections to be installed by others, if necessary for main equipment operation and safety, including instrument signals, alarms, controls and interlocking, etc.

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4.1.11 PACKAGER will be responsible for all required control and interlocking interface with the process plant outside its scope of supply, in order to guarantee the proper start-up, operation, pressurized and depressurized shutdown.

4.1.12 Proper means of electrical and environmental protection shall be applied to instruments and instrumentation-related electrical/electronic installations located in hazardous areas and/or an aggressive saline air environment. In order to guarantee adequacy to IEC-61892-7, all field instruments and other electrical instrumentation equipment installed in open areas shall be certified to operate in Zone 1. Certified enclosures against explosive atmosphere are mandatory. Remote I/O panels shall be made of AISI 316 stainless steel and installed in shelters protected from rain and wind in the respective compression modules. The panels shall have IP56 protective level and the panels internal temperature shall be kept bellow 30 degrees centigrade

4.2 UCP hardware

4.2.1 Each equipment package shall have its own UCP, with monitoring and control functions for all equipment (driven machine, driver, transmission and auxiliaries). Each UCP shall operate independently, so a failure of any component within a UCP does not affect the availability of any other UCP.

4.2.2 The UCPs located at the AEPR shall have: • Frontal HMI; • Cable entry from the bottom of the panel; • Front access doors.

4.2.3 Each UCP shall include, at least: • One dedicated safety system and one dedicated control system, which

shall be implemented using Programmable Logic Controllers (PLC); • HMI hardware; • First-out and reset devices; • Main equipment and auxiliaries start-up and stop devices; • Sound alarm; • Start counter and independent hourmeter; • Machinery Protection System; • Fire and gas and HVAC control and Safety System.

4.2.4 The network switches shall be industrial manageable type. 4.2.5 Control and supervisory networks must be redundant.

4.3 UCP software

4.3.1 PAS shall enable changes of set points, timer presets and control parameters, forcing I/O via software, input by-passing, output override with the system in operation, without damage to the process.

4.3.2 The control system programming and configuration shall be carried out by the UCP or additionally through a laptop computer (not provided by PACKAGER). The software editor shall be provided by PACKAGER.

4.3.3 HMI software (with runtime and development licenses) shall be provided.

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4.3.4 Access to configuration and programming shall be protected by change management tools, including specific passwords with several levels, such as: general, operation, maintenance and engineering. All passwords shall be delivered to PETROBRAS with NO access restrictions.

4.3.5 The control system programming shall be in accordance with PACKAGER specification. PACKAGER proposal shall inform the programming language used in the system.

4.3.6 The alarm annunciator units shall comply with IEC-62682, according to the sequence F2M-1 (manual reset first out with no subsequent alarm flashing and silence pushbutton. Alarm Management Systems shall comply with IEC-62682).

4.4 UCP system

4.4.1 The equipment UCP shall be capable of carrying out control, interlock, process, start-up, shutdown, normal operation and safety procedures for main machinery and auxiliary equipment, including all the necessary interfaces to connect with remote I/O, machine Protection System (MPS), Motor Control Center (MCC) and other controls and PETROBRAS security systems, such as: Control and Safety System (CSS), Power Management System (PMS), Asset Management System (AMS) and Machine Monitoring System (MMS).

4.4.2 Emergency shutdown relay shall be provided to actuate directly on the fuel gas shutoff valve and process plant SDVs.

4.4.3 The ESD from push buttons, PSD (Process Shutdown System), over speed and MPS, shall actuate the emergency shutdown relay and be used as input for UCP safety PLC.

4.4.4 Control system shall not allow undesirable nor unsafe operations. 4.4.5 UCP shall include, at least, the following functions:

• Automatic and manual start-up, loading, normal / emergency stop, purge and shutdown sequences without causing any damage to equipment or process instability;

• Interface for monitoring, recording and configuration for performance, Load sharing and Surge control systems. This interface shall be capable of recording surge events and may be implemented in the HMI of the UCP or in a dedicated HMI for each compressor service. This HMI shall also present PI&D and performance maps of operating points indicated in the compressor datasheet. The folowing maps are required: Rc x Q (m3/h), Pd (bar) x Q (m3/h), Td (oC) x Q (m3/h), Hp (kJ/kg) x Q (m3/h), ηp (%) x Q (m3/h), Pot (kW) x Q (m3/h), Hp (kJ/kg) x Qm (kg/h), ηp (%) x Qm (kg/h), Pd (bar) x Qn (Nm3/d at 20oC and 1 atm);

• Indication and recording of unit malfunction / shutdown, event signals and all machinery sequences (such as start-up, normal stop, etc.);

• Monitoring and control of all variables, alarms and shutdown signals with UCP indication as described in PURCHASER specification (such as temperature, pressures, etc. indicated in P&IDs and data sheets);

• Indication of independent fuel consumption totalizer; • Independent hourmeter and starts counter (gas turbine);

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• Speed monitoring and control system (all shafts, excluding gear); • Gas fuel specific consumption flow in Nm3/h (corrected to PURCHASER

standard conditions at 1atm and 20ºC); • Monitoring and control of variable geometry system position; • Ignition and fuel monitoring and control (including fuel control valve

position); • Enclosure ventilation and fire & gas system monitoring and control; • Automatic on-line and off-line turbine cleaning system; • Independent hourmeter and starts counter (compressor); • Suction gas flow for each compressor stage in m3/h; • Suction and discharge stages pressure control; • Capacity, load sharing and anti-surge control integrated (so any

individual corrective action taken by one loop shall not degrade a response from other). Systems shall enable adjustment of control parameters and perform by-pass inputs automatically without causing process disturbances, keeping the plant in safe condition and providing alarms to the operator.

4.4.6 Interface for monitoring, recording and configuration for performance, Load sharing and Surge control systems shall be provided. This interface shall be capable of recording surge events and may be implemented in the HMI of the UCP or in a dedicated HMI for each compressor service, installed at Central Control Room (CCR). In case of a dedicated HMI, a fiber optic port shall be available in one of the UCPs of the compression system for this HMI interconnection. This interface shall sample variables in high speed (milliseconds), storing and displaying all analog and digital variables, alarms and events. This interface shall also present PI&D and performance maps of operating points indicated in the compressor datasheet and the distance from anti-surge control line. The following maps are required: Rc x Q (m3/h), Pd (bar) x Q (m3/h), Td (oC) x Q (m3/h), Hp (kJ/kg) x Q (m3/h), ηp (%) x Q (m3/h), Pot (kW) x Q (m3/h), Hp (kJ/kg) x Qm (kg/h), ηp (%) x Qm (kg/h), Pd (bar) x Qn (Nm3/d at 20oC and 1 atm). This system shall be capable to have a remote client station in order to allow remote monitoring of all signals based on TCP/IP connection. One additional Ethernet network card available for PURCHASER use purpose (remote monitoring connection) and at least five (5) licenses for remote simultaneous clients are required.

4.4.7 UCP shall be capable to send and receive signals to / from Control and Safety System (CSS) according to PURCHASER specifications.

4.4.8 PAS shall have high reliability, integrity and availability for operation in fail safe mode in order to avoid, whenever possible, an unnecessary shutdown or loss any process variable with safety function.

4.4.9 PAS shall include on-line testing and self-diagnosis facilities, in order to allow the maintenance technician identify failures, enabling corrective maintenance without causing unit shutdown and avoiding operation without any safety function.

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4.4.10 In case of power failure, system shall retain all programs and data as well as interface software for a minimum of six months, not being necessary to reconfigure the system after power restore. During a power failure, all outputs shall be automatically changed to their safe position.

4.4.11 Connectivity to external system through open communication protocols shall be MODBUS and OPC (Open Platform Communications) by Ethernet TPC/IP Protocol. All I/O variables, controllers (including performance, load sharing and surge) and first out events shall be available.

4.4.12 The UCP interface with AMS shall be as described in I-ET-3010.1M-1200-800-P4X-014 - AUTOMATION INTERFACE OF PACKAGE.

4.4.13 UCP shall have a Remote I/O panel as described in in I-ET-3010.1M-1200-800-P4X-014 - AUTOMATION INTERFACE OF PACKAGE.

4.5 Human Machine Interface (HMI)

4.5.1 HMI shall allow the operator to view and acknowledge alarms and trips, protections reset, status of each I/O and intermediate variables, software monitoring / modification, system configuring, first-out of alarms and shutdowns, list of set points and parameters, analog variables, variables performance and trend, recording of all relevant data and periodic reports, events, number of starts and operation hours, I/O forcing, by-pass of inputs and override of outputs.

4.5.2 The logs shall be CSV (comma separated values) standard in three (3) different report types: • Daily files of digital and analog variables with 1 second sample time and

three months storage; • Hourly files of digital and analog variables with 40 milliseconds sample

time and last five days storage; • Individual ESD files of digital and analog variables with 40 milliseconds

sample time and ten minutes storage time (six minutes before and four minutes after the occurrence of ESD or normal stop). The HMI shall maintain the last 200 individual files at least.

4.5.3 HMI shall comply, at least, with the following requirements: • Industrial microcomputer installed inside the panel housing; • One aditional Ethernet network port available for PURCHASER use

purpose (remote monitoring connection); • Panel-mounted LCD color touch screen display. The CPU shall be

independent from the display screen; • Data logging and event/variable recording and storing, including any

event, alarms, trips and digital/analog variables values historic for at least two months with sample time not greater than 1 second and dead band not greather than 1%;

• Listing of all incoming alarms chronologically in a directory and a user-defined actions with PLC timestamps up to miliseconds time resolution;

• Real-time measurements; • Display of equipment schematic layout;

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• Display all analog and digital variables from sharing controllers, machinery protection and machinery monitoring systems.

4.5.4 PACKAGER shall provide HMI supervisory software (runtime and development tool) running on Windows environment, compatible with the size of the application and in its latest version. Software shall be supplied, installed, configured in the HMI and provided with complete manuals / electronic media.

4.5.5 If, for any reason, HMI have some malfunction, the control system shall continue with all its function normally. PACKAGER shall provide a hardware interface (such as a laptop computer connection) in order to establish an external communication with PLC.

4.5.6 English and Brazilian Portuguese languages shall be used on all HMI screens installed on UCP.

4.5.7 Each HMI must be capable to allow operation of any compression train in this compression system.

4.5.8 HMI software must be compatible with OSI “Plant Information-PI” software. 4.5.9 One remote HMI for each compression service shall be provided, with the

same functionalities of the UCP HMI, to be installed at Central Control Room (CCR). This HMI shall be a 19" rack-mounted PC, shipped loose. A fiber optic port shall be available in one of the UCPs of the compression system for this remote HMI interconnection.

4.6 Machinery Protection System (MPS)

4.6.1 Machinery Protection System (MPS) shall be according to the API 670 latest revision.

4.6.2 Probe arrangement for driven equipment, gearbox and driver: • Radial vibration: Two (2) non-contact probes for each radial bearing (X-

Y signal). • Axial position: Two (2) non-contact probes for each axial bearing. For

gearbox an arrangement with two (2) probes on low speed shaft. • Keyphasor: One (1) phase reference transducer for every different shaft

speed. • Casing vibration: Two (2) accelerometers for gearbox casing (one (1)

over the input and one (1) over the output shaft centerline, near radial bearings); two (2) accelerometers for gas turbine (one (1) for GG and one (1) for PT at least).

4.6.3 Probes shall allow gap adjustment. 4.6.4 PACKAGER shall identify which type of temperature sensor is used for each

variable (bearing temperature, oil temperature, etc.). 4.6.5 Only where metal bearing temperature measure is not feasible, PACKAGER

shall propose a bearing oil outlet temperature gauge with the same alarm and shutdown signals as indicated for metal bearing temperature in data sheets.

4.6.6 Monitors shall be mounted on Unit Control Panel (UCP) at Automation and Electrical Panes Room (AEPR).

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4.6.7 All vibration and temperature protection systems shall be according Original Equipment Manufacturer (OEM) standards and API 670 compliant.

4.6.8 Each monitor channel shall be capable of continuously comparing the input signal to warning set points. The warning system shall comprise at least two (2) levels: alarm and shutdown. The exception is axial position monitor, for which shall be supplied with four (4) independent alarms and shutdown adjustable limits (two (2) for each direction).

4.6.9 The vibration signals (including displacement and accelerometers) of the whole train shall have an unfiltered output at the UCP (one per channel) for recording and maintenance purposes.

4.6.10 Each channel shall be supplied with an electronic configurable time delay to avoid activation of alarm during transient signals.

4.6.11 All wiring shall be protected by flexible conduits to a 316L stainless steel junction box (at skid edge), neatly routed to allow machine maintenance without damaging probes and wire leads.

4.6.12 Extension cables shall be armored. 4.6.13 Oscillator-demodulators shall be mounted in an intrinsically safe junction

box. 4.6.14 Paired channels (XY) from the two transducers mounted at each bearing for

radial shaft vibration monitoring shall be allocated at the same MPS IO card. 4.6.15 A controlled access set point multiplier function shall be provided with

actuation by an external contact closure with causes the alarm (alert) and shut down (danger) set points to be increase by integer multiple.

4.7 Machinery Monitoring System (MMS).

4.7.1 Besides the control and supervisory UCP system, Machinery Protection System shall be integrated in the Machinery Monitoring System (MMS) of the FPSO, provided by others, for maintenance purposes. PACKAGER shall provide interface cards installed in the Machinery Protection System to allow the interconnection with the MMS (software and hardware). All vibration signals (including displacement and accelerometers) shall be available with buffer signal output.

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• Aerothermodynamic (gas turbine): at least the following real-time performance maps (in SI units) including actual operating point: PT speed, GG speed, ambient temperature, specific fuel consumption and heat rate versus shaft power; Air flow, axial compressor outlet pressure and temperature, HP turbine outlet pressure and temperature, PT exhaust pressure and temperature, specific fuel consumption, heat rate, combustion chamber temperature and PT speed versus GG speed; Exhaust pressure and temperature versus PT speed; Axial compressor outlet pressure and temperature, HP turbine outlet pressure and temperature, PT exhaust pressure and temperature, GG and PT speeds, IGV and CGV positions and control signals, fuel consumption (corrected to 20ºC and 1 atm) versus time. PACKAGER shall also furnish an algorithm for evaluate the total remaning life considering fuel consumption and number of starts;

• Mechanical: all machinery protection system signals (with possibility to make analysis like FFT, full spectrum, Bode plot, cascade and waterfall diagrams, shaft average center line, orbit, X-Y plot and experience-based vibration analysis) and auxiliary system signals (as mineral and sythetic lube, seal, etc.).

4.7.3 MPS radial vibration monitoring cards shall have all available variables enabled to send data to MMS.

4.7.4 In addition to the signal available through the MPS Communication Card, PACKAGER shall make available the required process variable signals presented in the I-ET-3010.00-5500.854-P4X-001 – MACHINERY MONITORING SYSTEM, through the Package Fast Ethernet Network to perform the functions above in the Machinery Monitoring System.

4.7.5 Packager shall provide all documentation of vibration signals and configuration files of the Machinery Protection System to be implemented by the MMS Supplier for Monitoring System configuration.

4.8 Compressor capacity control

4.8.1 The Capacity control shall be performed per each compression service type. 4.8.2 Process control shall maintain the suction pressure and limit the discharge

pressure of compressor trains. If the discharge pressure exceeds set point, system shall switch from suction pressure control to discharge pressure limit. These set points shall be monitored and controlled from UCP at Automation and Electrical Panels Room (AEPR).

4.8.3 Process control shall limit electric motor current of compressor trains. If the current exceeds set point, system shall switch from suction pressure control to electric motor current limit. These set points shall be monitored and controlled from Unit Control Panel (UCP) at Automation and Electrical Panels Room (AEPR).

4.8.4 PACKAGER shall furnish the Capacity control instrumentation. The instruments specification shall be submitted to PURCHASER approval, including throttle valves when specified. Valves and instrumentation shall be shipped loose for PURCHASER approval.

4.8.5 Capacity control system pressure transmitter shall have a maximum response time of 100 milliseconds

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4.8.6 Turbine speed set point shall be included in Capacity Control Loop. 4.8.7 Capacity control shall be mounted on Unit Control Panel (UCP) at

Automation and Electrical Panels Room (AEPR). 4.8.8 Capacity control system shall be implemented by separated and dedicated

microprocessor based system, independent of the compressor control, with hardwired interlock and network for communication purpose. The Capacity control, Load sharing control and Anti-surge systems of the compressors shall be segregated from the Control system and the Safety system PLCs.

4.9 Load sharing control

4.9.1 The load sharing control supplier shall be supplied according to the OEM standards.

4.9.2 The Load sharing control shall be performed by each compressor train. 4.9.3 Control system shall operate the units individually, partial units or all of them

in parallel, with automatic and manual modes. Set points shall be monitored and controlled from UCP at AEPR.

4.9.4 PACKAGER shall furnish the Load Sharing instrumentation (for each train). The instruments specification shall be submitted to PURCHASER approval, including throttle valves when specified. Valves and instrumentation shall be shipped loose, for PURCHASER field assembly.

4.9.5 Load sharing system pressure transmitters shall have a maximum response time of 100 milliseconds.

4.9.6 When operating in parallel, load sharing control shall provide appropriate distribution of loads between units, so that they operate proportionally equidistant from their respective limits. Special attention shall be given to specific stages operating closer to the surge line.

4.9.7 Load sharing control shall be mounted on Unit Control Panel (UCP) at Automation and Electrical Panels Room (AEPR).

4.9.8 Load Sharing control system shall be implemented by a separated and dedicated microprocessor based system, independent of the compressor control, with hardwired interlock and network for communication purpose.

4.10 Anti-Surge (AS) control

4.10.1 For design purpose, PACKAGER shall consider one AS recycle line for each stage in your proposal. Overall recycle line shall not be accepted.

4.10.2 In case of water gas content, an analysis shall be made to verify the possibility of hydrate formation in the recycle line. Hot recycle (ASV upstream of the heat exchanger) shall be preferably used.

4.10.3 PACKAGER shall furnish the AS control valves with their instrumentation including transmitters (flow, pressure and temperature) for each stage and AS control system (controllers installed at UCP). The anti-surge valves instrumentation and piping associated with the valves shall be specified by AS system VENDOR. The design of the anti-surge valves, instrumentation and piping associated with the valves shall be submitted to PURCHASER and VENDOR approval, including check valves. Valves and instrumentation shall be shipped loose, for PURCHASER field assembly.

4.10.4 AS system pressure and flow transmitters shall be smart with HART protocol and maximum response time of 100 milliseconds.

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4.10.5 The volume between discharge compressor, check valve (upstream heat exchanger) and AS valve shall be as minimum as possible. A double check valve shall be provided separating each compressor stage.

4.10.6 AS valves shall be sized according to process dynamic simulation to be performed by PACKAGER and submitted to PURCHASER approval.

4.10.7 The dynamic simulation shall be applied to tune the capacity and surge controls in order to optimize both controls. The dynamic simulation shall also confirm the AS configuration (valves, lines, etc.).

4.10.8 AS valves shall be sized to perform their function in all operating conditions, including transients, avoiding choke zone but not oversized in order to maintain their controllability.

4.10.9 Actuation time for AS valves, from fully closed to fully open position, shall be less than two (2) seconds and opening-closing cycle time shall be less than two (2) seconds;

4.10.10 AS control system shall be implemented by a separated and dedicated microprocessor based system, independent of the compressor control with hardwired interlock and network for communication purpose and shall be furnished with: • The antisurge valve shall be open failure type, with linear response,

class 5 balanced cage globe, ASTM-A 216 Gr WCB body material, AISI 316 seat material with “Stellite” or equivalent hardness material, no chromium coating shall be accepted and with anti-noise technology to attenuate up to 90 dBA @ 1m;

• The antisurge valve shall be mounted with high speed intelligent positioner and high flow booster to increase the precision and speed of actuation;

• The use of quick exhaust or similar system that opens the antisurge valve in an uncontrolled mode is not allowed;

• A solenoid shall be used, between the Booster and the Actuator, with high Kv to allow antisurge valve smallest stroke;

• The maximum antisurge valve opening stroke time (0 to 100%) shall be up to 1 second for valves less than or equal to 4 ", up to 2 seconds for valves greater than 4" and less than 12 " and up to 3 seconds for valve greater than 12";

• The minimum antisurge valve closure stroke time (100% to 0) shall be up to 3 seconds for a valve less than or equal to 4 ", up to 5 seconds for valve greater than 4" and less than or equal to 12 " and up to 8 seconds for valve greater than 12”;

• A maximum scan time of 0.05 seconds; • The AS control shall be capable to detect the compressor at surge; • In case of two (2) surge events within fifteen (15) seconds, the AS valve

shall be openned through curent analog output and solenoid deenergizing, installed between booster and actuator;

• In case of four (4) surge events within thirty (30) seconds, the AS control shall stop the compressor;

• A closed loop with anti-reset windup action;

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• Adaptative actions to allow the surge control line to change as a function of the displacement of the operating point, with automatic return to the original position;

• An adaptive open loop response to large and fast disturbances; • An adaptive detection algorithm in order to protect the compressor by

establishing new safety margins (more conservative than previous one) when a surge event occurs;

• An electronic decoupling algorithm used to avoid interaction between AS and the others compressors control loops;

• Automatic correction for molecular gas weight, suction pressure, suction temperature and compressor efficiency variations throughout the equipment service life;

• Devices to protect the machine even in manual operation. 4.10.11 In order to achieve good controllability, PACKAGER shall recommend and

review AS line layout. 4.10.12 AS control and Capacity control / Load sharing systems from compression

service shall have a decoupling capability in order to temporally reduce the capacity control action when the surge control is performed.

4.11 Advanced Control

4.11.1 Advanced controls are to be defined by PETROBRAS during the detail design, or during operation phase. These systems may use PETROBRAS software package, or third part packages when required, and run on computers in the automation network. The goal of advanced control is to assist operators in integrating and coordinating the various compressors in the unit’s gas treatment system.

4.11.2 PACKAGER shall provide connectivity through MODBUS and OPC for the advanced control to read all critical variables of the compressor (pressures, temperatures, power, current, speed, etc.).

4.11.3 PACKAGER shall provide for the compressor suction and discharge pressure set points two 4-20mA input signals at Capacity Control. In this way, the advanced control or the operator can command the suction pressure set points. At package HMI operator shall select if the set points will be defined locally (at package HMI) or remotely (from advanced control signals). This signals (4-20mA) will be provided by the Process Control System (PCS) (not in the scope of the PACKAGER).

4.11.4 PACKAGER shall provide for each AS recycle valve a 4-20mA input signal in AS control system. This signal will go to a high value selector (override) with the output of the anti-surge (AS) control algorithm. In this way, the advanced control or the operator can command the opening of the recycle valve, even if the AS control does not need to open the valve. This override selector shall be implemented in AS control system, but the override signal (4-20mA) will be provided by the Process Control System (PCS) (not in the scope of the PACKAGER). At package HMI, operator shall select if this remote ASV command will be enabled or not.

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5 ELECTRICAL 5.1 Electrical equipment and materials shall comply with requirements of I-ET-

3010.00-5140-700-P4X-002 - SPECIFICATION FOR ELECTRICAL MATERIAL AND EQUIPMENT FOR OFFSHORE UNITS.

5.2 Electrical installations inside the package and the voltages to be supplied for electrical loads (motors, heaters, control panels, etc.) shall comply with requirements of I-ET-3010.00-5140-700-P4X-003 - ELECTRICAL REQUIREMENTS FOR PACKAGES FOR OFFSHORE UNITS.

5.3 Electrical motors shall comply with requirements of I-ET-3010.00-5140-712-P4X-001 - LOW-VOLTAGE INDUCTION MOTORS FOR OFFSHORE UNITS. The electrical motors shall be fed from platform panels.

5.4 The electrical communications interfaces of the package shall comply with requirements of I-DE-3010.00-5140-797-P4X-00 – ELECTRICAL SYSTEM AUTOMATION ARCHITECTURE DIAGRAM, I-ET-3010.00-5140-797-P4X-001 –ELECTRICAL SYSTEM AUTOMATION ARCHITECTURE and I-LI-3010.00-5140-797-P4X-001 - ELECTRICAL SYSTEM AUTOMATION INTERFACE SIGNALS LIST.

5.5 Auxiliary MCCs (Motor Control Center) shall comply with requirements of I-ET-3010.00-5140-741-P4X-001 - LOW-VOLTAGE MOTOR CONTROL CENTER AND SWITCHGEAR FOR OFFSHORE UNITS and I-ET-3010.00-5140-700-P4X-005 - REQUIREMENTS FOR HUMAN ENGINEERING DESIGN FOR ELECTRICAL SYSTEMS OF OFFSHORE UNITS.

5.6 Heather panels shall comply with I-ET-3010.00-5140-741-P4X-003 – POWER PANEL FOR THYRISTORIZED HEATER FOR OFFSHORE UNITS.

5.7 Other panels, except MCC, shall comply with requirements of I-ET-3010.00-5140-700-P4X-002 - SPECIFICATION FOR ELECTRICAL MATERIAL AND EQUIPMENT FOR OFFSHORE UNITS.

5.8 Equipment, accessories, piping and structures shall be grounded according to requirements of I-DE-3010.00-5140-700-P4X-003 - GROUNDING INSTALLATION TYPICAL DETAILS, I-ET-3010.00-5140-700-P4X-001 – SPECIFICATION FOR ELECYTRICAL DESIGN FOR OFFSHORE UNITS, IEC 61892-6 and IEC-60092-502. Besides these standards, for installations in hazardous area, the grounding requirements of IEC 61892-7 shall be complied with.

5.9 Turbocompressor auxiliary loads shall be fed by turbocompressor auxiliary MCCs. These panels shall comply with I-ET-3010.00-5140-741-P4X-001 - LOW-VOLTAGE MOTOR CONTROL CENTER AND SWITCHGEAR FOR OFFSHORE UNITS.

5.10 The accumulator battery and battery charger, when requested by the package, and unless otherwise indicated, shall be supplied in accordance with I-ET-3010.00-5140-700-P4X-002 - SPECIFICATION FOR ELECTRICAL MATERIAL AND EQUIPMENT FOR OFFSHORE UNITS. Accumulator batteries shall be vented lead-acid.

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6 OPERATION AND MAINTENANCE REQUIREMENTS

6.1 PACKAGER shall make the applicable recommendations to optimize operation and maintenance, taking into account the remote location and platform general conditions. Any changes to equipment design, materials or specific spares that may improve the equipment operability, availability or reliability shall be submitted to PURCHASER for review and approval. But PACKAGER shall always comply with PURCHASER requirements before suggest any modification.

6.2 The packages shall be designed so that all maintenance can be carried out with standard tools as much as possible.

6.3 Equipment layout shall enable easy and safe access for maintenance to all components and parts. PACKAGER shall provide suitable walkways, ladders and handrails inside the skids for all packages, including auxiliaries. All equipment and peripherals, especially oil reservoirs, shall have full access and inspection doors / hatches.

6.4 Instruments and piping accessories shall be arranged in proper location in order to allow easy access by maintenance and operation personnel. Installation of piping and cable supports next to couplings, bearings and seals shall be avoided, for instance.

6.5 PACKAGER shall prepare detailed assembly, disassembly and maintenance procedures, describing the use of all involved lifting apparatus and including all required preventive and corrective maintenance tasks. PACKAGER shall inform the need for disassembling any component or equipment in order to facilitate access for maintenance. Suitable maintenance routes shall be provided to remove the main components and auxiliaries, avoiding interference with structures, piping, cabling, electric conduits and supports, equipment, etc. This plan shall be submitted to PURCHASER for approval.

6.6 PACKAGER shall provide electrically driven lifting / handling devices and external structure components enabling assembly, disassembly and removal all components inside the package (gas turbine, gearbox, compressor, etc.) with adequate and certified capacity to handle maximum maintenance weight and / or dimensions. Lifting and handling devices shall be according to I-ET-3010.1M-5266-630-P4X-001 – TOPSIDE´S MECHANICAL HANDLING PROCEDURES.

6.7 PACKAGER shall provide special tools for all maintenance activities including tools for compressor and driver assembly, disassembly and removal.

6.8 PACKAGER shall include in proposal a schedule stating the expected time between major overhauls.

6.9 PACKAGER shall provide a gearbox shaft end with an adaptor in order to allow manual turning for maintenance purposes.

6.10 Noise control requirements 6.10.1 Noise control analysis is a mandatory item to be carried-out. PACKAGER

shall present noise data regarding items included in scope of supply. 6.10.2 The GT acoustic enclosure shall be designed to reduce the pressure noise

level emitted by the GT skid to less than 85 dB(A) at 1.0 m distance, 1.5 m height in the free field conditions. The maximum allowable Turbocompressor train sound level shall be 90 dB(A) at 1.0 m around the unit and up to 2.0 m from the floor.

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6.10.3 The noise control system for the package shall consider the noise radiated by inlet / outlet piping, equipment enclosure including ventilation system (if specified) and equipment casings.

6.10.4 In case of expected noise are higher than allowable limits, the equipment must be furnished with some noise control reduction measure and the maximum noise allowable will be 85 dB(A) . PACKAGER may consider the best solution, which may include or not the supply of an acoustic and thermal enclosure with ventilation and safety system requirements. The use of device to comply with noise requirement must be proved to be efficient and submit to PURCHASER approval.

6.10.5 For all equipment installed without acoustical enclosure, the following data will be required during proposal phase: • Sound power level of the equipment; • Sound pressure level, in each of the four main directions and in one

point of the top. 6.10.6 For all equipment installed inside acoustic enclosure, the following data will

be required during proposal phase: • Sound power level of the equipment without enclosure; • Sound pressure level, in each of the four main directions and in one

point of the top, for the equipment plus enclosure; • Acoustical data of enclosure and silencers (when applicable).

7 INSPECTION AND TESTS 7.1 General requirements

7.1.1. PURCHASER is entitled to inspect the package anytime during fabrication to ensure that material and workmanship are in accordance with the specifications.

7.1.2. Inspection of materials and / or equipment will be made by PURCHASER or its authorized representatives.

7.1.3. Unless otherwise specified, all witnessed tests shall be informed, at least, 90 days before the scheduled dates.

7.1.4. Unless otherwise established by PURCHASER inspector, all equipment shall be available for inspection in an unpainted state.

7.1.5. All UCP shall be functionally tested at supplier facilities. All control sequences and shutdown logics shall be simulated and tested against the requirements. Details of supplier standard functional test procedures shall be submitted to PURCHASER approval.

7.1.6. PURCHASER inspector shall have the right to request inspections to ensure that the equipment complies with the relevant classification society requirements.

7.1.7. In case any defects and / or shortcomings are found, PACKAGER shall bear the full cost of such inspection and replacement as necessary. Any repair shall previously be approved by PURCHASER. The subsequent inspection necessary to confirm the satisfactory results will be at PACKAGER cost.

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7.1.8. For gas turbines, after factory acceptance tests, a boroscope inspection shall be carried out, recorded and send to PURCHASER.

7.1.9. For gas turbines, all fuel system welds shall be 100% radiographically inspected and submitted to magnetic particle examination.

7.1.10. For compressors, all process gas system welds shall be 100% radiographically inspected and submitted to magnetic particle examination.

7.1.11. DGS as well as Hydrodynamic Bearings shall be removed by PACKAGER after FAT and package separately with clear identification to be delivered with the main equipment in a packing suitable for long term storage for posterior PACKAGER assembly.

7.2. Hydrostatic test (HT)

7.2.1. For all trains, parts being tested shall be externally coated with a layer of white lead carbonate or any other suitable powder to help leakage detection.

7.2.2. No vises or clamping devices shall be used for pressing of nozzle flanges. 7.2.3. PTFE tape or thread compounds shall not be used to prevent leakage of

threaded plugs and connections. 7.3. Performance Test (PT)

7.3.1. For gas turbines, PT shall be performed on each unit (gas generator and power turbine) according to ASME PTC 22.

7.3.2. For compressors, PT shall be performed on each unit according to ASME PTC 10 (type 2).

7.3.3. For compressors, PACKAGER shall provide balance line flow meter and division wall flow measurement during performance test.

7.4. Mechanical Running Test (MRT)

7.4.1. For gas turbines, MRT shall be performed on each unit (gas generator and power turbine) according to API STD 616.

7.4.2. For compressors, MRT shall be performed on each unit and all spare bundles according to API STD 617.

7.4.3. For compressors, one full-pressure, full-load, full-speed test shall be performance as per API 617 item 4.3.8.6 per compressor type during the Mechanical Running Test, only for HP casing. As a MRT item, the full pressure/load/speed shall also be witnessed. During this test, shop driver may be used.

7.4.4. PACKAGER shall submit to PURCHASER a CD with vibration data recorded during MRT and all test information, including, at least: failed tests, with sweeping, starting / stopping ramp, equipment vibration signature, diagram for all bearing signals and phase angle versus speed.

7.5. Sound Level Test (SLT)

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7.5.1. The sound pressure meter shall be class I, according to IEC 61672. The characteristics of the octave filter shall be in accordance with IEC 61260. The sound pressure reading shall be made as equivalent continuous level, for 60 seconds sampling time. The recorded values shall be corrected to the nearest entire value within 1dB. A maximum deviation of 2dB will be allowed, both for the A scale weighted value and for the octave bands between 31.5 Hz and 8000 Hz.

7.5.2. The procedures for sound measurement assume a condition of free field over reflecting floor. This implies that the tests will be preferably performed in an outside area, with a smooth floor made of concrete, asphalt, etc. If this condition is not satisfied, then the correction for measurements in rooms shall be applied.

7.5.3. If the difference between the background noise level and the equipment sound level plus the background is less than 10dB, the measurements shall be corrected.

7.5.4. If the normal operating condition cannot be reached in the test facilities, PACKAGER and PURCHASER shall agree with measurements methods and values.

7.5.5. If the values measured and reported during the shop test are higher than the limits submitted by PACKAGER and approved by PETROBRAS in proposal, PACKAGER shall provide, without extra cost, sound attenuation methods in order to reach this limit, if required by PURCHASER.

7.6. Complete Unit Test (CUT)

7.6.1. PACKAGER shall execute CUT including the following contract parts, at least: gas generator, power turbine, gearbox, UCP, starting system, oil system (synthetic and mineral), and gas fuel system, compressor (HP + LP casings) and seal system.

7.6.2. CUT shall be a functional test and may be combined with others (MRT and/or PT) for test procedures optimization according PACKAGER schedule.

7.6.3. Vibration requirements (limits, acceptance, etc.) shall be the same used for MRT.

7.6.4. Control check shall be done during CUT, as part of functional test. 7.7. Site Acceptance Test (SAT)

7.7.1. PURCHASER will provide all facilities and technical procedures (mounting procedures, MCC, lube oil, etc.) to execute an air running, vacuum or inert gas (Nitrogen) functional test onshore for each set according to “Annex C”. PACKAGER shall provide technical assistance for all onshore SAT. Procedures and results shall be submitted for Classification Society and PURCHASER final approval.

7.7.2. In addition to the onshore SAT, an offshore field acceptance functional test shall be performed for each set according to “Annex A”

7.7.3. Probes and monitors shall be tested and calibrated before SAT, during commissioning. Calibration curves shall be plotted and checked according to probes standards tolerances.

7.7.4. PURCHASER will perform a SLT during SAT.

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7.8. Factory Stability Test (FST)

7.8.1. A FST per compressor type shall be performed as described in “Annex B” item 4.3.8.9.

7.9. Post Inspection Test (PIT)

7.9.1. A gas turbine boroscope test inspection shall be performed on every unit immediately after the last run prior to delivery and a report recorded in CD/DVD (movie or photo files). Dismantling, inspection and reassembling will be only required in case of unsatisfactory Mechanical Running Test (MRT), as defined in API 616, Section 6.

8 ANNEXES

8.1 Annex A: Turbocompressor Offshore Acceptance Test. 8.2 Annex B: Additions and Modifications to API 617. 8.3 Annex C: Inert Gas Compressor Running Test. 8.4 Annex D: Comments and Deviations to API 617.

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ANNEX A ROTATING EQUIPMENT RELIABILITY TEST

(TURBOMACHINERY UNITS) The reliability test is intended to demonstrate that turbomachinery unit overcomes the premature failures (“burn in phase”) and provide a reliable operation condition within useful life. For such evaluation, the reliability test shall be performed to measure the mean time to failure (MTTF) for each turbomachinery unit under specific condition (test) and acceptance criteria. The test is considered concluded and accepted if the number of countable failures is zero and the accumulated (aggregated) time in service is higher than 240h. If in the meantime any number of countable failures occurs, the procedure below shall be followed as mandatory:

a) The turbomachinery unit is considered accepted if it reaches the accumulated time in service indicated in the “Acceptance Zone” (Figure 1).

b) If any number of countable failures is reached in service leading to the “Rejection Zone”

(Figure 1), the turbomachinery unit is rejected and a root cause analysis shall be performed, turbomachinery unit repaired and the test restarted from the beginning. Both, the unit elapsed running time and number of failures shall be disregarded and a new reliability test shall be carried out.

c) Nevertheless, if accumulated time in service and number of failure is within between

rejection and acceptance lines the test must go on up to reach the “Acceptance Zone”.

d) The test is considered concluded as soon as it reaches the “Acceptance zone” or when it reaches 720h of accumulated (aggregated) time at most with no more than 7 countable failures.

FIGURE 1: RELIABILITY TEST ACCEPTANCE CRITERIA

0

1

2

3

4

5

6

7

8

0 120 240 360 480 600 720

Nu

mb

er

of

fail

ure

s

Accumulated time in service (hours)

Reliabitily Test Acceptance Criteria

Acceptance Line

Rejection Line

Continue to test

Rejection Zone

Acceptance Zone

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With regards to the reliability test, only failures occurring within the turbomachinery boundaries limits (Figure 2) shall be considered. Countable failure shall be considered as any event that causes complete or partial loss of system’s capability of providing its output (Appendix 1). Any external cause (from outside turbomachinery boundaries) that leads to the shutdown and any downtime shall be disregarded. The test shall continue after restart the turbomachinery unit counting the aggregated time so far.

FIGURE 2A

FIGURE 2B

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FIGURE 2 – ROTATING EQUIPMENT BOUNDARIES LIMITS

APPENDIX 1 – COUNTABLE FAILURE

• Any failure resulted from faulty manufacturing or design of main & ancillary equipment, components or systems.

• Any failure demanding casing disassembly, realignment, adjustment or any other fault demanding replacement or repair of main & ancillary equipment.

• Performance disturbances caused by malfunction of performance/capacity controllers, speed controllers, anti-surge controllers, recycles / relief/ bypass system and interlocking within the package.

• Vibration & bearing temperature levels higher than specified / contracted.

• Control, protection, sequence or interlocking system problems demanding re-programming or re-configuration.

• Any repeated actuation (more than three consecutive events) of the same trip demanding recalibration and re-setting of such parameters.

• More than three unsuccessful starts in sequence demanding recalibration and re-setting of startup system.

• Failure to stop on demanding during test sequence.

Remark: Any other occurrence that could cause no immediate neither critical impact on the equipment-unit function will be considered as typically non-critical failures and therefore will not interrupt the test (abnormal instrument reading, minimum external leakage, signal transmission with intermittent disconnection, poor response to feedback, false alarm, faulty instrument indication, loss of ability to provide heating, lack off or reduced ability to cooling/exhausting/ventilation of auxiliary systems).

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ANNEX B

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ADDITIONS AND MODIFICATIONS TO API 617 FOREWORD This Annex is based on API Standard 617, 8th edition, September 2014. It is only written in English. 1 SCOPE This Annex establishes the minimum conditions required for axial and centrifugal compressors, expander-compressors and their auxiliary equipment or systems, to be supplied in accordance with API Standard 617, 8th edition, September 2014. 2 SUPPLEMENTARY DOCUMENTS The following documents are referenced in the text and contain valid rules for this Annex. 2.1 Base Standard API Standard 617 – Eighth Edition – Axial and Centrifugal Compressors and Expander-compressors for Petroleum, Chemical, and Gas Industry Services. 3 GENERAL REQUIREMENTS 3.1 The requirements of this Annex are additions to, or modifications of the API Standard 617, 8th edition, which is an integral part of this Annex. 3.2 Except for new clauses, item numbers used in this Annex are the same API Standard 617, 8th edition paragraph ones. 3.3 No additional deviations from Annex D will be accepted. PACKAGER is responsible to relate each deviation from API Standard 617, 7th to 8th had already discussed with PETROBRAS as presented in Annex D. All deviations from new/modified paragraphs from the requirements in this Annex and/or API Standard 617, 8th edition must be clearly identified in the proposal and submitted to PETROBRAS for approval. Any requirement exception or deviation from any of the listed documents not clearly mentioned in tender will be considered by PETROBRAS as full compliance with the material requisition. 3.4 All deviations from the contracted design or scope of supply made by vendor during time of drawings and documents review shall be clearly mentioned in the particular document to be approved. 3.5 Vendor’s compliance with the requirements of these specifications does not exempt him from the responsibility of supplying equipment and accessories suitable for the specified service conditions. 3.6 Compressors and auxiliary equipment shall be in accordance with API Standard 617, 8th edition, plus the following changes, as noted in parenthesis for each clause,

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according to the definitions stated below. The information of each clause shall be read as follows, whenever starting with:

Addition: Continuation of that particular API Standard 617 paragraph

Modification: Replacement of part of that affected API Standard 617 paragraph

Substitution: Replacement of that API Standard 617 paragraph in its entirety

New: Insertion of a requirement not found in API Standard 617

Deletion: Removal of that particular API Standard 617 paragraph

Comment: Clarification or interpretation on that API Standard 617 paragraph 4 PETROBRAS CHANGES TO API STANDARD 617, EIGHTH EDITION Note - From this point onwards the numbering of the items refer to the corresponding item of the API 617 standard. PART 1- GENERAL REQUIREMENTS

4.8 DYNAMICS

4.8.2 Lateral Analysis

4.8.2.3 (Substitution) The supplier shall conduct an undamped analysis to identify the undamped critical speeds and determine their mode shapes. The analysis shall identify the first four undamped critical speeds and cover as a minimum the stiffness range from free-free to rigid support rotor modes.

4.8.2.4 b (Addition) The clearance ranges to be used in the analysis shall be: minimum bearing clearance and maximum preload, calculated using maximum pad, minimum bearing and maximum shaft radius; average bearing clearance and preload, calculated using mean pad, bearing and shaft radius; maximum bearing clearance and minimum preload, calculated using minimum pad, maximum bearing and minimum shaft radius; these calculated coefficients for the speed range, shall be presented in the damped unbalance response analysis report. Bearing circumferential temperature profile shall also be included.

4.8.2.4 c (Addition) The pad inertia and thermal effects, convection and pad conduction shall also be considered.

4.8.2.4 k (New) The influence over the operating range of the damper seals stiffness and damping, considering also the tolerance on the component clearance.

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4.8.2.7 (Modification)

Replace first sentence by: A separate damped unbalance response analysis shall be conducted for each critical speed in the range from ZERO to trip speed, as well as the next mode occurring above the trip speed.

4.8.2.8 (Substitution)

As required by 4.8.3.1, additional analyses shall be made for use with the verification test specified in 4.8.3. The location of the unbalance shall be determined by the supplier. The unbalance shall not be less than 2 times or greater than 8 times the value from Equation (3) or Equation (4) or as specified in 4.8.2.8.1. Any test stand parameters that influence the results of the analysis shall be included, such as actual bearing clearances used during the test and pedestal stiffness. If the chosen location of the unbalance does not excite the critical(s) of concern, the unbalance shall be placed in the plane(s) that would excite the critical most adversely.

4.8.2.9 a (Substitution) If the AF at a particular critical speed outside the operating speed range is less than 2.5, the response is considered critically damped and no separation margin is required (SMr = 0). However, even though amplification factor calculations for a given rotor may indicate critically damped response and then no separation margin would be required, critical speeds within the operating speed range will only be accepted if the vendor can demonstrate that all efforts to remove the critical speed from the operating speed range have been exhausted.

4.8.2.11 (Modification) Replace Equation (9) by: Scc = Avl / Amax

4.8.2.11.2 (Adition) For machines with abradable seals, the rotor response amplitudes, corrected in accordance with 4.8.2.11 at any speed from zero to trip speed shall not exceed 100 % of the minimum design diametral running clearances throughout the machine.

4.8.1.4.2 (Substitution)

Unless otherwise specified, the reporting requirements identified as required for independent audit of the results shall be provided.

4.8.1.4.3 (Substitution) Provisions shall be made to provide the purchaser with access to drawings to develop independent models of the rotor, bearings, and seals. This data shall be made available in electronic format.

Annex C.1.k.ii (Substitution)

Figure C.2 plot of log decrement, �, vs cross coupled stiffness for minimum and maximum bearing clearances, combined with the two extremes of oil temperature and

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pressure (minimum pressure with maximum oil temperature, and minimum temperature with maximum oil pressure); NOTE The minimum and maximum bearing clearances to be used in the analysis shall be:

Minimum bearing clearance and maximum preload, calculated using maximum pad, minimum bearing and maximum shaft radius; Maximum bearing clearance and minimum preload, calculated using minimum pad, maximum bearing and minimum shaft radius.

4.8.3 Unbalanced Rotor Response Verification Test


An unbalanced rotor response test (URT) shall be performed as part of the mechanical running test (see 6.3.5 of Part 1, 6.3.1 of Parts 2 and 3, and 6.3.3 of Part 4, whichever is applicable), and the results shall be used to verify the analytical model. The actual response of the rotor on the test stand to the same arrangement of unbalance and bearing loads as was used in the analysis specified in 4.8.2.8 shall be used for determining the validity of the damped unbalanced response analysis. To accomplish this, the requirements of 4.8.3.1.1 through 4.8.3.1.6 shall be followed. NOTE This test may be performed on an on-speed balancing machine if previously approved by PETROBRAS.

4.8.3.1.3 (Substitution) The machine shall then be brought up to trip speed after being held at maximum continuous speed until bearing temperature and vibration have been stabilized, and the indicated vibration amplitudes and phase shall be recorded during the coastdown using the same procedure as 4.8.3.1.1.

4.8.3.1.4 (Substitution) The location of critical speeds below the trip speed shall be clearly identified during the test. NOTE: This may be accomplished on an on-speed balacing machine if previously approved by PETROBRAS.

4.8.3.1.5 (Addition) If, after vectorial subtraction, the unbalance mass does not change the vibration at critical speed in more than 2.5 µm (0.1 mil), then the unbalance weight shall be increased and the test shall be repeated.

4.8.5 Level I Stability Analysis

4.8.5.8 Level I Screening Criteria (Modification)

Replace item a. ii by:

ii. 0.2. <a

δ

Replace item b. by:

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b. For axial flow rotors:

If 0.2 <

aδ , a Level II stability analysis shall be performed. Otherwise, the

stability is acceptable and no further analyses are required.

4.8.6 Level II Stability Analysis

4.8.6.9 Acceptance Criteria (Substitution) The Level II stability analysis shall indicate that the machine, as calculated in 4.8.6.1 through 4.8.6.8, shall have a final log decrement, ��, greater than 0.2.


A stability test, to measure damping ratio (and to determine the corresponding log decrement), shall be performed in accordance with item 6.3.8 if one of the following conditions is satisfied: a) the machine fails to meet the criteria specified in item 4.8.6.9; b) the test has been specified in compressor data sheet.

NOTE Some particular applications which have not proven rotordynamic design may require special consideration in determining the actual compressor damping ratio (thus demanding stability test to be performed), such as CO2 injection, high-pressure and high-density gases, etc.

4.8.8 Vibration and Balancing

4.8.8.11 (Modification)

Replace the item by: If the supplier can demonstrate that electrical or mechanical runout is present, a maximum of the level from Equation (13) or 6.35 µm (0.25 mil), whichever is greater, may be vectorially subtracted from the vibration signal measured during the factory acceptance test. 6 - INSPECTION, TESTING, AND PREPARATION FOR SHIPMENT

6.3 Testing 6.3.5.2 Substitution)

Shop test facilities shall include the capability of continuously monitoring, displaying, recording, and printing vibration displacement and phase, vibration spectra, Bode plots, shaft orbits, bearing metal temperatures and oil pressures and temperatures. Shop test facilities shall also include a dedicated station fully available for PETROBRAS use, and capable of handling and analyzing all real time data collected during all tests.

6.3.5.9.3 (Substitution)

Synchronous vibration amplitude and phase angle versus speed during acceleration and deceleration shall be plotted before and after the 4-hour run. Both the synchronous (one per revolution) and overall vibration levels shall be plotted. The speed range covered by these plots shall be from 400 rpm to trip speed and from trip speed to 400 rpm.

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6.3.5.9.5 (Substitution) The following seal flow data shall be taken during the compressor mechanical running test (MRT) and performance test (PT) to assure that the seals are installed and operating properly:

a. For compressors with oil seals, inner oil leakage, pressure and temperature shall be measured at each seal;

b. For single dry gas seals, flow, pressure and temperature in each vent line from each seal shall be measured. If a buffer gas seal is used, injection flow, pressure and temperature for each seal shall also be measured;

c. For tandem dry gas seals, flow, pressure and temperature in the primary and secondary

d. vent line from each seal shall be measured. If a buffer gas for primary and secondary seal is used, injection flow, pressure and temperature for each seal shall also be measured;

e. For double dry gas seals, the pressure, temperature and total flow to each seal shall be measured. 6.3.5.9.5.1 (New)

The guaranteed static seal leakage shall be checked during the assembled compressor gas leakage test.

6.3.5.9.6 (Substitution) Lube-oil and seal-oil inlet pressures and temperatures shall be varied through the range permitted in the compressor operating manual. The following cases shall be verified during the 4-hour test:

— high lube oil pressure & high lube oil temperature; — high lube oil pressure & low lube oil temperature; — low lube oil pressure & high lube oil temperature; — low lube oil pressure & low lube oil temperature.

Oil conditions change test shall be done during the four-hour mechanical running test, but not before all test parameters and variables are considered to be stable or steady enough to proceed. This test does not constitute a waiver of the other specified test requirements. The oil conditions change shall be held for a minimum of five minutes after temperature stabilization.

6.3.7 Optional Tests (Addition)

6.3.7.9 Spare-parts Test (Substitution) Spare parts such as rotors, bearings, and seals shall be inspected and tested under the same requirements of main components. Equivalent reports shall be issued as well. Spare rotors need not be performance tested, except when complete spare bundles are purchased. Complete spare bundles shall be performance tested using the same procedure as the main bundle.

6.3.8 (New) Stability Test The purpose of this entire new item is to provide the minimum requirements for the execution of a Factory Stability Test (FST), in order to measure the actual stability margin of the machine, identifying the sister modes (forward and backward) and their respective log decrements. The log decrement shall be measured, at least, in two different operational conditions, in order to plot the measured actual applied cross-

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coupled stiffness vs. Log decrement and the extrapolated produced curve, to the minimum log decrement at worst design conditions (see item C.1.k Part 1). The presentation of the results shall include a plot of applied cross-coupled stiffness vs. Log decrement, showing the measured values and the expected values for similar conditions. Equipment shall be tested in accordance with 6.3.8.1 through 6.3.8.6.

6.3.8.1 (New) Methods & Procedures The manufacturer shall specify in the FST procedure which kind of excitation is intended to be applied, which measurement devices to be used during the FST and how the test execution sequence has been planned. The type and direction of the excitation shall be fully described as well, including whether it would be directional (horizontal or vertical) or circular (forward or backward). It is purchaser understanding that there are several methods to apply excitation and to measure the required data, as below.

6.3.8.1.1 (New) Excitation Methods Impact exciters such as a hammer, bearing casing exciter or an Active Magnetic Bearing (AMB) exciter shall be used to excite the rotor. The excitation using an AMB could also be an impact or a sine sweep (blocking type or conventional).

6.3.8.1.2 (New) Measurement Techniques The measurement techniques can be applied in the frequency domain or in time domain. In any of the methods, the approach to estimate the forward and backward modes and respective log decrements shall be using multiple degrees of freedom (MDOF). The method employed shall provide acceptable results even in case of the following difficulties or abnormalities (but not limited to):

a) rotor system anisotropy; b) slightly damped systems (the method must render an acceptable damping ratio

estimation); c) limitations on the number of input and output locations; d) noise and /or internal sources of excitations, such as rotor unbalance.

Due to the proximity of modes in the rotating systems, the Single-Degree of Freedom (SDOF) technique is not acceptable. The methods that lead to the best results are the PEM (Predicted Error Method) for frequency domain and MOBAR (Multiple Output Backward Auto Regression) for time domain. Any other applicable methodology, rendering acceptable results even in case of above mentioned system characteristics, such methodology shall be fully described (type of load, application of load, measurement techniques, interpretation of results, definition of model order, etc.) and demonstrated (list of experience with similar designs, results and comparison with actual data). Methodologies shall be submitted to purchaser for review and approval.

6.3.8.2 (New) Definitions The stability of the machine shall be measured in two different operating conditions as defined in 6.3.8.2.1 and 6.3.8.2.2.

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6.3.8.2.1 (New) Base Stability The Base Stability is defined as the measured stability with the machine running with zero internal cross-coupling. This can be most closely achieved with the rotor running on High Speed Balancing Machine or running during the Mechanical Running Test, preferably under vacuum, which may be done during HSB at HSBM, or at Test Bed during Mechanical Running Test (MRT) or Performance Test (PT). The Base stability shall be measured at maximum continuous speed - MCS - and at Performance test speed (if Performance test speed is different than MCS). The procedure for applying the excitation shall be according to item 6.3.8.5.

6.3.8.2.2 (New) Measurement During Pressurized Test The stability measurement during the Pressurized Test is defined as the measurement of the log decrement of the machine for a specific cross-coupling, calculated taking in account the pressure and speed during the test, for one chosen point. The Pressurized Test may be a performance test according to ASME PTC-10 or a full pressure test (if specified). For an ASME PTC-10 type II test, the procedure shall consider the following premises:

a) after determination of the first surge point, the capacity flow rate shall be increased in order to remain in safe region; b) there shall be a delay, waiting for system stabilization (pressures, temperatures, flow rates, bearing temperatures and shaft centerline); c) the test conditions shall be chosen by manufacturer such that estimated cross-coupling be, at least, 20% of the cross-coupling calculated according to item 4.8.6.8 d. For boundary conditions where such margin cannot be accomplished, the test point shall be the highest feasible; d) the excitation shall be started as per item 6.3.8.5.

For an ASME PTC-10 type I test or full pressure test, the procedure shall consider the following premises:

a) maximum pressure shall be achieved. Purchaser and the manufacturer may agree and define other intermediate points; b) there shall be a delay, waiting for system stabilization (pressures, temperatures, flow rates, bearing temperatures and shaft centerline); c) the excitation shall be started as per item 6.3.8.5.

6.3.8.3 (New) Preparation for the Test

6.3.8.3.1 (New) When an active magnetic bearing is used for the excitation, its assembly on the shaft shall not significantly change the rotor response characteristics. The manufacturer shall submit for purchaser approval the proposed device and the expected changes in the rotor response prior to the test. The equipment measured unfiltered vibration, during the mechanical running and performance tests, with the assembled device, before applying any load, shall not exceed the limits of item 4.8.8.8. The manufacturer shall send a procedure informing how the AMB will be adjusted/calibrated and how the applied force will be measured. Prior to the tests, the

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accuracy of input force measurements shall be verified. The manufacturer shall submit the AMB calibration report for purchaser review.

6.3.8.3.2 (New) The manufacturer shall present, prior to the test, the calculated log decrement for the forward and backward modes at actual test conditions (Qf), such as bearing clearance, preload and test speed (for ASME PTC-10 type II test, the test speed may be different from maximum continuous speed).

6.3.8.3.3 (New) The data collect system shall consist as a minimum of an Oscilloscope, a Real Time Analyzer and a Data Recorder (analog or digital) with capability of continuously collecting all probes data and input signals. The sampling rate of the system shall be enough to identify the excitation frequencies and the results.

6.3.8.3.4 (New) The manufacturer shall present in the lateral vibration report, the expected orbits for both modes (forward and backward) at MCS, from zero to the maximum expected cross-coupling (0 %, 50 %, 100 %) for the average clearance case. The definition of excitation direction shall be based in those orbits.

6.3.8.3.5 (New) If a sine sweep method is used to identify the actual forward and backward frequencies, the frequency interval of each sine sweep shall be less or equal to 0.25 Hz.

6.3.8.4 (New) Signal Quality

6.3.8.4.1 (New) In order to have good response when applying the excitation, the Signal to Noise Ratio (SNR) shall be at least two. The amplitude of excitation shall be controlled in order to not exceed an agreed amount of bearing clearances for safety and linearity concerns.

6.3.8.4.2 (New) If the manufacturer decides to apply filtering to eliminate the synchronous response, the type of filter shall be informed to Purchaser. The design of the filter shall not influence the signal components of interest.

6.3.8.5 (New) Any measured point (forward and backward) shall be calculated from an average of at least five readings. These five readings shall be in the range of:

0.03 0.03 - +≤≤mim

δδδ , where

5

54321δδδδδδ ++++=

m

If any value falls outside the above defined range, it shall be discarded and measured again.

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The average value (m

δ ) will be used to compare with the predicted values.

6.3.8.6 (New) Acceptance Criteria

6.3.8.6.1 (New) Model Verification

If the measured value is above the predicted one, no correction in the model is necessary. The vendor shall correct the model if it fails to meet the following criteria: Any expected log decrement for the forward mode, for both cases (base stability and performance test conditions), calculated according 6.3.8.3.2, shall be inside the range of the measured log decrement (

mδ ± 0.03).

6.3.8.6.2 (New) Test Acceptance

The highest difference between the expected value and the measured log decrement (��) for each case (base stability and pressurized test conditions) will be the correction factor (��) to be applied to the calculated log decrement (��) for the worst condition (see item C.1.k Part 1) at maximum continuous speed and design pressure (see figure below). The equipment acceptance criteria shall be that the final corrected log decrement (��′), at worst condition (see item C.1.k Part 1), is greater than 0.1.

Figure 1 - Applied Cross-Coupled Stiffness, Q KN/mm (Klbf/in.)

Where: Qt: calculated cross-coupled stiffness at test conditions (see 6.3.8.3.2); Qf: calculated cross-coupled stiffness at maximum continuous speed, design pressure and worst conditions (see item C.1.k Part 1). NOTE The example in the curve above is only illustrative; no curve shape correction will be applied.

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PART 2 – NON-INTEGRALLY GEARED CENTRIFUGAL AND AXIAL COMPRESSORS 6 – INSPECTION, TESTING, AND PREPARATION FOR SHIPMENT

6.3 Testing

6.3.1 Mechanical Running Test

Replace Figure 4 of API Std 617 Part 2 by the following figure:

Figure 4 - Mechanical Running Test Sequence

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6.3.5.2.3 (New)

The shop vibration equipment used during the tests shall be configured in accordance with Annex C of this standard. All cables shall be identified. ADRE system is preferred for data collecting and monitoring. If vendor uses another system, then visualization (or translation into ADRE files) software shall be included as well.

6.3.1.2.10 (New) During the mechanical running test the measured unfiltered vibration amplitude shall not exceed, at any speed from zero to the minimum operating speed, the limit stablished in item 2.6.8.8 of Chapter 1 or the amplitude at probe locations in which the calculated major-axis, peak-to-peak, unbalanced rotor response amplitude reaches 50% of the minimum design diametral running clearance at any point throughtout the machine, whichever is greater.

6.3.3.1 Factory Performance Test

6.3.3.1.10 (New) During the performance test, the bearing temperatures limits used as acceptance criteria for mechanical running test shall also be applied. During the performance test, the following vibration limits shall apply for all points in the compressor operating range: a. The measured unfiltered vibration shall not exceed the limits of 2.6.8.8 of Chapter 1. b. The amplitude of any discrete, supersynchronous vibration shall not exceed 20% of the allowable vibration as defined in 2.6.8.8 of Chapter 1. c. The amplitude of any discrete, subsynchronous vibration shall not exceed 0.1 micron or the following value, whichever is greater:

where A = amplitude of unfiltered vibration, as defined in item 2.6.8.8 of Chapter 1. rho-t = gas density at the compressor suction in test conditions. rho-d = gas density at the compressor suction in design conditions. Note: Any point located in the area defined by the minimum compressor running speed, the maximum continuous running speed, the anti-surge control line and the compressor capacity limit (Stonewall limit) is considered to be within the compressor operating range. PRELIM

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INERT GAS COMPRESSOR RUNNING TEST

1. Inert Gas Compressor Running (IGCR) test shall be performed during onshore SAT. During the IGCR test, start-ups, operation and shutdowns shall be performed by means of compressor HMI. All compressor valves alignments shall be carried out as if normal operation alignments, except for the two manual valves, one upstream of the inlet SDV and the second downstream of the discharge SDVs, which shall be closed.

1.1. The IGCR test will be performed with inert gas. The inert gas shall be a mixture of N2, CO2 and He. The test conditions regarding proportion of gases, volumetric flowrate, pressures and temperatures shall be defined in order to avoid modifications in the compressor package (i.e., layouts, piping, controls, dry gas seal system, etc.).

1.2. IGCR Test shall be performed with the same compressor package instruments (i.e., pressure, temperature, flow, level, etc.) installed for its final location (offshore). Instrument ranges shall not be modified, if possible.

1.3. PACKAGER shall propose the IGCR test operating condition as an additional case in the compressor datasheet during the proposal phase including the related performance curves and its duration. Since the purpose of test is to check the system integrity, the operating pressures and the consumed power may be minimal in order to avoid modifications in the compressor package (i.e., layouts, piping, controls, dry gas seal system, etc.).

1.4. The compressor package control and interlocking shall not be changed nor adapted for the IGCR test, if possible. Set points and delays may be readjusted to run the tests and returned to the original values after the tests have finished. The alarm set points (L and H) and shutdown (LL and HH) shall not be changed for the IGCR test.

1.5. The inert gas injection during the test shall be performed between the manual valve and the inlet package SDVs.

1.6. During the IGCR test, AS valve may be substituted by a removable spool with orifice plate. BIDDER is responsible to fabricate and to install the spool. Therefore, the compressor PACKAGER shall inform orifice plate the dimension in the detail phase. In case of AS valve substitution, AS valve shall be conditioned and preserved in a proper location to return in perfect working conditions.

1.7. During the IGCR test, all the HMIs available variables shall be stored, and at the end of the test, media shall be provided with the variables stored. The programming and configuration of PLCs and other controllers such as Machine Protection System (MPS), Machine Monitoring System (MMS), Anti-surge, Load-Sharing and Capacity systems shall also be provided.

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1.8. Two programmed stops shall be performed. The pressurized stop shall be the first (forced trip) and the second as a normal stop. It shall be considered the maximum admissible electric motor starts and its thermal image for each new start.

1.9. The test shall be reinitialized:

• In case of non programmed/planned stop during the test;

• If necessary any program control adjustment or machine intervention (e.g., opening the compressor casing) including their auxiliary systems.

1.10. The criteria to approval the IGCR test are:

• The variables vibration signals, displacement and bearing temperatures of the whole train (compressor(s) casing(s), gearbox/HVSD (Hydraulic Variable Speed Drive) and electric motor) shall not exceeds 80% of monitored variable alarm set point.

• Seal Gas and oil systems: no variable shall display low alarm nor exceed 80% of monitored variable alarm set point.

• Compression System: no variable alarm set point may be reached.

1.11. The mixture of inert gas (N2,O2 and He) as defined in the compressor datasheet shall be supplied by BIDDER.

1.12. The compressor suction strainer to be used during the test shall have the same mesh required to execute the commissioning and start-up of natural gas compression system.

1.13. The IGCR Test Procedure shall be issued by BIDDER for entire package, including the machine test procedure issued by the Compressor PACKAGER.

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PETROBRAS PETRÓLEO BRASILEIRO SA

C O M M E N T S A N D D E V I A T I O N S T O A P I S T D 6 1 7 A N D N I - 2 6 2 6 TECHNICAL SPECIFICATION I-ET-0000.00-0000-321-PPM-002

SHEET 1 of 192 REVISION 0 DATE 26/09/2014

CLIENT: PROGRAM: UNIT:

- Standardization of Goods and Services -

DISCIPLINE: Rotating machinery MATERIAL/ITEM: Centrifugal compressor (API Std 617, Ch. 2)

CENPES/EB-AB-G&E/AEDC

GROUP: Centrifugal compressor standardization REFERENCE: MATERIAIS/OGBS/PDR 10/2012 SUBJECT: Discussion on Vendors’ comments and deviations

STANDARD REQUIREMENT AND VENDOR’S COMMENT COMMENTS, REPLIES, CONCLUSION REMARKS V API Std 617, 7 th edition – Axial and centrifugal compressors and expander-compressors for petroleum, chemical and gas industry services General comments

-

Drawings. VENDOR: [1] Drawings are in accordance with VENDOR works standard (extract of DIN). [2] Documentation (schedule / content) as mutually agreed upon.

PETROBRAS: [1] VENDOR is allowed to render documentation according to VENDOR's proprietary format, provided that: a) ALL required information and data contents are furnished as specified; b) PETROBRAS' job logo is included (VENDOR’S DWG may be pasted onto PETROBRAS' blank drawing template or form); c) PETROBRAS' requirements on drawings and documents size and format are followed. d) Minimum contents to be submitted for review / comments / approval and submission schedule to follow list of minimum documents required for the accomplishment of contract milestones, as provided by Material Requisition. [2] Proposal document list shall provide a table of equivalence between PETROBRAS’ list and VENDOR’s, regarding document names and contents. VENDOR: [1] Confirmed for project execution phase. [2] Confirmed. PETROBRAS: Noted.

Closed 600

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STANDARD REQUIREMENT AND VENDOR’S COMMENT COMMENTS, REPLIES, CONCLUSION REMARKS V

-

Electrical components and installations. VENDOR: All electrical components and installations comply with applicable DIN and VDE-Standards. Cables are mechanically protected by open metal conduits or cable trays; no closed conduit system with pull boxes, sealing etc. is provided. Electrical components in zone 1 and 2 or areas will be supplied and installed according to IEC (DIN EN) 60 079-14 ‘Electrical apparatus in explosive gas atmospheres’, using appropriate certified equipment according to VDE 0170-1-VDE 170-7 / VDE 171 standards, if not otherwise stated by VENDOR.

PETROBRAS: Basically electrical equipment and systems to follow IEC standards and Brazilian local regulations. Rotating electrical machines (mechanical requirements) to follow API standards. VENDOR #600: Confirmed however if IEC or any Brazilian regulations may require closed conduit it will result in extra cost.

PETROBRAS: All costs and schedule impacts to be considered during bid stage, i.e., to be included in VENDOR’s proposal. VENDOR #300: Agreed with comments. Requirement for cable protection shall be clearly stated in the project specification. PETROBRAS: Noted.

Closed 600

-

Physical and chemical ‘data’ certificates and calculations. VENDOR: Physical and chemical data certificates and calculations are conform to the design code selected, e. g. DIN, ASME etc.

PETROBRAS: Acceptable provided that certificates and calculations are equivalent to or better than those required by API. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

-

Referenced API standards. VENDOR: All referenced API Standards such as 613, 614, 670, 671, apply with VENDOR or the subsuppliers’ exceptions.

PETROBRAS: Noted. Since VENDOR and its subsuppliers' deviations have been analyzed by this Working Group. VENDOR: OK. PETROBRAS: Noted.

Closed 600

Chapter 1 – General requirements

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STANDARD REQUIREMENT AND VENDOR’S COMMENT COMMENTS, REPLIES, CONCLUSION REMARKS V Item Section 1 – General

1.4

The SI system of units and dimensions are used in this standard. Any data or drawings related to equipment supplied to this standard shall use the SI system. Alternate systems such as the U.S. Customary system may be used if specified. VENDOR: Unless otherwise noted, VENDOR will provide documents with SI units only when purchaser provides SI Data Sheets. By design, this machine has U.S. customary flanges and threads.

PETROBRAS: Units shall be as stated on the data sheets, except for piping and appurtenances, to be customary. VENDOR: VENDOR confirms compliance. PETROBRAS: Noted.

Closed 200

1.4

The SI system of units and dimensions are used in this standard. Any data or drawings related to equipment supplied to this standard shall use the SI system. Alternate systems such as the U.S. Customary system may be used if specified. VENDOR: Due to the reason of sub-supplier’s standard documents, MKS units may be used.

PETROBRAS: Units shall be as stated on the data sheets, except for piping and appurtenances, to be customary. VENDOR: Agreed to PETROBRAS’ comment. PETROBRAS: Noted.

Closed 300

1.5.54

Witnessed tests and inspections: Those to which a hold shall be applied to the production schedule and that the inspection or test shall be carried out with the purchaser or his representative in attendance. For mechanical running or performance tests, this requires written notification of a successful preliminary test. VENDOR: Exception: Preliminary testing and notification to be mutually agreed.

PETROBRAS: Exception not accepted. VENDOR #300: We have the same comment. VENDOR #800: To be complied. PETROBRAS: Exception on advanced notice not acceptable – contract schedule to be followed. PETROBRAS may accept (and usually does so) to attend in-house testing in order to reduce schedule.

Closed 800

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1.6, 1.6.1

1.6. Normative references. 1.6.1. Referenced publications are listed in Annex 1A. VENDOR: [1] All materials will be in accordance with JIS, DIN, ASME or equivalent unless otherwise noted in vendor’s proposal. Material inspection will be in accordance with JIS and vendor standards to be submitted for approval. [2] Screws and threads for machine will be in accordance with ISO metric standards. [3] The flanges with ANSI size and JIS material are provided. [4] Piping shall be in accordance with JIS standards which specify the same thickness as ANSI with small discrepancy of inner diameter. [5] No spot RT for all butt-welded part for pipings are applied. [6] Compressor casing are designed (strength calculation) in accordance with ASME Sec. VIII, but not code stamped. [7] Welding and repairing procedure will be in accordance with manufacturer’s standards and/or ASME section IX. [8] Welding and repairing of casing will be performed by welder’s qualified in accordance with JIS and/or JPI. [9] Welding of non-pressure containing parts such as baseplate & structural parts will be performed with manufacturer’s standard.

PETROBRAS: [1] Acceptable provided that materials are equivalent to or better than ASTM/ASME. Equivalence table in English text to be included in proposal. [2] Acceptable. Except for piping and appurtenances, where customary units shall prevail. Companion flanges shall always be included in VENDOR's scope of supply. [3] Acceptable provided that materials are equivalent to or better than ASTM/ASME. Equivalence table in English text to be included in proposal. [4] Acceptable. [5] Basically unacceptable. VENDOR to comply with applicable API and job specifications. Spot RT only will not suffice, VENDOR to propose before the order equivalent examinations. [6] Acceptable. [7] Not acceptable. VENDOR's experience, alternate methods and criteria will always be considered by PETROBRAS, provided they have been previously discussed and accepted by PETROBRAS (before the order). Otherwise, PETROBRAS will strictly follow API 617 requirements together with the amendments of its standards and technical specifications. [8] Welders, WPS and PQR shall be qualified by Third Party. This organization shall be according to ISO/IEC 17024. For inspectors in charge of generating WPS, PQR, and welder qualifications, besides ISO/IEC 17024, it shall be required a previous approval of qualification by PETROBRAS. Regarding welding of non-pressure containing parts, VENDOR´s standard will be acceptable if in accordance with AWS as a minimum. [9] Acceptable.

Continues below

300

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1.6, 1.6.1

(Continuation of the question above.)

VENDOR: [1] Agreed to PETROBRAS' comment. [2] Agreed to PETROBRAS' comment. [3] Agreed to PETROBRAS' comment. [4] OK [5] Agreed to PETROBRAS' comment. [6] OK. [7] Agreed to PETROBRAS' comment. [8] Vendor's comments is modified as follows: [8a] Welders, WPS and PQR will be qualified by third party qualified by each country’s organization or ASME Sec. IX. [8b] For inspectors in charge of generating WPS, PQR, and welder qualifications, besides ISO/IEC 17024, it shall be required a previous approval of qualification by PETROBRAS. [8c] Regarding welding of non-pressure containing parts, VENDOR´s standard in accordance with ASME section IX is proposed. [9] OK. PETROBRAS: [8a] The Third Party organization shall be qualified by ISO/IEC 17024 for each country. Third Party organizations without such certification will not be accepted. [8b] ISO/IEC 17024 is applied to Third Party organizations which qualify the inspectors. Third Party organizations without such certification will not be accepted. [8c] Noted. VENDOR: [8a][8b] Welders, WPS and PQR will be qualified by ASME Sec. IX. PETROBRAS: Noted. It is PETROBRAS understanding that VENDOR’s reply meaning is as follows: Welders, WPS and PQR will be qualified by Third Party organization (as per ISO/IEC 17024 directives) in accordance with ASME Sec. IX criteria.

Closed 300

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1.6.4

The editions of the Annex 1A standards, codes, and specifications that are in effect at the time of publication of this standard shall, to the extent specified herein, form a part of this standard. The applicability of changes in standards, codes, and specifications that occur after the inquiry shall be mutually agreed upon by the purchaser and the vendor. VENDOR: Standard elements, such as nuts, bolts, washers, keys, tapers, springs, internal flanges, etc., are metric, in accordance with DIN and ISO standards.

PETROBRAS: Deviation not applicable. PETROBRAS applies last editions up to the date of contract. VENDOR: Noted. However VENDOR wants to highlight that the mentioned standard elements will be according EN standard and not according US standards. PETROBRAS: Noted regarding the use of last editions of DIN and/or ISO standards. However, PETROBRAS wants to highlight that the use of metric units is not allowed for piping and appurtenances. VENDOR to refer to PETROBRAS’ answer to item 1.4.

Closed 400

1.6.5

The purchaser will specify whether equipment supplied to this standard shall comply with the applicable ISO standards or applicable U.S. standards. VENDOR: For materials, piping and threading ISO, DIN or U.S. standards apply.

PETROBRAS: Acceptable provided that materials are equivalent to or better than ASTM/ASME. Equivalence table to be included in proposal. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

1.7

The purchaser and the vendor shall mutually determine the measures that must be taken to comply with any governmental codes, regulations, ordinances, or rules that are applicable to the equipment. VENDOR: PURCHASER shall advise to vendor applicable governmental codes, regulations, ordinances or rules for this project before the order.

PETROBRAS: PETROBRAS will specify applicable specifications including local codes on the Material Requisition. VENDOR: Agreed to PETROBRAS’ comment. PETROBRAS: Noted.

Closed 300

Item Section 2 – Basic design PRELIMIN

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2

Basic design. VENDOR: Machined connections on casing, not including process connections, are bolted (cap screws) not studded.

PETROBRAS: Cap screws shall not be used indiscriminately on casing machined connections. Exceptions to be discussed, case by case. VENDOR to provide additional justification, considering space limitations and assembly/disassembly issues. VENDOR: At additional cost, machined connections can be provided, with exception of the sheer rings and the end covers. PETROBRAS: All costs and schedule impacts to be considered during bid stage, i.e., to be included in VENDOR’s proposal.

Closed 100

2.1.2

The equipment (including auxiliaries) covered by this standard shall be designed and constructed for a minimum service life of 20 years and at least 5 years of uninterrupted operation. Note: It is recognized that this is a design criterion. VENDOR: [1] This requirement is normally not a problem for the centrifugal compressor. [2] However actual time between overhaul may depend on factors beyond VENDOR control. [3] Design criteria for auxiliaries shall be as mutually agreed.

PETROBRAS: [1] Noted. [2] To be discussed. [3] Not acceptable. Secondary equipment failure shall not compromise main equipment performance/life. VENDOR: [1] OK. [2] Agreed. [3] It's confirmed that secondary equipment failure shall not compromise main equipment performance/life however the design rules shall be mutually agreed within the technical clarifications. PETROBRAS: [1] Noted. [2] Noted. [3] Discussions to be held during bid stage considering changes of scope of supply, design rules, and redundancy requirements.

Closed 600

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2.1.5.1

A cooling water system or systems shall be designed for the following conditions… VENDOR: Design condition of gas coolers are in accordance with related data sheet or project specification.

PETROBRAS: Noted, regarding site data. Everything else as per API Std 617 criteria. VENDOR: Agreed to PETROBRAS' comment. PETROBRAS: Noted.

Closed 300

2.1.5.1

A cooling water system or systems shall be designed for the following conditions… VENDOR: Temperature rise 6 K in accordance with VENDOR standard.

PETROBRAS: Not acceptable. API Std 617 criteria shall be followed. VENDOR: Please consider that this topic is also covered by API 614, where further explanation is given about handling temperature rise. The requirement of 10 K is rather a guideline, which sometimes should not be followed, since other considerations (e.g. fouling) may be in conflict to it. Please refer to API 614 5th Ed., Part 2, item 4.5.1.9. PETROBRAS: API Std 614, part 2, item 4.5.1.9: The vendor shall notify the purchaser if the criteria for minimum temperature rise and velocity over heat-exchange surfaces result in a conflict. The criterion for velocity over heat-exchange surfaces is intended to minimize water-side fouling; the criterion for minimum temperature rise is intended to minimize the use of cooling water. The purchaser shall approve the final selection. PETROBRAS base requirements follow API specifications. It is PETROBRAS understanding that, for shell-and-tube exchangers, the number of tubes shall be established according to velocity criterion, which shall prevail. However, in case of potential conflicts, VENDOR to submit exchanger selection and calculations to PETROBRAS for review and approval during bid stage, as per the very same item mentioned by VENDOR.

Closed 600

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2.1.6

The arrangement of the equipment, including piping and auxiliaries, shall be developed jointly by the purchaser and the vendor at or before the coordination meeting. Note: The arrangement should consider adequate clearance areas and safe access for operation and maintenance. VENDOR: The VENDOR package is provided in a standard arrangement of equipment, piping, and auxiliaries. The PURCHASER can make only minor changes to this configuration.

PETROBRAS: Any standard arrangement not compliant with API requirements or PURCHASER's specifications shall be clearly stated on the proposal. Otherwise such deviations will not be considered by PETROBRAS. VENDOR: Noted. VENDOR arrangement complies with API requirements and customer arrangements when provided. PETROBRAS: Noted.

Closed 100

2.1.6

The arrangement of the equipment, including piping and auxiliaries, shall be developed jointly by the purchaser and the vendor at or before the coordination meeting. Note: The arrangement should consider adequate clearance areas and safe access for operation and maintenance. VENDOR: The bid is based on the general arrangement in the proposal.

PETROBRAS: The bid is based on the scope of supply stated on the Material Requisition and its attachments, including suggested general arrangements. VENDOR: Noted. PETROBRAS: Noted.

Closed 600

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NI-2626, 6.2.1.2

Substitution (2.1.9 of API Std 617). Unless otherwise specified, the whole train furnished by the vendor (compressor, driver, gear and auxiliary equipment) shall conform to the maximum allowable sound pressure level of 85 dBA, slow-response, measured at 1 m (3.28 ft) from the equipment surfaces. Unless otherwise specifically stated on the data sheets, noise level tests need not to be performed. On the other hand, bidder/vendor shall guarantee that equipment actual sound pressure level will remain within allowable limits, informing in his proposal the expected or guaranteed maximum sound pressure level of quoted equipment and including copies of noise level test certificates performed on similar equipment. VENDOR: Noise requirements of 85 dB(A) shall apply for the compressor train including driver and gearbox. However since anti-surge valves will not open during normal operation, VENDOR standard for these valves of 100 dB(A) will apply.

PETROBRAS: Noted. VENDOR: OK.

Closed 600

2.1.13

Many factors (such as piping loads, alignment at operating conditions, supporting structure, handling during shipment, and handling and assembly at the site) may adversely affect site performance. To minimize the influence of these factors, the vendor shall, when requested, review and comment on the purchaser’s piping and foundation drawings. When specified, the vendor’s representative shall: a. Observe a check of the piping performed by parting the flanges. b. Check alignment at the operating temperature. c. Be present during the initial alignment check. VENDOR: When reviewing PURCHASER’s piping and foundation drawings VENDOR’S responsibility shall be confined to the equipment supplied by the VENDOR.

PETROBRAS: Noted. Design approval is not usually required but advice on arrangement is requested, especially when precluding equipment performance and/or life. When specified in contract, design approval of third parties shall be performed by the VENDOR. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

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2.1.13

Many factors (such as piping loads, alignment at operating conditions, supporting structure, handling during shipment, and handling and assembly at the site) may adversely affect site performance. To minimize the influence of these factors, the vendor shall, when requested, review and comment on the purchaser’s piping and foundation drawings. When specified, the vendor’s representative shall: a. Observe a check of the piping performed by parting the flanges. b. Check alignment at the operating temperature. c. Be present during the initial alignment check. VENDOR: VENDOR will only comment on dimensional compatibility with own furnished equipment. Design approval is neither expressed or implied.

PETROBRAS: Noted. Design approval is not usually required but advice on arrangement is requested, especially when precluding equipment performance and/or life. When specified in contract, design approval of third parties shall be performed by the VENDOR. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

2.1.15

Spare parts for the machine and all furnished auxiliaries shall meet all the criteria of this standard. VENDOR: Please replace the first part of the sentence by: ‘Spare parts of the machine and spare parts of all furnished auxiliaries shall meet...’

PETROBRAS: Not acceptable. API Std 617 text on this item to be followed. Additional comments within this technical specification shall also apply. VENDOR: Confirmed. Comment will be withdrawn. PETROBRAS: Noted.

Closed 600

2.1.16

When specified, the machine or machines shall be suitable for field run on air. Performance parameters, including any required precautions, shall be mutually agreed upon by the purchaser and the vendor. VENDOR: Volume reduction and/or sealing system and/or discharge temperature may prevent compressor from running on air.

PETROBRAS: Noted. VENDOR: Acknowledged.

Closed 200

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2.1.16

When specified, the machine or machines shall be suitable for field run on air. Performance parameters, including any required precautions, shall be mutually agreed upon by the purchaser and the vendor. VENDOR: When air test run at site is specified, test procedure and limitation will be discussed and stipulated in mutual meeting at detail engineering stage.

PETROBRAS: Noted. Any additional instrumentation or equipment required for testing to be included in proposal. VENDOR #300: Agreed to PETROBRAS’ comment. VENDOR #200: Although this VENDOR did not make this original comment, VENDOR clarifies that no additional instrumentation or equipment associated with a field run in on air is included in the scope of supply. VENDOR requests that the instrumentation and equipment to be quoted be specifically defined by PETROBRAS. PETROBRAS: Field run-in on air is just a functioning test, where no excessive work is done. Hence, by no means, shall be considered a field performance verification, which, in fact, would require additional instrumentation and equipment. PETROBRAS does not require any additional instrumentation or equipment during ordinary air run-in tests. Field instrumentation will suffice. Please disregard PETROBRAS’ comment above.

Closed 300

NI-2626, 6.2.1.4

Substitution (2.1.16 of API Std 617). Compressors shall be suitable for field run on air. Performance parameters, including required precautions shall be indicated by vendor and are subject to PETROBRAS approval. If a test run on air is not feasible, vendor shall indicate alternative procedure. Additional equipment required for the field test run shall be quoted separately. VENDOR: Compressors data sheets will show a test run on air indicating any precautions.


Closed 600

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2.2.1.1

Materials of construction shall be the manufacturer’s standard for the specified operating conditions, except as required or prohibited by the data sheets or by this standard. Annex 1E lists material specifications that, when used with appropriate heat treatment or impact testing requirements, or both, are generally considered acceptable for major component parts. The metallurgy of all major components shall be clearly stated in the vendor’s proposal. See 3.5 for requirements for auxiliary piping materials. VENDOR: Japanese Industrial Standard (JIS) materials are used for components of the proposed compressors.

PETROBRAS: Acceptable provided that materials are equivalent to or better than ASTM/ASME. Equivalence table to be included in proposal. VENDOR: Confirmed, equivalent materials of ASTM/AISI are indicated on compressor datasheet. PETROBRAS: Noted.

Closed 500

2.2.1.2

Materials shall be identified in the proposal with their applicable ASTM, AISI, ASME, or SAE numbers, including the material grade (see Annex 1E). When no such designation is available, the vendor’s material specification, giving physical properties, chemical composition, and test requirements, shall be included in the proposal. VENDOR: Materials are identified with their applicable EN numbers. Equivalents to ASTM, AISI, ASME and SAE standards are for reference only.

PETROBRAS: Acceptable provided that materials are equivalent to or better than ASTM/ASME. Equivalence table to be included in proposal. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

2.2.1.2

Materials shall be identified in the proposal with their applicable ASTM, AISI, ASME, or SAE numbers, including the material grade (see Annex 1E). When no such designation is available, the vendor’s material specification, giving physical properties, chemical composition, and test requirements, shall be included in the proposal. VENDOR: Materials will be identified with their designation and number according to European, German or U.S. material standards.

PETROBRAS: Acceptable provided that materials are equivalent to or better than ASTM/ASME. Equivalence table to be included in proposal. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

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2.2.1.5

Low-carbon steels can be notch sensitive and susceptible to brittle fracture at ambient or lower temperatures. Therefore, only fully killed, normalized steels made to fine grain practice are acceptable for machine components. The use of steel made to a course austenitic grain size practice (e.g., ASTM A-515) is prohibited. VENDOR: VENDOR will apply the requirements of this paragraph to pressure containing machine components only.

PETROBRAS: Not acceptable. Exposed (either static, rotating or pressure containing) or affected parts shall be considered regarding the use of fully killed normalized steels. VENDOR: Exposed part will consider the use of fully killed, normalized steels. Only pressure containing parts shall be impact tested. PETROBRAS: Noted.

Closed 200

2.2.1.5

Low-carbon steels can be notch sensitive and susceptible to brittle fracture at ambient or lower temperatures. Therefore, only fully killed, normalized steels made to fine grain practice are acceptable for machine components. The use of steel made to a course austenitic grain size practice (e.g., ASTM A-515) is prohibited. VENDOR: Exception: Items such as casing supports, diaphragms, inner barrels and other miscellaneous non-pressure parts are not constructed of fully killed normalized steels.

PETROBRAS: Not acceptable. Exposed (either static, rotating or pressure containing) or affected parts shall be considered regarding the use of fully killed normalized steels. VENDOR #300: Agreed except rotating parts. VENDOR #800: To be complied. PETROBRAS: PETROBRAS re-states previous comment. VENDOR #300’s comment was disregarded.

Closed 800

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2.2.1.6

Materials exposed to a sour environment (wet H2S) as defined by NACE MR0175 shall be in accordance with the requirements of that standard. Ferrous materials not covered by NACE MR0175 shall not have a yield strength exceeding 620 N/mm2 (90,000 psi), nor a hardness exceeding Rockwell C 22. Components that are fabricated by welding shall be postweld heat treated, if required, so that both the welds and heat-affected zones meet the yield strength and hardness requirements. Note 1: It is the responsibility of the purchaser to determine the amount of wet H2S that may be present, considering normal operation, start-up, shutdown, idle standby, upsets, or unusual operating conditions such as catalyst regeneration. Note 2: In many applications, small amounts of H2S are sufficient to require materials resistant to sulfide stress corrosion cracking. When there are trace quantities of wet H2S known to be present or if there is any uncertainty about the amount of wet H2S that may be present, the purchaser should consider requiring materials that are resistant to sulfide stress corrosion cracking. Note 3: Shafts in compressors of between-bearing design may exceed the stated limits of yield strength and hardness because of requirements for higher strength at reduced shaft sections near couplings and because of the low levels of working stress in the portion of the shaft between bearings. VENDOR: Hardness testing is conducted at random to ensure the hardness requirements of VENDOR’s specifications are met. Hardness testing on every component is not conducted; for example, the energizing metal spring inside the polymer seals complies with NACE chemistry and hardness requirements, but is not age hardened.

PETROBRAS: Not acceptable. VENDOR #300: Not agreed. PETROBRAS: PETROBRAS re-states comment above.

Closed 100

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2.2.1.6

Materials exposed to a sour environment (wet H2S) as defined by NACE MR0175 shall be in accordance with the requirements of that standard. Ferrous materials not covered by NACE MR0175 shall not have a yield strength exceeding 620 N/mm2 (90,000 psi), nor a hardness exceeding Rockwell C 22. Components that are fabricated by welding shall be postweld heat treated, if required, so that both the welds and heat-affected zones meet the yield strength and hardness requirements. Note 1: It is the responsibility of the purchaser to determine the amount of wet H2S that may be present, considering normal operation, start-up, shutdown, idle standby, upsets, or unusual operating conditions such as catalyst regeneration. Note 2: In many applications, small amounts of H2S are sufficient to require materials resistant to sulfide stress corrosion cracking. When there are trace quantities of wet H2S known to be present or if there is any uncertainty about the amount of wet H2S that may be present, the purchaser should consider requiring materials that are resistant to sulfide stress corrosion cracking. Note 3: Shafts in compressors of between-bearing design may exceed the stated limits of yield strength and hardness because of requirements for higher strength at reduced shaft sections near couplings and because of the low levels of working stress in the portion of the shaft between bearings. VENDOR: VENDOR employs a proprietary heat treatment process for 17-4 pH impellers that has been qualified by NACE after testing per their protocol. It fully meets the hardness limits of NACE MR0175 / ISO 15156-3.

PETROBRAS: Noted. Certificates (within validity period) of particular qualifications shall be submitted for PETROBRAS approval during proposal stage. VENDOR #200: Acknowledged. VENDOR #300: Not applicable. PETROBRAS: Noted for VENDOR #200 (internal certificates will be provided). Noted for VENDOR #300 (internal certificates are not applicable). Third Party certificates to be provided instead.

Closed 200

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2.2.1.6

Materials exposed to a sour environment (wet H2S) as defined by NACE MR0175 shall be in accordance with the requirements of that standard. Ferrous materials not covered by NACE MR0175 shall not have a yield strength exceeding 620 N/mm2 (90,000 psi), nor a hardness exceeding Rockwell C 22. Components that are fabricated by welding shall be postweld heat treated, if required, so that both the welds and heat-affected zones meet the yield strength and hardness requirements. Note 1: It is the responsibility of the purchaser to determine the amount of wet H2S that may be present, considering normal operation, start-up, shutdown, idle standby, upsets, or unusual operating conditions such as catalyst regeneration. Note 2: In many applications, small amounts of H2S are sufficient to require materials resistant to sulfide stress corrosion cracking. When there are trace quantities of wet H2S known to be present or if there is any uncertainty about the amount of wet H2S that may be present, the purchaser should consider requiring materials that are resistant to sulfide stress corrosion cracking. Note 3: Shafts in compressors of between-bearing design may exceed the stated limits of yield strength and hardness because of requirements for higher strength at reduced shaft sections near couplings and because of the low levels of working stress in the portion of the shaft between bearings. VENDOR: Shaft material has a nickel content higher than 1% (from 1.65% to 2%), which is the maximum value stated by NACE requirements for carbon and low alloy steels.

PETROBRAS: Noted. Certificates (within validity period) of particular qualifications shall be submitted for PETROBRAS approval during proposal stage. VENDOR #300: Since shaft material is not in contact with process gas, NACE requirement is not applicable to shaft material. PETROBRAS: All exposed parts, rotary or static, shall comply with such requirement.

Closed 900

2.2.1.8

Austenitic steels shall not be used in services where stress-corrosion cracking is a possibility. VENDOR: This paragraph shall be applicable only in presence of stress-corrosion cracking due to chlorides.

PETROBRAS: Noted.

Closed 900

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2.2.1.13

O-ring materials shall be compatible with all specified services. Special consideration shall be given to the selection of O-rings for high-pressure services to ensure that they will not be damaged upon rapid depressurization (explosive decompression). Note: Susceptibility to explosive decompression depends on the gas to which the O-ring is exposed, the compounding of the elastomer, temperature of exposure, the rate of decompression, and the number of cycles. VENDOR: VENDOR recommends that rapid depressurization shall be avoided and controlled by process side. Allowable depressurization rate will be discussed and agreed at the detail engineering stage.

PETROBRAS: PETROBRAS base requirement is as per API RP 520 and RP 521. The design criterion for depressurization time shall be up to 15 minutes (reaching 690 kPa pressure or half the initial pressure, whichever is lower). VENDOR: Agreed to PETROBRAS’ comment.

Closed 300

2.2.1.15

Low temperature. VENDOR: VENDOR will apply the paragraphs in this section to pressure casings only.

PETROBRAS: Not acceptable. VENDOR: VENDOR will only apply the impact testing requirements to pressure containing parts of the compressor. The impact testing requirements of this paragraph refer to ASME Section VIII, Division I which specifically applies to pressure containing parts. PETROBRAS: Parts exposed to, or affected by, low temperatures (static, rotating, pressure containing, nozzles, studs, nuts, etc.) shall be considered regarding low temperature requirements. VENDOR: For low temperature applications, all parts exposed to or affected by low temperature shall be considered for low temperature applications. For other applications, only pressure containing parts shall be impact tested. PETROBRAS: Noted.

Closed 200

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2.2.1.15

Low temperature. VENDOR: For low temperature service API 617, 6th edition applies. [1] Temperatures between room temperature and -29°C / -20°F: Orders are handled according to API 617, 6th edition. Testing temperatures and acceptance criteria are according to DIN/EN material standards. [2] Temperatures below -29°C / -20°F: Requirements of API 617, 7th edition are met. Conducting of testing and acceptance criteria are acc. to AD or DIN/EN standards, which are considered equivalent to ASME VIII.

PETROBRAS: Not acceptable. VENDOR: PETROBRAS to explain their concerns, please. Shall be mutually discussed and agreed within technical clarifications. PETROBRAS: Parts exposed to, or affected by, low temperatures (static, rotating, pressure containing, nozzles, studs, nuts, etc.) shall be considered regarding low temperature requirements. Additionally, for those standards not mentioned by API Std 617, VENDOR shall demonstrate they are equivalent to or better than ASTM/ASME. Equivalence table to be included in proposal.

Closed 600

2.2.1.15.1

Pressure casings and rotating elements shall be designed with materials that comply with the paragraphs included in this section. Note: “Low temperature” may apply to materials that operate or are exposed to considerably higher temperature than the previously used – 29°C (– 20°F) guidelines. VENDOR: Compressor is designed for: - a minimum operating temperature of -20°C and - a minimum transport temperature of -30°C This means that the minimum design temperature for: - the casing is -30°C and - the rotor is -20°C

PETROBRAS: API limits to apply for both rotative and stationary wetted parts. VENDOR: Noted. PETROBRAS: Noted.

Closed 600

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2.2.1.15.5

All carbon and low alloy steel pressure-containing components including nozzles, flanges, and weldments shall be impact tested in accordance with the requirements of Section VIII, Division 1, Sections UCS-65 through 68, of the ASME Code or equivalent standard. High-alloy steels shall be tested in accordance with Section VIII, Division l, Section UHA-51, of the ASME Code or equivalent standard. For materials and thicknesses not covered by Section VIII, Division l of the ASME Code or equivalent standards, the purchaser will specify requirements. Note: Impact testing of a material may not be required depending on the minimum design metal temperature, thermal, mechanical and cyclic loading and the governing thickness. Refer to requirements of Section VIII, Division l, Section UG-20F of the ASME Code, for example. Governing thickness used to determine impact testing requirements shall be the greater of the following: a. The nominal thickness of the largest butt-welded joint. b. The largest nominal section for pressure containment, excluding: 1. Structural support sections such as feet or lugs. 2. Sections with increased thickness required for rigidity to mitigate shaft deflection. 3. Structural sections required for attachment or inclusion of mechanical features such as jackets or seal chambers. c. One fourth of the nominal flange thickness, including parting flange thickness for axially split casings (in recognition that the predominant flange stress is not a membrane stress). The results of the impact testing shall meet the minimum impact energy requirements of Section VIII, Division l, Section UG-84, of the ASME Code or equivalent standard. VENDOR: In oil and gas applications very cold conditions are not normal, and VENDOR’s case design has been used for many years in thousands of installations without failure. VENDOR does not Charpy V-notch impact test as a standard practice. Impact testing is available at an additional cost. Charpy V-notch impact test as a standard practice. Impact testing is available at an additional cost.

PETROBRAS: Not acceptable. VENDOR: This requirement should be included in the customer (PETROBRAS) specification. PETROBRAS: Not acceptable, since it is a mandatory API Std 617 requirement for low temperature services. Whenever applicable, VENDOR shall include in proposal all necessary impact tests in the scope of supply, as per API Std 617. The following parts exposed to, or affected by, low temperatures (static, rotating, pressure containing, nozzles, studs, nuts, etc.) shall be considered regarding low temperature requirements.

Closed 100

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2.2.1.15.5

All carbon and low alloy steel pressure-containing components including nozzles, flanges, and weldments shall be impact tested in accordance with the requirements of Section VIII, Division 1, Sections UCS-65 through 68, of the ASME Code or equivalent standard. High-alloy steels shall be tested in accordance with Section VIII, Division l, Section UHA-51, of the ASME Code or equivalent standard. For materials and thicknesses not covered by Section VIII, Division l of the ASME Code or equivalent standards, the purchaser will specify requirements. Note: Impact testing of a material may not be required depending on the minimum design metal temperature, thermal, mechanical and cyclic loading and the governing thickness. Refer to requirements of Section VIII, Division l, Section UG-20F of the ASME Code, for example. Governing thickness used to determine impact testing requirements shall be the greater of the following: a. The nominal thickness of the largest butt-welded joint. b. The largest nominal section for pressure containment, excluding: 1. Structural support sections such as feet or lugs. 2. Sections with increased thickness required for rigidity to mitigate shaft deflection. 3. Structural sections required for attachment or inclusion of mechanical features such as jackets or seal chambers. c. One fourth of the nominal flange thickness, including parting flange thickness for axially split casings (in recognition that the predominant flange stress is not a membrane stress). The results of the impact testing shall meet the minimum impact energy requirements of Section VIII, Division l, Section UG-84, of the ASME Code or equivalent standard. VENDOR: All carbon and low alloy steel pressure-containing components including nozzles, flanges, and weldments which design temperature below -29°C shall be impact tested.

PETROBRAS: Not acceptable. API and ASME codes to be followed. VENDOR: Agreed to PETROBRAS’ comment. PETROBRAS: Noted.

Closed 300

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2.2.1.15.5

All carbon and low alloy steel pressure-containing components including nozzles, flanges, and weldments shall be impact tested in accordance with the requirements of Section VIII, Division 1, Sections UCS-65 through 68, of the ASME Code or equivalent standard. High-alloy steels shall be tested in accordance with Section VIII, Division l, Section UHA-51, of the ASME Code or equivalent standard. For materials and thicknesses not covered by Section VIII, Division l of the ASME Code or equivalent standards, the purchaser will specify requirements. Note: Impact testing of a material may not be required depending on the minimum design metal temperature, thermal, mechanical and cyclic loading and the governing thickness. Refer to requirements of Section VIII, Division l, Section UG-20F of the ASME Code, for example. Governing thickness used to determine impact testing requirements shall be the greater of the following: a. The nominal thickness of the largest butt-welded joint. b. The largest nominal section for pressure containment, excluding: 1. Structural support sections such as feet or lugs. 2. Sections with increased thickness required for rigidity to mitigate shaft deflection. 3. Structural sections required for attachment or inclusion of mechanical features such as jackets or seal chambers. c. One fourth of the nominal flange thickness, including parting flange thickness for axially split casings (in recognition that the predominant flange stress is not a membrane stress). The results of the impact testing shall meet the minimum impact energy requirements of Section VIII, Division l, Section UG-84, of the ASME Code or equivalent standard. VENDOR: All carbon and low alloy steel pressure-containing components will be impact tested in accordance with applicable European or German standards. When German or European materials are used, impact tests will be performed in accordance with the applicable European or German standards. The results of impact testing shall meet the impact requirements of the applicable European or German standards.

PETROBRAS: Not acceptable. ASME codes to be followed. VENDOR #600: PETROBRAS to explain their concerns, please. When using German and/or European materials it is obvious that German and/or European standards will apply. However these standards will be equivalent or better to any American or International standards. If the PETROBRAS concern is about test plates or test weld these may be provided as an option with impact on cost and delivery time. PETROBRAS: Parts exposed to, or affected by, low temperatures (static, rotating, pressure containing, nozzles, studs, nuts, etc.) shall be considered regarding low temperature requirements. Additionally, for those standards not mentioned by API Std 617, VENDOR shall demonstrate they are equivalent to or better than ASTM/ASME. Equivalence table to be included in proposal. VENDOR #300: Agreed with PETROBRAS’ comments. PETROBRAS: PETROBRAS re-states final comment. Considering acceptance by VENDOR #300, subject is closed.

Closed 600

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2.2.1.15.5

All carbon and low alloy steel pressure-containing components including nozzles, flanges, and weldments shall be impact tested in accordance with the requirements of Section VIII, Division 1, Sections UCS-65 through 68, of the ASME Code or equivalent standard. High-alloy steels shall be tested in accordance with Section VIII, Division l, Section UHA-51, of the ASME Code or equivalent standard. For materials and thicknesses not covered by Section VIII, Division l of the ASME Code or equivalent standards, the purchaser will specify requirements. Note: Impact testing of a material may not be required depending on the minimum design metal temperature, thermal, mechanical and cyclic loading and the governing thickness. Refer to requirements of Section VIII, Division l, Section UG-20F of the ASME Code, for example. Governing thickness used to determine impact testing requirements shall be the greater of the following: a. The nominal thickness of the largest butt-welded joint. b. The largest nominal section for pressure containment, excluding: 1. Structural support sections such as feet or lugs. 2. Sections with increased thickness required for rigidity to mitigate shaft deflection. 3. Structural sections required for attachment or inclusion of mechanical features such as jackets or seal chambers. c. One fourth of the nominal flange thickness, including parting flange thickness for axially split casings (in recognition that the predominant flange stress is not a membrane stress). The results of the impact testing shall meet the minimum impact energy requirements of Section VIII, Division l, Section UG-84, of the ASME Code or equivalent standard. VENDOR: Clarification: Only materials subjected to temperatures below -20°F (-29°C) will be impact tested.

PETROBRAS: Not acceptable. VENDOR: To be complied. PETROBRAS: Noted.

Closed 800

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2.2.2.4

Nodular iron castings shall be produced in accordance with an internationally recognized standard such as ASTM A 395. VENDOR: All nodular cast iron grades used by VENDOR are according to DIN EN standards. German Pressure Vessel Code (AD-Merkblätter) permits welding of pressure vessels made of nodular cast iron grades. Due to this fact VENDOR considers welding as a reasonable and safe technique to repair nodular cast iron parts. Up to now VENDOR or it subsupplier’s have gained much experience in welding nodular cast iron. This welding will be performed under supervision of notified body and based on approved PQR. Cast grey iron is not subject to this comment.

PETROBRAS: Noted. VENDOR #400: Noted. VENDOR #300: We do propose cast iron. PETROBRAS: Only nodular cast iron to be considered.

Closed 400

2.2.3.1

The forging material shall be selected from those listed in Annex 1E. VENDOR: Forging materials may be selected from European or German material standards.

PETROBRAS: Acceptable provided that materials are equivalent to or better than ASTM/ASME. Equivalence table to be included in proposal. VENDOR: Confirmed.

Closed 600

2.2.3.1

The forging material shall be selected from those listed in Annex 1E. VENDOR: Other forging materials may be used due to VENDOR experience or special circumstances.

PETROBRAS: Acceptable provided that materials are equivalent to or better than ASTM/ASME. Equivalence table to be included in proposal. VENDOR: See VENDOR standard materials listed in the proposal. PETROBRAS: Not acceptable. It is a vague statement. VENDOR to provide equivalence table.

Closed 700

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2.2.3.2

All repairs that are not covered by ASTM specifications shall be subject to the purchaser’s approval. VENDOR: For casing and head flanges made from forgings the criteria for repair notification to the PURCHASER is the one defined in the par 2.3.1.10.1 For repair on impeller forging the notification criteria is the following (as defined by ASTM): “Repair by welding shall not exceed 10% of the surface area of the forgings nor 1/3 of the wall thickness of the finished forgings or 3/8 in. [9.5 mm], whichever is less, without prior approval of the PURCHASER”.

PETROBRAS: Accepted. Closed 900

2.2.4

Welding. VENDOR: Welding of piping, pressure-containing parts, and weld repairs are performed and qualified according to Section IX of the ASME code or the corresponding European standard EN 288-3. As far as base materials according to German or European standards are used, the applicability of welding procedures concerning the grouping of similar base materials and the requirements for the post weld heat treatment follow the applicable German or European standards.

PETROBRAS: Acceptable provided that the procedures are equivalent to or better than ASME. Equivalence table in English text to be included in proposal. Welders, WPS and PQR shall be qualified by Third Party. This organization shall be according to ISO/IEC 17024. For inspectors in charge of generating WPS, PQR, and welder qualifications, besides ISO/IEC 17024, it shall be required a previous approval of qualification by PETROBRAS. Regarding welding of non-pressure containing parts, VENDOR’s standard will be acceptable if in accordance with AWS as a minimum. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

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2.2.4.1

Unless otherwise specified, other welding, such as welding on baseplates, non-pressure ducting, lagging, and control panels, shall be performed by welders qualified in accordance with an appropriate recognized standard such as AWS D 1.1 or ASME Section IX. VENDOR: Welding and repairing of casing will be performed by welder’s qualified in accordance with JIS and/or JPI. Welding of non-pressure containing parts such as baseplate & structural parts will be performed with manufacturer’s standard.

PETROBRAS: Welders, WPS and PQR shall be qualified by Third Party. This organization shall be according to ISO/IEC 17024. For inspectors in charge of generating WPS, PQR, and welder qualifications, besides ISO/IEC 17024, it shall be required a previous approval of qualification by PETROBRAS. Regarding welding of non-pressure containing parts, VENDOR’s standard will be acceptable if in accordance with AWS as a minimum. VENDOR: Vendor's comments is modified as follows: ‘Welders, WPS and PQR will be qualified by third party qualified by each country’s organization or ASME Sec. IX. For inspectors in charge of generating WPS, PQR, and welder qualifications, besides ISO/IEC 17024, it shall be required a previous approval of qualification by PETROBRAS. Regarding welding of non-pressure containing parts, VENDOR´s standard in accordance with ASME section IX is proposed.’ PETROBRAS: VENDOR to refer to PETROBRAS’ answer to item 1.6, 1.6.1. VENDOR: Same answer as item 1.6, 1.6.1. PETROBRAS: Noted. It is PETROBRAS understanding that VENDOR’s reply meaning is as follows: Welders, WPS and PQR will be qualified by Third Party organization (as per ISO/IEC 17024 directives) in accordance with ASME Sec. IX criteria.

Closed 300

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2.2.4.1

Unless otherwise specified, other welding, such as welding on baseplates, non-pressure ducting, lagging, and control panels, shall be performed by welders qualified in accordance with an appropriate recognized standard such as AWS D 1.1 or ASME Section IX. VENDOR: Welders may be qualified in accordance with European standard EN287-1. Welders for these weldments are qualified in accordance with ASME IX or equivalent European standards.

PETROBRAS: PETROBRAS and API base requirements are ASME IX. Other standards shall be submitted to PETROBRAS for approval during bid stage. Basically, they should be acceptable if equivalent or better than ASME. BIDDER to demonstrate with table of equivalence using English-text comparison. VENDOR: Noted. PETROBRAS: Noted.

Closed 600

2.3.1.1

The pressure casing shall be designed in accordance with 2.3.1.1.1 or 2.3.1.1.2, and the casing joint bolting shall be in accordance with 2.3.1.1.3. VENDOR: Casings will be designed to VENDOR design standards and criteria. The design procedures are derived from international standards. Based on these procedures stress values are calculated, and checked that ASME figures are not exceeded.

PETROBRAS: Not acceptable. PETROBRAS and API base requirements are ASME IX. Other standards shall be submitted to PETROBRAS for approval during bid stage. Basically, they should be acceptable if equivalent or better than ASME. VENDOR to demonstrate with table of equivalence using English-text comparison. VENDOR: Compared standards are equivalent or better. Corresponding values for casing design pressure and temperature will be indicated on compressor data sheets. PETROBRAS: VENDOR to provide equivalence table as required above.

Closed 600

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2.3.1.1.1

The allowable tensile stress used in the design of the pressure casing (excluding bolting) for any material shall not exceed 0.25 times the minimum ultimate tensile strength for that material at the maximum specified operating temperature. For cast materials, the allowable tensile stress shall be multiplied by the appropriate casting factor as shown in Table 1.2-2. VENDOR: Casing stresses significantly adhere to the specification. However, certain minimal localized areas of the casing may exceed the stated stress level. Strict adherence to the specification results in unnecessary massive components that are more defect-prone, leading to increased weight and complexity. Each casing/cover is individually tested and witnessed at 1.5X maximum working pressure to prove the design and manufacturing integrity and fitness for service.

PETROBRAS: Not acceptable. VENDOR #700: [1] For pipeline compressors, VENDOR uses cast steel material. It is not possible to change the casting to match the limits in the specification. VENDOR has significant experience using the proposed materials and has had no issues in the areas indicated. See the attached reference list. [2] The barrel compressor casing is forged steel. This exception does not apply to barrel compressors. PETROBRAS: [1] VENDOR to provide list as stated above. [2] Noted. VENDOR #300: Information is not enough. PETROBRAS: Subject closed.

Closed 700

2.3.1.1.1

The allowable tensile stress used in the design of the pressure casing (excluding bolting) for any material shall not exceed 0.25 times the minimum ultimate tensile strength for that material at the maximum specified operating temperature. For cast materials, the allowable tensile stress shall be multiplied by the appropriate casting factor as shown in Table 1.2-2. VENDOR: Casings will be sized according to VENDOR design criteria. Design criteria will be referenced and proven through a list of past experiences.

PETROBRAS: Not acceptable. VENDOR #300: Information is not enough. PETROBRAS: PETROBRAS re-states comment above. Subject closed.

Closed 900

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2.3.1.1.2

Pressure-containing components may be designed with the aid of finite element analysis provided that the design limits comply with Section VIII Division 2 of the ASME Pressure Vessel Code (Code) stress intensity as modified by Equation 1.2-1. VENDOR: Compressor casings are not defined as pressure vessels. ASME Code was not developed for compressor casings, but for pressure vessels.

PETROBRAS: Not acceptable. VENDOR #400: According to API 617 7th edition Paragraph 1-2.3.1.1 there are two different possibilities for casing design: 1-2.3.1.1.1 or 1-2.3.1.1.2. VENDOR designs the casings according to 1-2.3.1.1.2. PETROBRAS: VENDOR to demonstrate FEA compliance with ASME limits. It would be very helpful to demonstrate right now, during this technical specification discussion, in order to save time and avoid repeating discussions for every proposal. VENDOR #300: Information is not enough. PETROBRAS: PETROBRAS re-states comment above. Subject closed.

Closed 400

2.3.1.1.2

Pressure-containing components may be designed with the aid of finite element analysis provided that the design limits comply with Section VIII Division 2 of the ASME Pressure Vessel Code (Code) stress intensity as modified by Equation 1.2-1. VENDOR: If casings dimensions and/or working conditions are worse than in past experience, casing will be verified through FEA analysis at Design pressure and hydraulic test pressure conditions. VENDOR criteria will be applied to verify suitability of the design.

PETROBRAS: Not acceptable. VENDOR #300: Not Agreed. Agreed to VENDOR’s comment. PETROBRAS: PETROBRAS re-states comment above for both vendors. Subject closed.

Closed 900

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2.3.1.7

Bolting shall be furnished as specified in 2.3.1.7.1 through 2.3.1.7.4. VENDOR: Bolting shall conform to metric standards (ISO).

PETROBRAS: PETROBRAS base requirements follow API specifications. Other requirements shall be submitted to PETROBRAS for approval during bid stage. VENDOR #300: These paras allow use of metric threads. PETROBRAS: VENDOR #300’s comment noted. Subject closed.

Closed 400

2.3.1.7.2

Studs shall be supplied on the main joint of axially split casings and bolted end covers of radially split casings. Studs shall be used instead of cap screws, on all other external joints, except where hexagonal head cap screws are essential for assembly purposes and have been approved by the purchaser. VENDOR: Cap screws are used on all external connections.

PETROBRAS: Acceptable for transportation services only. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

2.3.1.7.2

Studs shall be supplied on the main joint of axially split casings and bolted end covers of radially split casings. Studs shall be used instead of cap screws, on all other external joints, except where hexagonal head cap screws are essential for assembly purposes and have been approved by the purchaser. VENDOR: Exception: VENDOR’s horizontally split centrifugal compressor design uses a combination of both threaded nuts and through-bolts.

PETROBRAS: To be clarified. VENDOR to provide drawings and specifications, and submit deviation with proposal. VENDOR #300: Not enough information. VENDOR #800: Noted. PETROBRAS: VENDOR #800”s reply comment noted. VENDOR #300’s comment disregarded. Subject closed.

Closed 800

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2.3.1.8

Materials, casting factors, and the quality of any welding shall be equal to those required by Section VIII, Division 1, of the ASME Code. The manufacturer’s data report forms, as specified in the code, are not required. Note: For low temperature requirements, see 2.2.1.15. VENDOR: Quality of material, castings and welding will fulfill the conditions required by VENDOR design and specifications.

PETROBRAS: Basically acceptable, but it is a vague statement. VENDOR design shall always comply with applicable API and job specifications. Deviations shall be clearly stated case by case, item by item, and included in proposal. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 400

2.3.1.9

Welding of piping, pressure-containing parts, weld repairs and any dissimilar-metal welds shall be performed and inspected by operators and procedures qualified in accordance with Section VIII Division l, and Section IX of the ASME Code (see 4.2.1.1). VENDOR: Welding of piping and pressure-containing parts shall be in accordance with ASME IX or EN 287, EN 288 and EN 729. Submittal of welding procedures are not in VENDOR scope of supply and can be quoted optionally if requested.

PETROBRAS: Not acceptable. Procedures shall be submitted for PETROBRAS approval during Pre-Inspection Meeting (PIM). PETROBRAS base requirements follow API specifications. Other requirements shall be submitted to PETROBRAS for approval during bid stage. Basically, they should be acceptable if equivalent or better than specified by PETROBRAS or required by API. BIDDER to demonstrate with table of equivalence using English-text comparison. VENDOR: Pressure retaining parts are welded according ASME code. Non-pressure retaining parts (e.g. Baseframe) are welded according equivalent EN norms that are at least ASME equivalent. WPS/PQR for the compressor can be reviewed during pre-inspection meeting at supplier premises. PETROBRAS: VENDOR to refer to answer to item 1.6, 1.6.1. Subject closed.

Closed 400

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2.3.1.9

Welding of piping, pressure-containing parts, weld repairs and any dissimilar-metal welds shall be performed and inspected by operators and procedures qualified in accordance with Section VIII Division l, and Section IX of the ASME Code (see 4.2.1.1). VENDOR: See 2.2.4.1. Welding of piping, pressure-containing parts, weld repairs and any dissimilar-metal welds shall be performed and inspected by operators and procedures qualified in accordance with Section VIII Division 1, and ASME IX of the ASME Code or equivalent European standards. When German or European materials are used to qualify welding procedures according to the ASME Code these welding procedures shall be applicable for other German or European materials of the same material group according to ISO 15608. The PWHT requirements for such welding procedures shall follow the applicable German or European standards.

PETROBRAS: PETROBRAS base requirements follow API specifications. Other requirements shall be submitted to PETROBRAS for approval during bid stage. Basically, they should be acceptable if equivalent or better than specified by PETROBRAS or required by API. BIDDER to demonstrate with table of equivalence using English-text comparison. Procedures already in accordance with base requirements may be submitted for PETROBRAS approval during Pre-Inspection Meeting (PIM). Regarding other materials specifications and PWHT requirements, BIDDER is required to clarify his statement and submit before quotation. Materials not in accordance with ASTM/ASME (with no P-numbers) shall be comparable by means of their actual compositions. VENDOR: Can be withdrawn, however this will have an impact to cost and delivery time. PETROBRAS: All costs and schedule impacts to be considered during bid stage, i.e., to be included in VENDOR’s proposal.

Closed 600

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2.3.1.10

The vendor shall be responsible for the review of all repairs and repair welds to ensure that they are properly heat treated and nondestructively examined for soundness and compliance with the applicable qualified procedures (see 2.3.1.8). Repairs shall be nondestructively tested by the same method used to detect the original flaw, however the minimum level of inspection after the repair, shall be by the magnetic particle method in accordance with 4.2.2.4 for magnetic material and by the liquid penetrant method in accordance with 4.2.2.5 for nonmagnetic material. Unless otherwise specified, procedures for major repairs shall be subject to review by the purchaser prior to any repair. VENDOR: VENDOR’s material procurement approach allows for PURCHASER notification of major repairs. Requirements only by prior agreement at the time of order.

PETROBRAS: VENDOR shall notify PETROBRAS prior to any procedure concerning any major repair. All major repairs require previous PETROBRAS approval to proceed. VENDOR shall extend this very requirement to his SUB-SUPPLIER orders. Procedures for major repairs (either by VENDOR or by SUB-SUPPLIER) shall be subject to review and approval by PETROBRAS. VENDOR: VENDOR keeps track of any major repair done in-house. Rework Orders are documented in the Production Order system. PETROBRAS: Answer regarding records noted, but it does not reply to PETROBRAS’ comment on the issue of previous approval of procedures.

Closed 100

2.3.1.10

The vendor shall be responsible for the review of all repairs and repair welds to ensure that they are properly heat treated and nondestructively examined for soundness and compliance with the applicable qualified procedures (see 2.3.1.8). Repairs shall be nondestructively tested by the same method used to detect the original flaw, however the minimum level of inspection after the repair, shall be by the magnetic particle method in accordance with 4.2.2.4 for magnetic material and by the liquid penetrant method in accordance with 4.2.2.5 for nonmagnetic material. Unless otherwise specified, procedures for major repairs shall be subject to review by the purchaser prior to any repair. VENDOR: Proven standard procedures for major repairs will be issued for information only.

PETROBRAS: Not acceptable. Procedures shall be submitted for PETROBRAS approval prior to any major repair. Submission during Pre-Inspection Meeting (PIM) is preferred. VENDOR: Standard repair procedures can be made available to PETROBRAS in advance. However, in case of an order, repair procedures will have a major impact on delivery time, therefore mutual agreement shall be made within order execution. PETROBRAS: Noted. It would be very helpful to provide them right now, during this technical specification discussion, in order to save time and avoid repeating discussions for every order.

Closed 600

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2.3.1.11.3

Pressure-containing welds, including welds of the case to horizontal or vertical joint flanges, shall be full penetration (complete joint) welds unless otherwise approved by the purchaser prior to any fabrication. Note: This does not apply to auxiliary connections as described in 2.3.2.3. VENDOR: Exception: The external volute iso-cool/double flow discharge section for the compressor does not have full penetration welds. VENDOR provides single side, full-strength corner joints on the final closure welds of external volute chambers. These welds are at least 80% penetration of the thinner member plus a reinforcing fillet weld of 1/2-inch minimum leg size. Inaccessibility to the backside necessitates such an approach.

PETROBRAS: Not acceptable. VENDOR #300: Not Agreed. Agreed with VENDOR. VENDOR #800: To be complied. PETROBRAS: VENDOR #800”s reply comment noted. VENDOR #300’s comment disregarded. Subject closed.

Closed 800

2.3.1.12.2.1

Radiographic examination shall be in accordance with Section VIII, Division 1, UW-51 (100%) and UW-52 (spot), of the ASME Code or an equivalent international standard. Spot radiography shall consist of a minimum of one 150-mm (6-in.) spot radiograph for each 7.6 m (25 ft) of weld on each casing. As a minimum, one spot radiograph is required for each welding procedure and welder used for pressure-containing welds. VENDOR: Clarification: Meaningful radiography can be performed only on butt welds. RT cannot be applied to welding procedures or welders for non-butt welds.

PETROBRAS: In this case, VENDOR shall use UT instead of RT. VENDOR #300: Agreed with comment. Agreed with PETROBRAS’s comment if meaningful UT is possible. VENDOR #800: Noted. PETROBRAS: Both comments noted. Subject closed.

Closed 800

2.3.1.12.2.1, 2.3.1.12.2.2, 2.3.1.12.2.3, 2.3.1.12.2.4

Material inspection of pressure containing parts. VENDOR: Fabricated casing welding will be examined as follows: [1] Manual UT before and after post welding heat treatment (PWHT); [2] MT internal and external before and after PWHT; and [3] RT before PWHT only on crossing between buttwelds.

PETROBRAS: VENDOR shall use UT instead of RT wherever RT is not applicable. VENDOR #300: Not Agreed. Agreed with VENDOR. PETROBRAS: PETROBRAS re-states comment above. VENDOR #300”s comment disregarded. Refer to VENDOR’s agreement to paragraph above (2.3.1.12.2.1). Subject closed.

Closed 900 PRELIMIN

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2.3.1.12.3

Cast steel casing parts shall be examined by magnetic particle methods. Acceptability of defects shall be based on a comparison with the photographs in ASTM E 125 Code. For each type of defect, the degree of severity shall not exceed the limits specified in Table 1.2-3. VENDOR: Inspection for defects is in accordance with VENDOR Engineering Specification ES 9-296, Table 1.

PETROBRAS: PETROBRAS base requirements follow API specifications. Other requirements shall be submitted to PETROBRAS for approval during bid stage. Basically, they should be acceptable if equivalent or better than specified by PETROBRAS or required by API. VENDOR to demonstrate with table of equivalence using English-text comparison. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

2.3.2.1.1

All connections shall be flanged or machined and studded, except where threaded connections are permitted by 2.3.2.3. All process gas connections to the casing shall be suitable for the maximum allowable working pressure as defined in 1.5.17. VENDOR: All compressor connections are shown on the data sheets and identified by type of connection and service.

PETROBRAS: Statement noted. Not a deviation. Any requirement exception or deviation from any of the listed documents not clearly mentioned in tender will be considered by PETROBRAS as full compliance with the material requisition. VENDOR: Differences in requirement will be stated on each API 617 datasheet. Included in the Technical Proposal (depending on the compressor model/application). PETROBRAS: Noted. However, it would be very helpful to provide deviations right now, during this technical specification discussion, in order to save time and avoid repeating discussions for every proposal.

Closed 100

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2.3.2.1.1

All connections shall be flanged or machined and studded, except where threaded connections are permitted by 2.3.2.3. All process gas connections to the casing shall be suitable for the maximum allowable working pressure as defined in 1.5.17. VENDOR: All connections shall be designed at least for the max stage working pressure or settle out pressure whichever is higher. See datasheets.

PETROBRAS: Not acceptable. All connections to the same pressure casing shall be equally rated as per API requirements. Any requirement exception or deviation from any of the listed documents not clearly mentioned in tender will be considered by PETROBRAS as full compliance with the material requisition. VENDOR #400: Some of the connections to the compressor casing such as the dry gas seal buffer gas connection will never be exposed to the maximum allowable working pressure. If such connections needs to be designed for the MAWP this would have an enormous effect on VENDOR's compressor layout and could lead to a changed design which is, in VENDOR's opinion, not the optimized solution in a technically point of view. Therefore VENDOR asks for approval of the original comment. PETROBRAS: PETROBRAS concern with this paragraph is with main process (gas) connections, as stated per API Std 617. Therefore, VENDOR deviation is still not acceptable and justification has been considered inadequate. VENDOR #300: Not Agreed. Agreed with VENDOR. PETROBRAS: PETROBRAS re-states comment above. VENDOR #300’s comment disregarded. Subject closed.

Closed 400

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2.3.2.1.1

All connections shall be flanged or machined and studded, except where threaded connections are permitted by 2.3.2.3. All process gas connections to the casing shall be suitable for the maximum allowable working pressure as defined in 1.5.17. VENDOR: Due to space constrains on the compressor, socket head bolts are widely used for auxiliary connections.

PETROBRAS: Basically acceptable, but it is a vague statement. VENDOR design shall always comply with applicable API and job specifications. Deviations shall be clearly stated case by case, item by item, and included in proposal. VENDOR: VENDOR uses SAE flanges on auxiliary connection for bearing feed/drain, seal gas lines, casing drains. Studs are not used. PETROBRAS: Acceptable for transportation services only.

Closed 700

2.3.2.1.3

All openings or nozzles for piping connections on pressure casings shall be in accordance with ISO 6708 (ANSI/ASME B1.20.1). Sizes DN 32, DN 65, DN 90, DN 125, DN 175 and DN 225 (11/4, 21/2, 31/2, 5, 7, and 9 NP)shall not be used. Note: NP designates pipe per ANSI/ASME B1.20.1. VENDOR: In some instances, it is impractical or impossible to use flanges which comply fully due to space constraints on the compressor. SAE flanges are frequently used due to their compact design.

PETROBRAS: Acceptable for transportation services only. Non-standard flanges (either on size or design standard) shall be submitted for PETROBRAS approval with FEA in proposal. Companion flanges shall always be included in VENDOR's scope of supply. VENDOR: VENDOR uses SAE flanges on auxiliary connection for bearing feed/drain, seal gas lines, casing drains. FEA is not provided in the proposal. Customer connection points for piping will always be ASME flanges. PETROBRAS: FEA is necessary for non-standard flanges.

Closed 700

2.3.2.1.4

Connections welded to the casing shall meet the material requirements of the casing, including impact values, rather than the requirements of the connected piping. VENDOR: Exception: Some minor piping connections are welded to the casing after machining. Casing heat treatment after such welding is not practical or necessary.

PETROBRAS: Basically acceptable, but it is a vague statement. Deviations shall be clearly stated case by case, item by item, and included in proposal. VENDOR: This exception is only for large compressors and it will be evaluated on a case by case basis. PETROBRAS: Noted.

Closed 800 PRELIMIN

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2.3.2.1.5

All welding of connections shall be completed before the casing is hydrostatically tested (see 4.3.2). VENDOR: Air vent holes for hydrostatic test and temperature/pressure measuring holes furnished for performance test in horizontally split compressor are plugged and seal welded after hydrostatic test.

PETROBRAS: Noted. VENDOR: Noted.

Closed 500

2.3.2.1.6

For axially split pressure casings, the vendor shall provide connections for complete drainage of all gas passages. For radially split pressure casings, the drains shall be located at the lowest point of each inlet section, the lowest point of the section between the inner and outer casings, and the lowest point of each discharge section. Number and size of drain connections shall be shown in the data sheet. VENDOR: Inlet and discharge section low-point drains are provided.

PETROBRAS: Valved drains shall be provided on all casings. Multistage equipment shall be provided with individual stage casing drains. Balance piston cavity (if any) shall also be drained. If individual stage drains cannot be provided due to design limitations, it shall be demonstrated during proposal stage (with drawings) that no inner parts would remain undrained with the proposed arrangement. VENDOR: VENDOR provides low point connections for Inlet and Discharge of the compressor. Valves can be provided on the multi-stage compressor. No cavity drains are provided on balance piston. PETROBRAS: Incomplete answer. Valved drains are always required. VENDOR to ensure full drainage as well, including balance piston cavity, as above. It would be very helpful to demonstrate proper drainage with drawings right now, during this technical specification discussion, in order to save time and avoid repeating discussions for every proposal.

Closed 100

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2.3.2.1.7

When specified, individual stage drains, including a drain for the balance piston cavity, shall be provided (see 2.3.2.1.6). VENDOR: Individual stages are not provided with drains. Balance pistons cavity drain is not provided.

PETROBRAS: Valved drains shall be provided on all casings. Multistage equipment shall be provided with individual stage casing drains. Balance piston cavity (if any) shall also be drained. If individual stage drains cannot be provided due to design limitations, it shall be demonstrated during proposal stage (with drawings) that no inner parts would remain undrained with the proposed arrangement. VENDOR: VENDOR provides low point connections for Inlet and Discharge of the compressor. Valves can be provided on the multi-stage compressor. No cavity drain are provided on balance piston. PETROBRAS: Incomplete answer. Valved drains are always required. VENDOR to ensure full drainage as well, including balance piston cavity, as above. It would be very helpful to demonstrate proper drainage with drawings right now, during this technical specification discussion, in order to save time and avoid repeating discussions for every proposal.

Closed 100

2.3.2.1.7

When specified, individual stage drains, including a drain for the balance piston cavity, shall be provided (see 2.3.2.1.6). VENDOR: Drains are located at the lowest point of the inlet and discharge section at the balance piston as well between inner casing and outer casing.


Closed 400

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2.3.2.1.7

When specified, individual stage drains, including a drain for the balance piston cavity, shall be provided (see 2.3.2.1.6). VENDOR: Compressor doesn't have individual stage drains.

PETROBRAS: Valved drains shall be provided on all casings. Multistage equipment shall be provided with individual stage casing drains. Balance piston cavity (if any) shall also be drained. If individual stage drains cannot be provided due to design limitations, it shall be demonstrated during proposal stage (with drawings) that no inner parts would remain undrained with the proposed arrangement. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

2.3.2.1.7

When specified, individual stage drains, including a drain for the balance piston cavity, shall be provided (see 2.3.2.1.6). VENDOR: Exception: Due to space limitations, a drain for the balance piston cavity will not be provided.

PETROBRAS: Not acceptable. Former supplies already complied with it. VENDOR #300: Not enough information. VENDOR #800: VENDOR to comply. PETROBRAS: VENDOR #800’s reply comment noted. VENDOR #300’s comment disregarded. Subject closed.

Closed 800

2.3.2.1.7

When specified, individual stage drains, including a drain for the balance piston cavity, shall be provided (see 2.3.2.1.6). VENDOR: The feasability of individual stage drain and balance piston chamber draina, if specified, shall be verified case by case and subjected to a separate quotation.

PETROBRAS: Separated quotation not acceptable. Valved drains shall be provided on all casings. Multistage equipment shall be provided with individual stage casing drains. Balance piston cavity (if any) shall also be drained. If individual stage drains cannot be provided due to design limitations, it shall be demonstrated during proposal stage (with drawings) that no inner parts would remain undrained with the proposed arrangement.

Closed 900 PRELIMIN

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NI-2626, 6.2.2.1.1

Substitution (2.3.2.1 and 2.3.2.1.7 of API Std 617). Individual stage drains, including a drain for the balance piston cavity, shall be provided. VENDOR: Individual stage draining is not possible due to space problems. The lowest points of inlet volute, outlet volute and balance piston chamber are drained.

PETROBRAS: Balance piston cavity (if any) shall also be drained. If individual stage drains cannot be provided due to design limitations, it shall be demonstrated during proposal stage (with drawings) that no inner parts would remain undrained with the proposed arrangement. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 400

NI-2626, 6.2.2.1.1


PETROBRAS: Balance piston cavity (if any) shall also be drained. If individual stage drains cannot be provided due to design limitations, it shall be demonstrated during proposal stage (with drawings) that no inner parts would remain undrained with the proposed arrangement. VENDOR: Confirmed, balance piston cavity can also be drained. PETROBRAS: Noted.

Closed 500

NI-2626, 6.2.2.1.1


PETROBRAS: Balance piston cavity (if any) shall also be drained. If individual stage drains cannot be provided due to design limitations, it shall be demonstrated during proposal stage (with drawings) that no inner parts would remain undrained with the proposed arrangement. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600 PRELIMIN

ARY





2.3.2.2.1

Main process connections shall be flanged or machined and studded and oriented as specified on the data sheets. Note: Main process connections include all process inlets and outlets including those for sideloads and intermediate cooling. VENDOR: Main process connections on some VENDOR compressor models are machined on the casing. Studs and nuts are not provided.

PETROBRAS: Acceptable for transportation services only. Non-standard flanges (either on size or design standard) shall be submitted for PETROBRAS approval in proposal. Companion flanges shall always be included in VENDOR's scope of supply. VENDOR #100: All VENDOR flanges meet the standard. Companion flanges can be provided at additional cost. PETROBRAS: PETROBRAS clarifies that non-standard flanges are meant to those not locally (in Brazil) commercially available ones, to be provided with their respective companions (at no extra cost). However, if VENDOR’s flanges meet standards and are easily purchasable, then companion flanges are not necessary. VENDOR #300: Agreed with comment. High pressure compressor may have main process connection machined on the casing. PETROBRAS: VENDOR #100: subject already closed. VENDOR #300’s additional comment noted.

Closed 100

2.3.2.2.1

Main process connections shall be flanged or machined and studded and oriented as specified on the data sheets. Note: Main process connections include all process inlets and outlets including those for sideloads and intermediate cooling. VENDOR: VENDOR may use Grayloc connection for main process connections when size and weight limitations prohibit the use of flanged connections.

PETROBRAS: It is recognized that for very high pressure compressors, some process connections may need special designs. Refer to VENDOR #300’s comment above and VENDOR #200’s suggestion. PETROBRAS has not decided yet which technical solutions are acceptable and to which limits they should apply. Vendors are requested to provide additional information on the adopted method during bid stage.

Closed 200

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2.3.2.2.10

Machined and studded connections shall conform to the facing and drilling requirements of ISO 7005-1 or 7005-2 (ANSI/ASME B16.1, B16.5, B16.42 or B16.47). Studs and nuts shall be furnished installed, the first 1.5 threads at both ends of each stud shall be removed. Note: Threads are removed at the end of the stud to allow the stud to bottom without damaging the end threads in the hole. Threads are removed from both ends of the stud to allow either end of the stud to be inserted into the threaded hole. VENDOR: Refer to comment to paragraph 2.3.2.2.1.

PETROBRAS: Acceptable for transportation services only. Non-standard flanges (either on size or design standard) shall be submitted for PETROBRAS approval in proposal. Companion flanges shall always be included in VENDOR's scope of supply. VENDOR: All VENDOR flanges meet the standard. Companion flanges can be provided at additional cost. PETROBRAS: PETROBRAS clarifies that non-standard flanges are meant to those not locally (in Brazil) commercially available ones, to be provided with their respective companions (at no extra cost). However, if VENDOR’s flanges meet standards and are easily purchasable, then companion flanges are not necessary.

Closed 100

2.3.2.3.2

Flanges shall conform to ISO 7005-1 or 7005-2 (ANSI/ASME B16.1, B16.5 or B16.42), as applicable. VENDOR: Flanges may include SAE-4 bolt. Refer to corresponding API 617 data sheets for list of connections and services.

PETROBRAS: Acceptable for transportation services only. Non-standard flanges (either on size or design standard) shall be submitted for PETROBRAS approval in proposal. Companion flanges shall always be included in VENDOR's scope of supply. Any requirement exception or deviation from any of the listed documents not clearly mentioned in tender will be considered by PETROBRAS as full compliance with the material requisition. VENDOR: Noted for the accessory connections. PETROBRAS: Noted.

Closed 100

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2.3.2.3.2

Flanges shall conform to ISO 7005-1 or 7005-2 (ANSI/ASME B16.1, B16.5 or B16.42), as applicable. VENDOR: Grayloc and NORSOK flanges are not per ASME standards and will be used at compressor auxiliary connections if ANSI flanges would interfere with assembly and disassembly. When Grayloc or NORSOK flanges are used at the compressor, actual customer connections are still in accordance with ASME standards.

PETROBRAS: It is recognized that for very high pressure compressors, some process connections may need special designs. Refer to VENDOR #300’s comment above and VENDOR #200’s suggestion. PETROBRAS has not decided yet which technical solutions are acceptable and to which limits they should apply. Vendors are requested to provide additional information on the adopted method during bid stage.

Closed 200

2.3.2.3.3

Auxiliary connections shall be socket-welded and flanged, or machined and studded (see 2.3.2.3.4.1). VENDOR: Some auxiliary connections are also threaded without the use of flanges and without seal welding.

PETROBRAS: VENDOR design shall always comply with applicable API and job specifications. Deviations shall be clearly stated case by case, item by item, and included in proposal, considering type and severity of service. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

2.3.2.3.4

A pipe nipple, preferably not more than 150 mm (6 in.) long, schedule 80 seamless minimum, shall be installed in the socket-weld opening. A 2-mm (1/16-in.) gap, as measured prior to welding, shall be left between the pipe end and the bottom of the socket in the casing. Each pipe nipple shall be provided with a welding-neck, socket-weld, or slip-on flange, except as indicated below. VENDOR: Auxiliary lines are attached directly to the casing connections.


Closed 100

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2.3.2.3.4

A pipe nipple, preferably not more than 150 mm (6 in.) long, schedule 80 seamless minimum, shall be installed in the socket-weld opening. A 2-mm (1/16-in.) gap, as measured prior to welding, shall be left between the pipe end and the bottom of the socket in the casing. Each pipe nipple shall be provided with a welding-neck, socket-weld, or slip-on flange, except as indicated below. VENDOR: VENDOR applies a full penetration weld joint design for gas seal primary supply, intermediate supply (if equipped) and separation gas supply pipe (pipe only) connections to heads. This joint design allows for easier cleaning versus the socket-weld joint noted in the paragraph.

PETROBRAS: Not acceptable. VENDOR: The full penetration welds shall only be used for piping welds which are directly in contact with the compressor heads. VENDOR considers this weld as part of the compressor design and maintains that this weld is the better choice than the socket weld referenced in this paragraph. PETROBRAS: Noted. VENDOR’s alternate design is acceptable as well.

Closed 200

2.3.2.3.4.1

Auxiliary connections for lube oil, seal oil, or dry gas seal operation shall use weld-neck or slip-on flanges only. Note: Socket-weld is not allowed due to the possibility of a dirt trap. VENDOR: Some auxiliary connections are also threaded without the use of flanges and without seal welding.

PETROBRAS: Acceptable for transportation services only. VENDOR design shall always comply with applicable API and job specifications. As some services do not allow for threaded connections, VENDOR shall clearly state the deviation in proposal, considering type and severity of service. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

2.3.2.3.4.1

Auxiliary connections for lube oil, seal oil, or dry gas seal operation shall use weld-neck or slip-on flanges only. Note: Socket-weld is not allowed due to the possibility of a dirt trap. VENDOR: Socket-weld fittings may be used on ¾” and 1” lines.

PETROBRAS: Acceptable for transportation services only. VENDOR design shall always comply with applicable API and job specifications. As some services do not allow for threaded connections, VENDOR shall clearly state the deviation in proposal, considering type and severity of service. VENDOR: OK. PETROBRAS: Noted.

Closed 700 PRELIMIN

ARY





2.3.2.3.5.1

Threaded openings and bosses for tapered pipe threads shall conform to ISO 7—Parts 1 and 2 (ANSI/ASME B1.20.1). VENDOR: Threaded openings are straight o-ring boss for 1.00-inch (2.54 cm) diameter tube.


Closed 100

2.3.2.3.5.1

Threaded openings and bosses for tapered pipe threads shall conform to ISO 7—Parts 1 and 2 (ANSI/ASME B1.20.1). VENDOR: Threaded connections to be in accordance with either: ISO 7-1 / ISO 7-2 Tapered Pipe Threads (PT) 55º, ANSI B1.2. National Pipe Tapered (NPT) 60º with thread tape, or DIN ISO 228/1 Parallel Pipe Threads with gasket, cutting face or O-Ring (G) 55º.


Closed 400

2.3.2.3.5.1, 2.3.2.3.5.2

2.3.2.3.5.2. Pipe threads shall be taper thread conforming to ANSI/ASME B1.20.1. VENDOR: Standard taper pipe threads through 3” are Dryseal (NPTF) per ANSI/ASME B1.20.3 and NPT per B.1.20.1 above 3”.

PETROBRAS: Acceptable for transportation services only. VENDOR design shall always comply with applicable API and job specifications. As some services do not allow for threaded connections, VENDOR shall clearly state the deviation in proposal, considering type and severity of service. VENDOR: OK. PETROBRAS: Noted.

Closed 700 PRELIMIN

ARY





2.3.2.3.5.4

For threaded connections that are to be connected to pipe, a pipe nipple, preferably not more than 150 mm (6 in.) long, schedule 160 seamless minimum, shall be installed in the threaded opening. Each pipe nipple shall be provided with a welding-neck, socket-weld or slip-on flange. The nipple and flange materials shall meet the requirements of 2.3.2.1.4. VENDOR: Threaded connections may be made to stainless steel tubing in place of pipe.


Closed 100

2.3.2.3.5.5

Threaded openings not required to be connected to piping shall be plugged with solid, round-head steel plugs in accordance with ANSI/ASME B16.11. As a minimum, these plugs shall meet the material requirements of the pressure casing. Plugs that may later require removal shall be of a corrosion resistant material. Plastic plugs are not permitted. A process compatible thread lubricant of proper temperature specification shall be used on all threaded connections. Thread tape shall not be used. VENDOR: Square and/or socket head plugs may be used to assure less protrusion and are easier to install and remove.

PETROBRAS: Openings not connected to piping shall be held to a minimum. Those openings, if any, shall comply with the following additional requirements: any flammable fluid or any toxic fluid, field connections shall terminate in a flange or a flanged valve. For other services, a bolted and gasketed blind flange shall be used. Tapped openings may be alternatively used, provided that they are plugged with round-head plugs furnished in accordance with the dimensional requirements of ANSI B16.11 and seal-welded. VENDOR: Some openings are plugged to close a cross drilling in the part. These openings will not have a blind flange. They will be plugged to VENDOR standards. Round head plugs are not used and may not be seal welded. PETROBRAS: Plugs not in accordance with API Std 617 and ANSI/ASME B16.11 requirements are not acceptable for process compressors. Regarding transportation services, VENDOR to provide its standard plug details for PETROBRAS review and approval.

Closed 700

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2.5.1

Shaft ends for couplings shall conform to the requirements of API Std 671. VENDOR: Shaft ends are configured to accept a coupling hub located by interference fits. Torque is transmitted through a spline.

PETROBRAS: Basically API Std 671 shall apply, considering keyless hydraulic tapered fits of 1:24. Deviations shall be clearly stated case by case, with reference list, and included in proposal. VENDOR: API 617 allows the torque to be transmitted through a spline. Additional details are Included in the datasheet. PETROBRAS: Acceptable for transportation services only.

Closed 100

2.5.1

Shaft ends for couplings shall conform to the requirements of API Std 671. VENDOR: Shaft ends shall be conform to VENDOR’s standard (5% taper)

PETROBRAS: Basically API Std 671 shall apply, considering keyless hydraulic tapered fits of 1:24. Deviations shall be clearly stated case by case, with reference list, and included in proposal. VENDOR: A 1:20 taper (5%) is also listed in API 671 4th edition Annex G Table G.1. All of VENDOR's tapered shaft ends are executed with a 1:20 taper. PETROBRAS: Noted. VENDOR to provide special tool for such non-standard taper assembly at no extra cost to PETROBRAS.

Closed 400

2.5.1

Shaft ends for couplings shall conform to the requirements of API Std 671. VENDOR: Shaft end with taper 1:20, in accordance with VENDOR standard, is provided.

PETROBRAS: Basically API Std 671 shall apply, considering keyless hydraulic tapered fits of 1:24. Deviations shall be clearly stated case by case, with reference list, and included in proposal. VENDOR has not replied. PETROBRAS’ decision: VENDOR to provide special tool for such non-standard taper assembly at no extra cost to PETROBRAS.

Closed 900

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2.5.3

The final surface finish of sensing areas to be observed by radial vibration probes shall be a maximum of 1.0 µm (0.32 mil.) Ra, preferably obtained by honing or burnishing. These areas shall be properly demagnetized to the levels specified in API Std 670, or otherwise treated so that the combined total electrical and mechanical runout does not exceed 5 µm (0.25 mil) for areas to be observed by radial vibration probes. Note: If all reasonable efforts fail to achieve the limits noted in 2.5.3, the vendor and the purchaser should mutually agree on alternate acceptance criteria. VENDOR: Probe tip diameter is considered to be the diameter of the sensing element. Bidder will attempt to achieve a combined radial, electrical and mechanical runout limit of .25 mil. After a .5 mil combined radial, electrical and mechanical level has been reached, Bidder will make two additional attempts for a lower level by burnishing. After two attempts, if the level is .5 mil or less, it will be considered as acceptable.

PETROBRAS: Not acceptable. VENDOR: 0.25 mil mechanical runout may not be achievable for all compressor applications, depending on the size and the operating conditions of the compressor. VENDOR will attempt to reach a 0.5 mil combined runout as desired. If this cannot be achieved than VENDOR and the client will discuss a mutually agreed upon resolution to the issue. PETROBRAS: Radial runouts above 6.35 µm (0.25 mil) will only be accepted if the vendor can demonstrate that all efforts to reduce the actual runout (combined) to API levels have been exhausted. Refer to comment to this item made by VENDOR #800.

Closed 200

2.5.3

The final surface finish of sensing areas to be observed by radial vibration probes shall be a maximum of 1.0 µm (0.32 mil.) Ra, preferably obtained by honing or burnishing. These areas shall be properly demagnetized to the levels specified in API Std 670, or otherwise treated so that the combined total electrical and mechanical runout does not exceed 5 µm (0.25 mil) for areas to be observed by radial vibration probes. Note: If all reasonable efforts fail to achieve the limits noted in 2.5.3, the vendor and the purchaser should mutually agree on alternate acceptance criteria. VENDOR: These areas shall be… treated so that the combined total electrical and mechanical runout does not exceed 25% of the test level calculated from Equation 1.2-10a or 6.4 µm, whichever is greater for areas to be observed by radial vibration probes.

PETROBRAS: Correct. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

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2.5.3

The final surface finish of sensing areas to be observed by radial vibration probes shall be a maximum of 1.0 µm (0.32 mil.) Ra, preferably obtained by honing or burnishing. These areas shall be properly demagnetized to the levels specified in API Std 670, or otherwise treated so that the combined total electrical and mechanical runout does not exceed 5 µm (0.25 mil) for areas to be observed by radial vibration probes. Note: If all reasonable efforts fail to achieve the limits noted in 2.5.3, the vendor and the purchaser should mutually agree on alternate acceptance criteria. VENDOR: Two attempts will be carried out to achieve the limits given in 2.5.3.

PETROBRAS: Not acceptable. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

2.5.3

The final surface finish of sensing areas to be observed by radial vibration probes shall be a maximum of 1.0 µm (0.32 mil.) Ra, preferably obtained by honing or burnishing. These areas shall be properly demagnetized to the levels specified in API Std 670, or otherwise treated so that the combined total electrical and mechanical runout does not exceed 5 µm (0.25 mil) for areas to be observed by radial vibration probes. Note: If all reasonable efforts fail to achieve the limits noted in 2.5.3, the vendor and the purchaser should mutually agree on alternate acceptance criteria. VENDOR: The 0.25 mils equals to 6.35 µm not 5 µm. Then the combined total electrical and mechanical runout does not exceed 6.35 µm.

PETROBRAS: Correct. VENDOR: Noted. PETROBRAS: Noted.

Closed 500

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2.5.3

The final surface finish of sensing areas to be observed by radial vibration probes shall be a maximum of 1.0 µm (0.32 mil.) Ra, preferably obtained by honing or burnishing. These areas shall be properly demagnetized to the levels specified in API Std 670, or otherwise treated so that the combined total electrical and mechanical runout does not exceed 5 µm (0.25 mil) for areas to be observed by radial vibration probes. Note: If all reasonable efforts fail to achieve the limits noted in 2.5.3, the vendor and the purchaser should mutually agree on alternate acceptance criteria. VENDOR: Three attempts to achieve the combined run-out will be made. If a level of 0.5mil or less is the best achieved upon completion of the three attempts, it will be considered acceptable.

PETROBRAS: Not acceptable. VENDOR: Based on experience the more stringent requirements of the specification do not produce more reliable, trouble free equipment. If not achievable after 3 attempts, then the parts will likely need to be scrapped and lead to project delays. PETROBRAS: Radial runouts above 6.35 µm (0.25 mil) will only be accepted if the vendor can demonstrate that all efforts to reduce the actual runout (combined) to API levels have been exhausted. Refer to comment to this item made by VENDOR #800.

Closed 700

2.5.3

The final surface finish of sensing areas to be observed by radial vibration probes shall be a maximum of 1.0 µm (0.32 mil.) Ra, preferably obtained by honing or burnishing. These areas shall be properly demagnetized to the levels specified in API Std 670, or otherwise treated so that the combined total electrical and mechanical runout does not exceed 5 µm (0.25 mil) for areas to be observed by radial vibration probes. Note: If all reasonable efforts fail to achieve the limits noted in 2.5.3, the vendor and the purchaser should mutually agree on alternate acceptance criteria. VENDOR: Clarification: Change the second sentence to: ‘…the combined total electrical and mechanical runout does not exceed 6.35 µm (0.25 mil)…’

PETROBRAS: Correct.

Closed 800

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2.5.3

The final surface finish of sensing areas to be observed by radial vibration probes shall be a maximum of 1.0 µm (0.32 mil.) Ra, preferably obtained by honing or burnishing. These areas shall be properly demagnetized to the levels specified in API Std 670, or otherwise treated so that the combined total electrical and mechanical runout does not exceed 5 µm (0.25 mil) for areas to be observed by radial vibration probes. Note: If all reasonable efforts fail to achieve the limits noted in 2.5.3, the vendor and the purchaser should mutually agree on alternate acceptance criteria. VENDOR: For areas to be observed by radial probes the total run-out allowed is calculated as 6.25*(12000/RPM)1/2 or 6.35 µm, whichever is greater. This figure is consistent with the amount of run-out that may be vectorially subtracted during MRT (see chapter 1, par. 2.6.8.11; cited eq. is in fact 1.2-6, not 1.2-8). For large rotors (bearing diameter ³ 250mm), the maximum allowable value is 15 µm.

PETROBRAS Correct. Closed 900

2.5.5

Replaceable thrust collars shall be furnished only when they are required for removal of shaft end seals. When replaceable collars are furnished (for assembly and maintenance purposes), they shall be positively locked to the shaft to prevent fretting. When integral collars larger than 5 in. diameter are furnished, they shall be provided with at least 3 mm (1/8 in.) of additional stock to enable refinishing if the collar is damaged. Note: Integral thrust collars are required unless thrust collars must be removed. VENDOR: VENDOR standard is a hydraulic fit which is considered positively locking. VENDOR standard is a hydraulic fit on a sleeve. As additional security a shaft nut is provided to prevent axial movement.

PETROBRAS: Not acceptable. VENDOR: Confirmed. Comment will be withdrawn. PETROBRAS: Noted.

Closed 600

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2.5.6

Both faces of thrust collars shall have a surface finish of not more than 0.4 mm (16 min.) Ra, and the axial total indicator runout of either face shall not exceed 13 mm (0.0005 in.). VENDOR: The total indicated runout of either face shall not exceed 0.001 inches (25.4 micrometers).

PETROBRAS: Not acceptable. VENDOR: VENDOR confirms compliance with the API specification. PETROBRAS: Noted.

Closed 200

2.5.6

Both faces of thrust collars shall have a surface finish of not more than 0.4 µm (16 µin.) Ra, and the axial total indicator runout of either face shall not exceed 13 µm (0.0005 in.). VENDOR: For large rotors (bearing diameter ≥ 250 mm), the maximum allowable axial run-out is 20 µm.

PETROBRAS: Not acceptable. VENDOR has not replied. PETROBRAS’ decision: Axial runouts above API limits will only be accepted if the vendor can demonstrate that all efforts to reduce the actual runout (combined) to API levels have been exhausted.

Closed 900

2.5.7

Stationary labyrinth seals shall have replaceable shaft sleeves or be designed so that major rotating parts need not be replaced. Labyrinth-type seals with the teeth on the rotating element shall have replaceable non-rotating element of an abradable material. VENDOR: Interstage balance piston and shaft end sealing lab. can be either stationary or rotating depending on the working pressure. Rotating lab. strips do not cause bending of the shaft when rubbing occurs between lab. and stator and are thus preferred. The lab. strips are easily individually replaceable. The stationary interstage labyrinths and balance piston do not contact the shaft and thus sleeves are not required.

PETROBRAS: PETROBRAS does not accept abradable rotating parts. VENDOR to follow API requirements. VENDOR: It is confirmed that no abradable rotating labyrinths are used. PETROBRAS: Noted.

Closed 400

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2.5.10.3

All accessible weld surfaces on welded impellers and finish machined surfaces of electro eroded impellers shall be inspected by visual and magnetic particle or liquid penetrant examination. Impeller fabrications resulting in joints that are not visually accessible, such as brazed joints, shall be subjected to ultrasonic examination to verify joint integrity. Refer to 4.2.2 for material inspection methods and 4.2.2.1.1 for acceptance criteria. VENDOR: Clarification: VENDOR may use liquid penetrant inspection for brazed impeller joints since the joints are visually accessible.

PETROBRAS: Not acceptable. PETROBRAS’ decision: API requirements to be followed. VENDOR’s clarification is considered acceptable for fully visually accessible joints only. VENDOR: Joint integrity for brazed impellers shall be inspected by UT and FPT. PETROBRAS: Accepted.

Closed 800

2.6

Dynamics. VENDOR: VENDOR interpretation and criteria for meeting the requirements of this section are detailed in VENDOR Standard Specification which will be included in VENDOR's proposal.

PETROBRAS: Not acceptable. It is a vague statement. VENDOR to provide detailed list of deviations case by case, item by item. VENDOR #200: The referenced bidder specification is not a deviation to the API standard. It is a procedure that goes into detail about how VENDOR complies with the specification requirements and is only presented for clarification. PETROBRAS: As above. VENDOR’s standard specification on dynamics has not yet been received. VENDOR #300: Not enough information. VENDOR #200: The above referenced specification shall be sent to PETROBRAS for evaluation. PETROBRAS: For the time being, noted. Final decision will be taken upon receipt of procedure.

Closed 200

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2.6

Dynamics. VENDOR: Following exception is only valid for SPCP pipeline compressors for which a speed range below 70% of nominal gas turbine speed is specified: API requires a certain separation margin to critical speeds of the rotor system. Response peaks with a sufficiently small amplification factor (AF<2.5) are evaluated as permissible within the operating speed range. This definition of the limit AF=2.5 is not a physical boundary, but based on operating experience. The fundamental aspect behind this rule is the limitation of high vibration amplitudes, which could lead to fatigue in the long-term. Since API has to cover all applications and in particular also most adverse process conditions with dirty gases and fouling, API needs of course to be conservative. In particular for SPCP pipeline compressors VENDOR allows response peaks with a larger amplification factor than 2.5 to be located within the operating speed range. Since the same alarm and shut-down levels of shaft vibration will be valid for SPCP pipeline compressors as for any other compressor, VENDOR allows amplification factors of up to 5 within the operating speed range (AF<5) for its SPCP pipeline compressors.This does not mean any elevated risk nor any reduction of reliability and life-time, since the permissible vibration levels are identical with those of any other compressor.

PETROBRAS: Critical speeds within the range of operating speeds are not automatically acceptable. Before the conclusion on accepting such nonconformance, a complete decision sequence - as per item 2.6.2.13, and other rotordynamic requirements of applicable API / PETROBRAS standards - shall be followed in order to verify all possibilities. As a result, critical speeds within the operating speed range will only be accepted if the vendor can demonstrate that all efforts to remove the critical speed from the operating speed range have been exhausted. VENDOR: Accepted. PETROBRAS: Noted.

Closed 600

2.6

Dynamics. VENDOR: Clarification: For rerates of equipment constructed under a previous edition of API standards and successfully operating in the field, VENDOR will make practical efforts, within the scope of supply, to bring the compressor up to current API standards. When this is not possible, it is VENDOR standard practice to provide a design that is analytically similar to or better than the unit currently in operation.

PETROBRAS: Noted.

Closed 800

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2.6.2.2

The location of all critical speeds below the trip speed shall be confirmed on the test stand during the mechanical running test (see 2.6.3.1). The accuracy of the analytical model shall be demonstrated (see 2.6.3). VENDOR: See exception to para. 2.6.3.1. ‘[1] A verification test of the unbalanced response analysis shall only be performed if the separation margins according to para 2.6.2.10 are not fulfilled. [2] If required, the verification test can be performed on one of the rotors with a coupling unbalance during the mechanical shop testing in the test bed, or in the vacuum bunker after high speed balancing.’

PETROBRAS: [1] PETROBRAS requires all rotor and bearing systems to be subjected to URT. Refer to item 6.2.3.1.10 of NI-2626 regarding mandatory requirement of at least one URT. [2] Usually, only URT1 is specified, but URT2 would also be necessary if URT1 results should not suffice to validate rotordynamic model. In case the balancing machine is used, rotor and bearing systems shall be equivalent to actual design. VENDOR to demonstrate equivalence with analytical models. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 400

NI-2626, 6.2.3.1.2

Addition (2.6.2.4 b of API Std 617). The clearance ranges to be used in the analysis shall be: — minimum bearing clearance and maximum preload, calculated using maximum pad, minimum bearing and maximum shaft radius; — average bearing clearance and preload, calculated using mean pad, bearing and shaft radius; — maximum bearing clearance and minimum preload, calculated using minimum pad, maximum bearing and minimum shaft radius; — these calculated coefficients for the speed range, shall be presented in the damped unbalance response analysis report. Bearing circumferential temperature profile shall also be included. VENDOR: Bearing circumferential temperature profile is included in the parameters used by the Vendor tools to compute the rotordynamic behavior of the machines. The bearing temperature profile is unfortunately not available as output from our calculation software and as output from our calculation software and thus cannot be shared with the customer.

PETROBRAS: Noted.

Closed 900

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NI-2626, 6.2.3.1.3

Addition (2.6.2.4 c of API Std 617). The pad inertia and thermal effects such as radiation, convection and pad conduction shall also be considered. VENDOR: According to VENDOR rotordynamic experience and for the bearings we normally install on our machines, these effects can be considered as secondary ones, and thus negligible, in predicting/assessing the rotordynamic behavior of a centrifugal compressor. The redictability/reliability of VENDOR approach has been extensively validated by the consistency in between our theoretical rotordynamic calculations and testing+filed results.

PETROBRAS: Noted.

Closed 900

2.6.2.4.d

The damped unbalanced response analysis shall include but shall not be limited to the following: Note: The following is a list of items the analyst is to consider. It does not address the details and product of the analysis which is covered in 2.6.2.7 and 2.6.2.8… d. Support stiffness, mass, and damping characteristics, including effects of frequency dependent variation. The term “support” includes the foundation or support structure, the base, the machine frame and the bearing housing as appropriate. For machines whose bearing support system stiffness values are less than or equal to 3.5 times the bearing oil film stiffness values, support stiffness values derived from modal testing or calculated frequency dependent support stiffness and damping values (impedances) shall be used. The vendor shall state the support stiffness values used in the analysis and the basis for these values (for example, modal tests of similar rotor support systems, or calculated support stiffness values). Note 1: The support stiffness should in most cases be no more than 8.75 × 106 N/mm (5 × 106 lb./in.). Note 2: Guide lines are used to define whether or not bearing support stiffness should be considered. While modal testing of the actual bearing support system would be preferred, an analytical analysis (such as FEA) is permitted. VENDOR: Clarification: The effective stiffness of the support structure is considered rigid, based on VENDOR experience of the past 30+ years. This has provided a good correlation of the predicted speed with test data.

PETROBRAS: VENDOR's experience, alternate methods and criteria will always be considered by PETROBRAS, provided they have been previously discussed and accepted by PETROBRAS (before the order). Otherwise, PETROBRAS will strictly follow API 617 requirements together with the amendments of its standards and technical specifications.

Closed 800

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2.6.2.6

When specified, the effects of other equipment in the train shall be included in the damped unbalanced response analysis (that is, a train lateral analysis shall be performed). Note: In particular, this analysis should be considered for machinery trains with rigid couplings. VENDOR: No train lateral analysis will be performed because flexible couplings are applied and the effects of other equipment are not transmitted.

PETROBRAS: Train lateral analysis shall be performed when specified. VENDOR: Confirmed, train lateral analysis is performed when specified. PETROBRAS: Noted.

Closed 500

2.6.2.9

Additional analyses shall be made for use with the verification test specified in 2.6.3. The location of the unbalance shall be determined by the vendor. Any test stand parameters which influence the results of the analysis shall be included. Note: For most machines, there will only be one plane readily accessible for the placement of an unbalance; for example, the coupling flange on a single ended drive machine, or the impeller hub or disk on an integrally geared machine, or expander-compressors. However, there is the possibility that more planes are available such as axial compressor balance planes, or on through drive compressors. When this occurs, and there is the possibility of exciting other criticals, multiple runs may be required. VENDOR: If the test specified in 2.6.3 is performed, the location of the unbalance will be in correspondence of the coupling.

PETROBRAS: Acceptable. Closed 900

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2.6.2.11

The calculated unbalanced peak to peak amplitudes (see 2.6.2.8b) shall be multiplied using the correction factor calculated from Equation 1.2-5. The correction factor shall have a value greater than 0.5. VENDOR: Exception: VENDOR will apply a maximum correction factor, CF = 2.0, which corresponds to a maximum amount of unbalance equal to eight times (4 W/N) since that is all that is required in the testing phase.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR: [1] API 617-8th edition, when it is released, will require 12*4W/N, which is equivalent to CF = 3.0. We can agree to comply with that. [2] API 617-7 has no limit, which is very risky. [3] If all we have is abradable seals, and PETROBRAS has no requirement on the clearance, which would need to be confirmed, then we can comply to API 617-7th edition. [4] Otherwise, we should propose to comply to the requirements that will be in API 617-8th edition. PETROBRAS: [1] PETROBRAS agrees to discuss when API Std 617 8th edition is released. Additionally, all paragraphs regarding such subject should be discussed together. [2] Risks may occur, depending on design quality. PETROBRAS expects that qualified vendors always take all necessary measures to avoid or overcome design faults. [3] PETROBRAS has in fact already stated its requirements on the use of abradable materials. Refer to paragraph 2.6.2.12 below. [4] As above, PETROBRAS and vendors shall discuss the entire standard, not just a single, isolated, paragraph.

Closed 800

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2.6.2.12

The calculated major-axis, peak-to-peak, unbalanced rotor response amplitudes, corrected in accordance with 2.6.2.11 at any speed from zero to trip speed shall not exceed 75% of the minimum design diametral running clearances throughout the machine (with the exception of floating-ring seal locations). For machines with abradable seals, the response amplitude to the running clearance shall be mutually agreed. Note: Running clearances may be different than the assembled clearances with the machine shutdown. VENDOR: Peak-to-peak amplitudes at labyrinth seals may exceed 75% of assembled clearance. Abradable seals are provided to minimize internal leakage flow.

PETROBRAS: For conventional labyrinths, API 75% limit shall be followed. When abradable seals are used, the allowable response amplitude could be considered 100% of abradable seals minimum clearance or equivalent of 75% of the minimum clearance of a non-abradable (conventional) labyrinth from the VENDOR standard that could be used in the analysis. It is a VENDOR’S choice. The VENDOR shall inform to PETROBRAS which values will be used in the analysis. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

2.6.2.12

The calculated major-axis, peak-to-peak, unbalanced rotor response amplitudes, corrected in accordance with 2.6.2.11 at any speed from zero to trip speed shall not exceed 75% of the minimum design diametral running clearances throughout the machine (with the exception of floating-ring seal locations). For machines with abradable seals, the response amplitude to the running clearance shall be mutually agreed. Note: Running clearances may be different than the assembled clearances with the machine shutdown. VENDOR: Diametral running clearances are designed to provide optimum aerodynamic performance without compromising mechanical integrity. The calculated unbalanced peak-to-peak rotor amplitudes (see 2.6.2.11) at any speed from zero to trip may exceed 75 percent of these clearances. Minor labyrinth seal rubs (during testing) that do not exceed Bidder's assembly drawing clearances are considered acceptable.

PETROBRAS: For conventional labyrinths, API 75% limit shall be followed. When abradable seals are used, the allowable response amplitude could be considered 100% of abradable seals minimum clearance or equivalent of 75% of the minimum clearance of a non-abradable (conventional) labyrinth from the VENDOR standard that could be used in the analysis. It is a VENDOR’S choice. The VENDOR shall inform to PETROBRAS which values will be used in the analysis. VENDOR: VENDOR will comply with the API requirement with regard to unbalanced peak-to-peak rotor amplitudes limitations to 75% of the diametral running clearances. Minor labyrinth seal rubs (during testing) that do not exceed VENDOR's assembly drawing clearances are considered acceptable. PETROBRAS: Noted.

Closed 200

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2.6.2.12

The calculated major-axis, peak-to-peak, unbalanced rotor response amplitudes, corrected in accordance with 2.6.2.11 at any speed from zero to trip speed shall not exceed 75% of the minimum design diametral running clearances throughout the machine (with the exception of floating-ring seal locations). For machines with abradable seals, the response amplitude to the running clearance shall be mutually agreed. Note: Running clearances may be different than the assembled clearances with the machine shutdown. VENDOR: If abradable seals are used, the allowable response amplitude shall be equivalent to the 75% of the clearance of a suitable non-abradable labyrinth from the VENDOR standard that could be used to replace the abradable seal.

PETROBRAS: For conventional labyrinths, API 75% limit shall be followed. When abradable seals are used, the allowable response amplitude could be considered 100% of abradable seals minimum clearance or equivalent of 75% of the minimum clearance of a non-abradable (conventional) labyrinth from the VENDOR standard that could be used in the analysis. It is a VENDOR’S choice. The VENDOR shall inform to PETROBRAS which values will be used in the analysis. VENDOR: Accepted. Explanation: For conventional labyrinths, API 75% limit will be used. For abradable seals, 75% limit related to the minimum clearance of a conventional labyrinth will be used. PETROBRAS: Noted.

Closed 600

2.6.2.14

When specified, in addition to the other requirements of 2.6.2, the lateral analysis report shall include the following: a. Dimensional data of the bearing design in sufficient detail to enable calculations of stiffness and damping coefficients. b. Shaft geometry with sufficient detail to model the shaft including the location of bearing centerlines and mounted components. c. The weight, polar and transverse moments of inertia and center of gravity of the impellers, balance piston, shaft end seals and coupling(s) with sufficient detail to conduct an independent analysis of the rotor. d. The input model used for the vendors analysis. e. The support stiffness used in the analysis and its basis. VENDOR: This is not part in the standard lateral analysis report, but can be included as an option.

PETROBRAS: If necessary, a non-disclosure agreement shall be discussed and signed, after the purchase order with all parties involved. VENDOR: Acknowledged. PETROBRAS: Noted.

Closed 600

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2.6.2.14

When specified, in addition to the other requirements of 2.6.2, the lateral analysis report shall include the following: a. Dimensional data of the bearing design in sufficient detail to enable calculations of stiffness and damping coefficients. b. Shaft geometry with sufficient detail to model the shaft including the location of bearing centerlines and mounted components. c. The weight, polar and transverse moments of inertia and center of gravity of the impellers, balance piston, shaft end seals and coupling(s) with sufficient detail to conduct an independent analysis of the rotor. d. The input model used for the vendors analysis. e. The support stiffness used in the analysis and its basis. VENDOR: This is not part in the standard lateral analysis report, but can be included as an option.

PETROBRAS: Disregard the bullet. Paragraph 2.6.2.14 text is mandatory. VENDOR: Accepted. PETROBRAS: Noted.

Closed 600

2.6.3

Unbalanced rotor response verification test. VENDOR: A shop verification of unbalance response is not provided.

PETROBRAS: Not acceptable. VENDOR: VENDOR can offer this as an option. Unbalance will be added to the coupling during the mechanical test to simulate an unbalance. Disassembly of the compressor will not be done to add unbalance. PETROBRAS: The Unbalance Response Test is a mandatory requirement, to be performed after Mechanical Running Test. Usually, only URT1 is required, but URT2 would also be necessary if URT1 results should not suffice to validate rotordynamic model. PETROBRAS will accept VENDOR’s choice for unbalance weight location, since it is stated on API Std 617. Disassembly of compressor to add unbalance is not expected for centrifugal compressors, just for axial ones.

Closed 700

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2.6.3

Unbalanced rotor response verification test. VENDOR: Clarification: Please refer to Page PP1628, “Shop Verification of Unbalance Response Analysis - VENDOR Criteria”. This test would be conducted on only one rotor per compressor.

PETROBRAS: Usually, only URT1 is specified, but URT2 would also be necessary if URT1 results should not suffice to validate rotordynamic model. In case the balancing machine is used, rotor and bearing systems shall be equivalent to actual design. VENDOR to demonstrate equivalence with analytical models.

Closed 800

2.6.3, 2.6.3.1

2.6.3.1. An unbalanced rotor response test shall be performed as part of the mechanical running test (see 4.3 of the applicable chapter), and the results shall be used to verify the analytical model. The actual response of the rotor on the test stand to the same arrangement of unbalance and bearing loads as was used in the analysis specified in 2.6.2.9 shall be the criterion for determining the validity of the damped unbalanced response analysis. To accomplish this, the requirements of 2.6.3.1.1 through 2.6.3.1.6 shall be followed. VENDOR: Proposed compressor has enough separation margin, so the actual unbalanced response test is not necessary. However, if the separation margin between the critical speed and the operating speed range cannot be secured, the actual unbalanced response test will be performed. The test weight and location will be determined by VENDOR.

PETROBRAS: Not acceptable. Unbalance response test shall be performed. The test weight and location will always be determined by VENDOR. VENDOR: Agreed to PETROBRAS’ comment. PETROBRAS: Noted.

Closed 300

2.6.3.1

An unbalanced rotor response test shall be performed as part of the mechanical running test (see 4.3 of the applicable chapter), and the results shall be used to verify the analytical model. The actual response of the rotor on the test stand to the same arrangement of unbalance and bearing loads as was used in the analysis specified in 2.6.2.9 shall be the criterion for determining the validity of the damped unbalanced response analysis. To accomplish this, the requirements of 2.6.3.1.1 through 2.6.3.1.6 shall be followed. VENDOR: Bidder standard is to unbalance at the coupling.


Closed 200

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2.6.3.1

An unbalanced rotor response test shall be performed as part of the mechanical running test (see 4.3 of the applicable chapter), and the results shall be used to verify the analytical model. The actual response of the rotor on the test stand to the same arrangement of unbalance and bearing loads as was used in the analysis specified in 2.6.2.9 shall be the criterion for determining the validity of the damped unbalanced response analysis. To accomplish this, the requirements of 2.6.3.1.1 through 2.6.3.1.6 shall be followed. VENDOR: [1] A verification test of the unbalanced response analysis shall only be performed if the separation margins according to para 2.6.2.10 are not fulfilled. [2] If required, the verification test can be performed on one of the rotors with a coupling unbalance during the mechanical shop testing in the test bed, or in the vacuum bunker after high speed balancing.

PETROBRAS: [1] Not acceptable. [2] Usually, only URT1 is specified, but URT2 would also be necessary if URT1 results should not suffice to validate rotordynamic model. The Unbalance Response Test (URT) can be performed after Mechanical Running Test (MRT) or after High speed balancing (HSB) at Vendor’s choice. In this case, a specific rotordynamic model, for High speed bench support stiffness shall be provided prior to the test. VENDOR: See comment to para. 2.6.2.2. PETROBRAS: Noted.

Closed 400

2.6.3.1

An unbalanced rotor response test shall be performed as part of the mechanical running test (see 4.3 of the applicable chapter), and the results shall be used to verify the analytical model. The actual response of the rotor on the test stand to the same arrangement of unbalance and bearing loads as was used in the analysis specified in 2.6.2.9 shall be the criterion for determining the validity of the damped unbalanced response analysis. To accomplish this, the requirements of 2.6.3.1.1 through 2.6.3.1.6 shall be followed. VENDOR: [1] The verification test is not included as a standard, but can be included as an option. [2] If applicable this test will be performed to Siemens standard in the high speed balancing machine.

PETROBRAS: [1] Not acceptable. [2] The Unbalance Response Test (URT) can be performed after Mechanical Running Test (MRT) or after High speed balancing (HSB) at Vendor’s choice. In this case, a specific rotordynamic model, for High speed bench support stiffness shall be provided prior to the test. VENDOR: [1] Confirmed. A verification test will be included as a standard. [2] Accepted. PETROBRAS: Noted.

Closed 600

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NI-2626, 6.2.3.2.2

Substitution (2.6.3.1.3 of API Std 617). The unbalance which was used in the analysis performed in 2.6.2.9, shall be added to the rotor in the location used in the analysis. VENDOR: A MRT-test unbalances located between the bearings are not explicitly excluded in the paragraph. Due to high amount of effort Siemens excludes setting test unbalances between the bearing location during MRT. Test unbalances between the bearing could be set after final high speed balancing in the Balancing chamber. For the case that PETROBRAS insist of setting mid- and/or out-of phase unbalances between the bearings significant additional testing costs has to be considered.


Closed 600

2.6.3.2

The vendor shall correct the model if it fails to meet either of the following criteria: a. The actual critical speeds determined on test shall not deviate from the corresponding critical speeds predicted by analysis by more than 5%. Where the analysis predicts more than one critical speed in a particular mode (due, for example, to the bearing characteristics being significantly different horizontally and vertically or between the two ends of the machine), the test value shall not be lower than 5% below the lowest predicted value nor higher than 5% above the highest predicted value. Note: It is possible, particularly on electric motors, that the vertical and horizontal stiffness are significantly different and the analysis will predict two differing critical speeds. Should the operating speed fall between these critical speeds, these two critical speeds should be treated separately, as if they resulted from separate modes. b. The actual major axis amplitude of peak responses from test, including those critically damped, shall not exceed the predicted values. The predicted peak response amplitude range shall be determined from the computer model based on the four radial probe locations. VENDOR: In case predicted values are exceeded VENDOR considers the design acceptable if the requirements of para. 2.6.2.12 are met.

PETROBRAS: Not acceptable. API requirement to be followed. VENDOR: Accepted. PETROBRAS: Noted.

Closed 600

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NI-2626, 6.2.3.2.5

Addition (2.6.3.2 c of API Std 617). The predicted amplification factors shall not deviate from the actual test-stand values by more than ± 20 %. VENDOR: [1] According to API Std we never compare the Af actual with AF predicted. [2] Your requirement can be not accepted during proposal phase. If of your interest it can be discussed during execution phase.

PETROBRAS: [1] This is a former acceptance criterion from API 617 past editions, withdrawn from 7th. Ed. It is PETROBRAS understanding that such requirement still applies and, therefore, shall be considered during execution phase. [2] VENDOR is correct when stating that it is not possible to guess, during bid stage, whether actual AF would deviate from predicted AF by more than ± 20 % or not. Nevertheless, VENDOR shall foresee and consider the possibility, and shall be prepared to comply with such criterion during testing phase, without any additional cost to PETROBRAS. VENDOR #300: Not agreed. PETROBRAS: PETROBRAS re-states comments above. Subject closed.

Closed 900

2.6.4

Additional testing. VENDOR: This test is not performed. Further additional tests, not requiring disassembly of the machine, may be done in agreement with Customer. It is understood that these additional tests will be performed on one rotor only.

PETROBRAS: Not acceptable. Additional tests as per 2.6.4.2 shall be performed if Machine fails to meet 2.6.4.1 criteria.

Closed 900

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2.6.4.1

Additional testing is required (see 2.6.4.2) if from the shop verification test data (see 2.6.3) or from the damped, corrected unbalanced response analysis (see 2.6.3.3), it appears that either of the following conditions exists: a. Any critical response which fails to meet the SM requirements (see 2.6.2.10) or which falls within the operating speed range. b. The clearance requirements of 2.6.2.12 have not been met. VENDOR: If the VENDOR and the Purchaser concur that a critical speed response as calculated or revealed during mechanical test falls within the specified separation margin or does not meet 2.6.2.12, one or all of the following steps will be taken at the option of the VENDOR: 1. Practical design modifications will be made in an attempt to adjust the critical speed to fall outside the separation margin. 2. The VENDOR will demonstrate the sensitivity of the rotor design as applicable. The amount of unbalance weight, location, and amplitude limits for the unbalance test will be reviewed with the client. 3. The VENDOR will verify analytically that, on the permanent foundation, the critical speed response will not fall within the specified separation margins.

PETROBRAS: Correction steps shall not be at VENDOR's discretion only. It is PETROBRAS understanding that if meeting the Separation Margins or item 2.6.2.12 requirements becomes impossible, then both PETROBRAS and VENDOR should discuss and agree on further steps to be done. PETROBRAS baseline for discussions is as follows: 1. Design modifications are preferred instead of additional unusual tests; 2. Test procedure to be agreed, based on paragraph 2.6.4.2. 3. Not acceptable.

Closed 800

2.6.4.2

Unbalance weights shall be placed as described in 2.6.2.7; this may require disassembly of the machine. Unbalance magnitudes shall be achieved by adjusting the indicated unbalance that exists in the rotor from the initial run to raise the displacement of the rotor at the probe locations to the vibration limit defined by Equations 1.2-6a or 1.2-6b (see 2.6.2.11) at the maximum continuous speed; however, the unbalance used shall be no less than twice or greater than 8 times the unbalance limit specified in 2.6.2.7, Equations 1.2-2a or 1.2-2b. The measurements from this test, taken in accordance with 2.6.3.1.1 and 2.6.3.1.2, shall meet the following criteria: a. At no speed outside the operating speed range, including the SM, shall the shaft deflections exceed 90% of the minimum design running clearances. b. At no speed within the operating speed range, including the SM, shall the shaft deflections exceed 55% of the minimum design running clearances or 150% of the allowable vibration limit at the probes (see 2.6.2.11). VENDOR: If additional testing per 2.6.4.1 is required, the Purchaser and Bidder shall agree on requirements for any additional testing and on the equipment's acceptability.

PETROBRAS: Paragraph 2.6.4.2 shall be followed, however test procedure shall be discussed. VENDOR: Acknowledged. PETROBRAS: Noted.

Closed 200

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2.6.4.2

Unbalance weights shall be placed as described in 2.6.2.7; this may require disassembly of the machine. Unbalance magnitudes shall be achieved by adjusting the indicated unbalance that exists in the rotor from the initial run to raise the displacement of the rotor at the probe locations to the vibration limit defined by Equations 1.2-6a or 1.2-6b (see 2.6.2.11) at the maximum continuous speed; however, the unbalance used shall be no less than twice or greater than 8 times the unbalance limit specified in 2.6.2.7, Equations 1.2-2a or 1.2-2b. The measurements from this test, taken in accordance with 2.6.3.1.1 and 2.6.3.1.2, shall meet the following criteria: a. At no speed outside the operating speed range, including the SM, shall the shaft deflections exceed 90% of the minimum design running clearances. b. At no speed within the operating speed range, including the SM, shall the shaft deflections exceed 55% of the minimum design running clearances or 150% of the allowable vibration limit at the probes (see 2.6.2.11). VENDOR: Exception: It is extremely difficult and time consuming to perform a meaningful verification test by putting unbalance inside the compressor on the test floor. Unusually high amounts of unbalance may be required analytically to raise the amplitude at the probe locations to the vibration limit. Calculated high unbalance, if required for the verification test per this requirement, can be detrimental to the machine and may also pose a safety hazard.

PETROBRAS: Not acceptable. The additional tests as per 2.6.4.2 shall be performed whenever Machine fails to meet 2.6.4.1 criteria, which means the machine being tested has a problem. The unbalance weight shall be sufficient to create a discernable difference in the first critical based on vectorial subtraction. In addition, since the goal is to excite the critical speed, the location of weights shall be mutually agreed upon by PETROBRAS and VENDOR. PETROBRAS may agree with fewer runs, if such runs are capable of exciting the critical speed and to render a significant difference in amplitudes when compared to MRT results. VENDOR #300: Not agreed. Agreed with VENDOR. PETROBRAS: PETROBRAS re-states comments above. Subject closed.

Closed 800

2.6.5, 2.6.5.10,

2.6.6

2.6.5. Level I stability analysis. 2.6.5.10. Level I screening criteria. 2.6.6. Level II stability analysis. VENDOR: Necessity of level II stability analysis shall be determined in accordance with Fig.2-5 of API617 without Level I analysis.

PETROBRAS: Not acceptable. Level I analysis shall be performed. VENDOR: Agreed to PETROBRAS’ comment. PETROBRAS: Noted.

Closed 300

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2.6.5.1

A stability analysis shall be performed on all centrifugal or axial compressors and/or radial flow rotors except those rotors whose maximum continuous speed is below the first critical speed in accordance with 2.6.2.3, as calculated on rigid supports. For this analysis, the machine inlet and discharge conditions shall be at either the rated condition or another operating point unless the vendor and purchaser agree upon another operating point. Note: Level I analysis was developed to fulfill two purposes: first, it provides an initial screening to identify rotors that do not require a more detailed study. The approach as developed is conservative and not intended as an indication of an unstable rotor. Second, the Level I analysis specifies a standardized procedure applied to all manufacturers similar to that found in 2.6.2. (Refer to API Publ 684, 1.6 for a detailed explanation.) VENDOR: It is VENDOR standard to execute an in-house stability analysis taking into consideration the actual destabilizing seal forces. This comes very close to a Level II stability analysis.

PETROBRAS: If VENDOR prefers to do only a level II analysis, including the requirements of paragraphs 2.6.2.4 and 2.6.6.2, this is acceptable. VENDOR: Noted. PETROBRAS: Noted.

Closed 600

NI-2626, 6.2.3.4.1

Substitution (2.6.6.5 of API Std 617). The Level II stability analysis shall indicate that the machine, as calculated in 2.6.6.1 through 2.6.6.3, shall have a final log decrement, δf, greater than 0.2. VENDOR: It is VENDOR standard to execute an in-house stability analysis taking into consideration the actual destabilizing seal forces. This comes very close to a Level II stability analysis.

PETROBRAS: PETROBRAS criteria to be followed. Closed 900

NI-2626, 6.2.3.4.2

New (2.6.6.7). A stability test, to measure damping ratio (and to determine the corresponding log decrement),shall be performed if one of the following conditions is satisfied: a) the machine fails to meet the criteria specified in item 2.6.6.5; b) the test has been specified in compressor data sheet. VENDOR: It is VENDOR standard to execute an in-house stability analysis taking into consideration the actual destabilizing seal forces. This comes very close to a Level II stability analysis.

PETROBRAS: Whenever test is performed in balancing machine, acceptance criteria shall be changed in order to compensate for absence of casing. VENDOR #300: Not enough information. PETROBRAS: PETROBRAS re-states comment above. VENDOR #300’s comment disregarded. Subject closed.

Closed 900 PRELIMIN

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2.6.7.3

The torsional natural frequencies of the complete train shall be at least 10% above or 10% below any possible excitation frequency within the specified operating speed range (from minimum to maximum continuous speed). VENDOR: Higher torsional modes may occur within the stated range. In such a case it will be demonstrated either through references machines or simulation that the resonances do not have an adverse effect on the train.

PETROBRAS: Not acceptable. Paragraph 2.6.7.5 criteria shall be applied. VENDOR: Accepted. PETROBRAS: Noted.

Closed 600

2.6.7.4

Torsional natural frequencies at two or more times running speeds shall preferably be avoided or, in systems in which corresponding excitation frequencies occur, shall be shown to have no adverse effect. VENDOR: Bidder standard practice is to tune couplings for one times running speed only.

PETROBRAS: It is PETROBRAS understanding that torsional frequencies at two or more times running speeds shall always be avoided. However, for those cases where it is not possible to detune frequencies, API Std 617 shall govern, especially regarding stress analyses. VENDOR: Acknowledged. PETROBRAS: Noted.

Closed 200

2.6.7.4

Torsional natural frequencies at two or more times running speeds shall preferably be avoided or, in systems in which corresponding excitation frequencies occur, shall be shown to have no adverse effect. VENDOR: Torsional natural frequencies at two times running speed as well as one and two times line frequency for motor driven systems shall preferably be avoided or, in systems in which corresponding excitation frequencies occur, shall be shown to have no adverse effect.

PETROBRAS: Noted. Paragraph 2.6.7.5 shall be followed, if necessary. It is PETROBRAS understanding that torsional frequencies at two or more times running speeds shall always be avoided. However, for those cases where it is not possible to detune frequencies, API Std 617 shall govern, especially regarding stress analyses. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

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2.6.7.4

Torsional natural frequencies at two or more times running speeds shall preferably be avoided or, in systems in which corresponding excitation frequencies occur, shall be shown to have no adverse effect. VENDOR: Higher torsional modes may occur within the stated range. In such a case it will be demonstrated either through references machines or simulation that the resonances do not have an adverse effect on the train.

PETROBRAS: Not acceptable. Paragraph 2.6.7.5 criteria shall be applied. VENDOR: Accepted. PETROBRAS: Noted.

Closed 600

2.6.7.5

When torsional resonances are calculated to fall within the margin specified in 2.6.7.3 (and the purchaser and the vendor have agreed that all efforts to remove the critical from within the limiting frequency range have been exhausted), a stress analysis shall be performed to demonstrate that the resonances have no adverse effect on the complete train. The assumptions made in this analysis regarding the magnitude of excitation and the degree of damping shall be clearly stated. The acceptance criteria for this analysis shall be mutually agreed upon by the purchaser and the vendor. VENDOR: If a stress analysis is performed to satisfy this paragraph, then the acceptance criteria shall be the Bidder standard criteria for fatigue analysis.

PETROBRAS: When the requirements of paragraphs 2.6.7.3 and 2.6.7.4 are not met, and the VENDOR demonstrates that all efforts have been exhausted and PETROBRAS concurs, then stress analysis shall be performed. The acceptance criteria shall always be discussed and mutually agreed upon by PETROBRAS and VENDOR after the purchase order, case by case. VENDOR: Acknowledged. PETROBRAS: Noted.

Closed 200

2.6.7.5

When torsional resonances are calculated to fall within the margin specified in 2.6.7.3 (and the purchaser and the vendor have agreed that all efforts to remove the critical from within the limiting frequency range have been exhausted), a stress analysis shall be performed to demonstrate that the resonances have no adverse effect on the complete train. The assumptions made in this analysis regarding the magnitude of excitation and the degree of damping shall be clearly stated. The acceptance criteria for this analysis shall be mutually agreed upon by the purchaser and the vendor. VENDOR: Clarification: VENDOR interprets "all efforts to remove the critical from within the frequency range have been exhausted" to mean that no acceptable coupling(s) can be found to remove all critical speeds from all limiting frequency ranges.

PETROBRAS: Noted. However, the VENDOR shall demonstrate that all efforts have been exhausted, as per API Std 617, paragraph 2.6.7.5.

Closed 800

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2.6.8.1

Major parts of the rotating element, such as the shaft, balancing drum and impellers, shall be individually dynamically balanced before assembly, to ISO 1940 Grade G1 or better. When a bare shaft with a single keyway is dynamically balanced, the keyway shall be filled with a fully crowned half key, in accordance with ISO 8821. Keyways 180 degrees apart, but not in the same transverse plane, shall also be filled. The initial balance correction to the bare shaft shall be recorded. The components to be mounted on the shaft (impellers, balance drum, etc.), shall also be balanced in accordance with the “half-key-convention,” as described in ISO 8821. VENDOR: Impellers only are individually balanced according to vendor’s standard.

PETROBRAS: Not acceptable. VENDOR: Balance piston is integrated in the shaft. The shaft is as rotational symmetric part. Therefore balancing of the shaft is not required. The impellers will be balanced individually in accordance with ISO 1940 Grade G1.0. The assembled rotor is subject to at speed balancing. PETROBRAS: Noted. From the viewpoint of machinery design, PETROBRAS is not concerned with machinery balance criteria. The methods, procedures, quality and degree of dynamic balancing chosen by the Vendor will always be evaluated by the vibration readings taken and recorded during factory acceptance tests (FAT1) and field acceptance tests (FAT2). Regarding maintenance purposes, balance quality as adopted by the Vendor is an item of utmost importance.

(a) After completion of the final balancing, all major elements of the assembled rotor shall be match marked.

(b) Balance quality data (as designed / as final) for all rotating equipment and components shall be provided in IOM manuals and other applicable documents.

(c) Balance quality shall always be stated in accordance with applicable ISO standards.

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2.6.8.2

Unless otherwise specified, the rotating element shall be sequentially multiplane dynamically balanced during assembly. This shall be accomplished after the addition of no more than two major components. Balancing correction shall only be applied to the elements added. Minor correction of other components may be required during the final trim balancing of the completely assembled element. In the sequential balancing process, any half-keys used in the balancing of the bare shaft (see 2.6.8.1) shall continue to be used until they are replaced with the final key and mating element. On rotors with single keyways, the keyway shall be filled with a fully crowned half-key. The weight of all half-keys used during final balancing of the assembled element shall be recorded on the residual unbalance worksheet (see Annex 1B). The maximum allowable residual unbalance per plane (journal) shall be calculated as follows… VENDOR: VENDOR does not sequentially balance the compressor rotating element.

PETROBRAS: From the viewpoint of machinery design, PETROBRAS is not concerned with machinery balance criteria. The methods, procedures, quality and degree of dynamic balancing chosen by the VENDOR will always be evaluated by the vibration readings taken and recorded during factory acceptance tests (FAT1) and field acceptance tests (FAT2). Regarding maintenance purposes, balance quality as adopted by the VENDOR is an item of utmost importance: (a) After completion of the final balancing, all major elements of the assembled rotor shall be match marked. (b) Balance quality data (as designed / as final) for all rotating equipment and components (both at low speed balancing and, if specified, at high speed) shall be provided in IOM manuals and other applicable documents. (c) Balance quality shall always be stated in accordance with ISO standards. VENDOR: Noted. PETROBRAS: Noted.

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2.6.8.2

Unless otherwise specified, the rotating element shall be sequentially multiplane dynamically balanced during assembly. This shall be accomplished after the addition of no more than two major components. Balancing correction shall only be applied to the elements added. Minor correction of other components may be required during the final trim balancing of the completely assembled element. In the sequential balancing process, any half-keys used in the balancing of the bare shaft (see 2.6.8.1) shall continue to be used until they are replaced with the final key and mating element. On rotors with single keyways, the keyway shall be filled with a fully crowned half-key. The weight of all half-keys used during final balancing of the assembled element shall be recorded on the residual unbalance worksheet (see Annex 1B). The maximum allowable residual unbalance per plane (journal) shall be calculated as follows… VENDOR: The rotor shall be balanced according to the VENDOR’s standard. Depending on the specific rotor design a sequential low speed balancing may not be possible.

PETROBRAS: From the viewpoint of machinery design, PETROBRAS is not concerned with machinery balance criteria. The methods, procedures, quality and degree of dynamic balancing chosen by the VENDOR will always be evaluated by the vibration readings taken and recorded during factory acceptance tests (FAT1) and field acceptance tests (FAT2). Regarding maintenance purposes, balance quality as adopted by the VENDOR is an item of utmost importance: (a) After completion of the final balancing, all major elements of the assembled rotor shall be match marked. (b) Balance quality data (as designed / as final) for all rotating equipment and components (both at low speed balancing and, if specified, at high speed) shall be provided in IOM manuals and other applicable documents. (c) Balance quality shall always be stated in accordance with ISO standards. VENDOR: Noted. PETROBRAS: Noted.

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2.6.8.2

Unless otherwise specified, the rotating element shall be sequentially multiplane dynamically balanced during assembly. This shall be accomplished after the addition of no more than two major components. Balancing correction shall only be applied to the elements added. Minor correction of other components may be required during the final trim balancing of the completely assembled element. In the sequential balancing process, any half-keys used in the balancing of the bare shaft (see 2.6.8.1) shall continue to be used until they are replaced with the final key and mating element. On rotors with single keyways, the keyway shall be filled with a fully crowned half-key. The weight of all half-keys used during final balancing of the assembled element shall be recorded on the residual unbalance worksheet (see Annex 1B). The maximum allowable residual unbalance per plane (journal) shall be calculated as follows… VENDOR: As shrinking may cause shaft runout, balancing after the addition of a new component is not applied, otherwise internal moments could be introduced in the rotor. VENDOR standard operating speed balancing procedure is applied.

PETROBRAS: From the viewpoint of machinery design, PETROBRAS is not concerned with machinery balance criteria. The methods, procedures, quality and degree of dynamic balancing chosen by the VENDOR will always be evaluated by the vibration readings taken and recorded during factory acceptance tests (FAT1) and field acceptance tests (FAT2). Regarding maintenance purposes, balance quality as adopted by the VENDOR is an item of utmost importance: (a) After completion of the final balancing, all major elements of the assembled rotor shall be match marked. (b) Balance quality data (as designed / as final) for all rotating equipment and components (both at low speed balancing and, if specified, at high speed) shall be provided in IOM manuals and other applicable documents. (c) Balance quality shall always be stated in accordance with ISO standards. VENDOR: (a) Confirmed. (b) Confirmed. (c) Confirmed. PETROBRAS: Noted.

Closed 600

2.6.8.2, 2.6.8.6

2.6.8.6. A rotor that is to be operating-speed balanced shall, when specified, first receive a sequential low speed balance as specified in 2.6.8.2. VENDOR: Exception: Incremental rotor balancing is not performed on rotors that are high speed balanced.

PETROBRAS: Noted.

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2.6.8.3

When specified, completely assembled rotating elements shall be subject to operating-speed (at speed) balancing in lieu of a sequential low speed balancing (see 2.6.8.2). When the vendor’s standard balance method is by operating-speed balancing in lieu of a sequential low speed balancing and operating speed balancing is not specified, it may be used with the purchaser’s approval. The operatingspeed balance shall be in accordance with 2.6.8.4. VENDOR: The completely assembled rotor will be operating speed (at speed) balanced.


Closed 400

2.6.8.3

When specified, completely assembled rotating elements shall be subject to operating-speed (at speed) balancing in lieu of a sequential low speed balancing (see 2.6.8.2). When the vendor’s standard balance method is by operating-speed balancing in lieu of a sequential low speed balancing and operating speed balancing is not specified, it may be used with the purchaser’s approval. The operatingspeed balance shall be in accordance with 2.6.8.4. VENDOR: Operating speed balancing is VENDOR standard method.

PETROBRAS: It is PETROBRAS understanding that VENDOR is stating that the "at speed", balancing method is VENDOR standard, as per API Std 617, paragraph 2.6.8.3. VENDOR: Confirmed. PETROBRAS: Noted.

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2.6.8.5

Unless otherwise specified, the vibration acceptance criteria for operating-speed balancing, with maximum pedestal stiffness at all speeds, measured on the bearing cap shall be as follows… VENDOR: Exception: VENDOR does not believe that the values specified are correct since the actual transmitted force depends on both the pedestal stiffness and the measured velocity. VENDOR will use the tolerances suggested in the Second Edition of API 684, "Tutorial on the API Standard Paragraphs Covering Rotor Dynamics and Balancing", Section 5.4.5.4 "Balancing Tolerance".

PETROBRAS: From the viewpoint of machinery design, PETROBRAS is not concerned with machinery balance criteria. The methods, procedures, quality and degree of dynamic balancing chosen by the VENDOR will always be evaluated by the vibration readings taken and recorded during factory acceptance tests (FAT1) and field acceptance tests (FAT2). Regarding maintenance purposes, balance quality as adopted by the VENDOR is an item of utmost importance: (a) After completion of the final balancing, all major elements of the assembled rotor shall be match marked. (b) Balance quality data (as designed / as final) for all rotating equipment and components (both at low speed balancing and, if specified, at high speed) shall be provided in IOM manuals and other applicable documents. (c) Balance quality shall always be stated in accordance with applicable ISO standards. VENDOR: Note that the comment from PETROBRAS does not seem to reject our exception. In response to added items: (a) VENDOR does not match mark the components of the compressor rotor due to the fact that once the rotor is balanced, it is not disassembled. If it is disassembled for any reason it could be match marked then, but the rotor would need to be rebalanced anyway once it is reassembled. If PETROBRAS will not accept this reasoning, we could comply with cost and delivery impact. (b) This information will be supplied in the Manufacturer's Data Books as a standard. (c) VENDOR balances to API 684 standards, which in all cases is more stringent than the ISO standards being referenced. PETROBRAS: Noted.

Closed 800

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2.6.8.7

For a rotor that has been low speed sequentially balanced (see 2.6.8.2), and when specified for rotors that are high-speed balanced (see 2.6.8.3), a low speed residual unbalance check shall be performed in a low speed balance machine and recorded in accordance with the residual unbalance worksheet (see Annex 1B). Note: This is done to provide a reference of residual unbalance and phase for future use in a low speed balance machine. VENDOR: Residual unbalance check of the balancing machine shown in Appendix-1B will not be performed. The check will be carried out with the correcting rotor per ISO 2953 modified.

PETROBRAS: From the viewpoint of machinery design, PETROBRAS is not concerned with machinery balance criteria. The methods, procedures, quality and degree of dynamic balancing chosen by the VENDOR will always be evaluated by the vibration readings taken and recorded during factory acceptance tests (FAT1) and field acceptance tests (FAT2). VENDOR: Noted, residual unbalance check of the balancing machine is carried out with the correcting rotor per ISO 2953 modified as vendor standard. PETROBRAS: Noted. Regarding maintenance purposes, balance quality as adopted by the VENDOR is an item of utmost importance: (a) After completion of the final balancing, all major elements of the assembled rotor shall be match marked. (b) Balance quality data (as designed / as final) for all rotating equipment and components (both at low speed balancing and, if specified, at high speed) shall be provided in IOM manuals and other applicable documents. (c) Balance quality shall always be stated in accordance with applicable ISO standards. Refer PETROBRAS answer to same question above (VENDOR #800).

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2.6.8.7

For a rotor that has been low speed sequentially balanced (see 2.6.8.2), and when specified for rotors that are high-speed balanced (see 2.6.8.3), a low speed residual unbalance check shall be performed in a low speed balance machine and recorded in accordance with the residual unbalance worksheet (see Annex 1B). Note: This is done to provide a reference of residual unbalance and phase for future use in a low speed balance machine. VENDOR: Residual unbalance check will be carried out, when specified, and with respect to ISO 1940 G2.5.

PETROBRAS: From the viewpoint of machinery design, PETROBRAS is not concerned with machinery balance criteria. The methods, procedures, quality and degree of dynamic balancing chosen by the VENDOR will always be evaluated by the vibration readings taken and recorded during factory acceptance tests (FAT1) and field acceptance tests (FAT2). VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

2.6.8.7

For a rotor that has been low speed sequentially balanced (see 2.6.8.2), and when specified for rotors that are high-speed balanced (see 2.6.8.3), a low speed residual unbalance check shall be performed in a low speed balance machine and recorded in accordance with the residual unbalance worksheet (see Annex 1B). Note: This is done to provide a reference of residual unbalance and phase for future use in a low speed balance machine. VENDOR: Clarification: VENDOR will conduct a residual unbalance check of all rotors at the conclusion of required balancing, testing, and factory operation. Rotors that will ship in their casing following test will not be removed for residual check.

PETROBRAS: From the viewpoint of machinery design, PETROBRAS is not concerned with machinery balance criteria. The methods, procedures, quality and degree of dynamic balancing chosen by the VENDOR will always be evaluated by the vibration readings taken and recorded during factory acceptance tests (FAT1) and field acceptance tests (FAT2). However, regardless of methods and procedures, residual unbalance checks shall be performed for all rotors, whenever specified. VENDOR: VENDOR to comply. PETROBRAS: Noted.

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2.6.8.7

For a rotor that has been low speed sequentially balanced (see 2.6.8.2), and when specified for rotors that are high-speed balanced (see 2.6.8.3), a low speed residual unbalance check shall be performed in a low speed balance machine and recorded in accordance with the residual unbalance worksheet (see Annex 1B). Note: This is done to provide a reference of residual unbalance and phase for future use in a low speed balance machine. VENDOR: This test is not performed. In case of High speed balancing, the low speed residual unbalance check is performed in the HSB machine which is capable of carrying out such a check. This capability is certified by HSB machine manufacturer every six months, and therefore the residual unbalance worksheet is not needed.

PETROBRAS: From the viewpoint of machinery design, PETROBRAS is not concerned with machinery balance criteria. The methods, procedures, quality and degree of dynamic balancing chosen by the VENDOR will always be evaluated by the vibration readings taken and recorded during factory acceptance tests (FAT1) and field acceptance tests (FAT2). However, regardless of methods and procedures, residual unbalance checks shall be performed for all rotors, whenever specified. VENDOR has not replied. Subject closed.

Closed 900

2.6.8.8

During the mechanical running test of the machine, assembled with the balanced rotor, operating at its maximum continuous speed or at any other speed within the specified operating speed range, the peak-to-peak amplitude of unfiltered vibration in any plane, measured on the shaft adjacent and relative to each radial bearing, shall not exceed the following value or 25 µm (1 mil), whichever is less… VENDOR: At the trip speed of driver, the vibration shall not exceed 150% of the max. allowable value (calculated in accordance with API) or a measured value plus 13 micrometers… At any speed greater than the maximum continuous speed, upto and including the trip speed of the driver, the vibration shall not exceed 12.7 micro, meters plus the maximum value recorded at the maximum continuous speed.

PETROBRAS: Not acceptable. It is PETROBRAS understanding that at any speed greater than the maximum continuous speed, up to and including the trip speed of the driver, the vibration level shall not exceed half of the value calculated by equations 1.2-10a/b (API Std 617, par. 2.6.8.8) or 12.7 µm (0.5 mil) above the maximum value recorded at the maximum continuous speed, whichever is less. VENDOR: Agreed to PETROBRAS’ comment. PETROBRAS: Noted.

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2.6.8.8

During the mechanical running test of the machine, assembled with the balanced rotor, operating at its maximum continuous speed or at any other speed within the specified operating speed range, the peak-to-peak amplitude of unfiltered vibration in any plane, measured on the shaft adjacent and relative to each radial bearing, shall not exceed the following value or 25 µm (1 mil), whichever is less… VENDOR: Process: This limitation shall not be applicable for compressors with magnetic bearings. The test procedure for compressors with magnetic bearings has to be mutually agreed. Transport: Will not exceed the value of the equation or 50 µm, whichever is less. This limitation shall not be applicable for compressors with magnetic bearings. The test procedure for compressors with magnetic bearings has to be mutually agreed.

PETROBRAS: Basically not acceptable. It is PETROBRAS understanding that acceptance criteria should be the same regardless of bearing type. If the procedure is different than API Std 617 then the VENDOR shall submit it to PETROBRAS for review and approval during bid stage. Nevertheless, magnetic fields generating log decrements less than API Std 617 acceptable limits should be avoided. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

2.6.8.8

During the mechanical running test of the machine, assembled with the balanced rotor, operating at its maximum continuous speed or at any other speed within the specified operating speed range, the peak-to-peak amplitude of unfiltered vibration in any plane, measured on the shaft adjacent and relative to each radial bearing, shall not exceed the following value or 25 µm (1 mil), whichever is less… VENDOR: The maximum allowable value of amplitude will be determined by the specified equations only, without limitation to 25 µm (1 mil).

PETROBRAS: Not acceptable. VENDOR to follow API requirements. Besides that, it is PETROBRAS understanding that at any speed greater than the maximum continuous speed, up to and including the trip speed of the driver, the vibration level shall not exceed half of the value calculated by equations 1.2-10a/b (API Std 617, par. 2.6.8.8) or 12.7 µm (0.5 mil) above the maximum value recorded at the maximum continuous speed, whichever is less. VENDOR #300: Agreed with PETROBRAS. PETROBRAS: VENDOR #700 has not replied. Subject closed.

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2.6.8.8

During the mechanical running test of the machine, assembled with the balanced rotor, operating at its maximum continuous speed or at any other speed within the specified operating speed range, the peak-to-peak amplitude of unfiltered vibration in any plane, measured on the shaft adjacent and relative to each radial bearing, shall not exceed the following value or 25 µm (1 mil), whichever is less… VENDOR: Exception: VENDOR considers 1.0 mil as unduly restrictive for expanders, axial compressors and overhung single stage compressors. For these machines, VENDOR will guarantee a vibration level of 1.0 mil plus one-half of the amount above 1.0 mil from Equation (1.2-10b) excluding runout. The allowable vibration at any speed above maximum continuous speed (N), up to and including trip speed, will not exceed 1.5 times the allowable vibration level at maximum continuous speed excluding runout.

PETROBRAS: VENDOR's reply is partially out of scope of this PETROBRAS document (expanders and axial compressors). Regarding applicability for overhung centrifugal compressors, the reply is not acceptable. It is PETROBRAS understanding that at any speed greater than the maximum continuous speed, up to and including the trip speed of the driver, the vibration level shall not exceed half of the value calculated by equations 1.2-10a/b (API Std 617, par. 2.6.8.8) or 12.7 µm (0.5 mil) above the maximum value recorded at the maximum continuous speed, whichever is less. VENDOR #300: Agreed with PETROBRAS. VENDOR #800: VENDOR to comply. PETROBRAS: Noted.

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2.6.8.8

During the mechanical running test of the machine, assembled with the balanced rotor, operating at its maximum continuous speed or at any other speed within the specified operating speed range, the peak-to-peak amplitude of unfiltered vibration in any plane, measured on the shaft adjacent and relative to each radial bearing, shall not exceed the following value or 25 µm (1 mil), whichever is less… VENDOR: Exception: For the compressor(s) quoted, the guaranteed vibration level at maximum continuous speed is 1.0 mil.

PETROBRAS: This is a specific deviation for a quotation. VENDOR to provide a generic statement. Not acceptable. VENDOR to follow API requirements. Besides that, it is PETROBRAS understanding that at any speed greater than the maximum continuous speed, up to and including the trip speed of the driver, the vibration level shall not exceed half of the value calculated by equations 1.2-10a/b (API Std 617, par. 2.6.8.8) or 12.7 µm (0.5 mil) above the maximum value recorded at the maximum continuous speed, whichever is less. VENDOR #300: Agreed with PETROBRAS. VENDOR #800: VENDOR to follow API requirement. PETROBRAS: Noted.

Closed 800

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2.6.8.8

During the mechanical running test of the machine, assembled with the balanced rotor, operating at its maximum continuous speed or at any other speed within the specified operating speed range, the peak-to-peak amplitude of unfiltered vibration in any plane, measured on the shaft adjacent and relative to each radial bearing, shall not exceed the following value or 25 µm (1 mil), whichever is less… VENDOR: Exception: The allowable vibration at any speed above maximum continuous speed (N), up to and including trip speed, will not exceed 1 mil (excluding runout) or 0.5 mil above the maximum value recorded at maximum continuous speed (excluding runout), whichever is greater.

PETROBRAS: Not acceptable. It is PETROBRAS understanding that at any speed greater than the maximum continuous speed, up to and including the trip speed of the driver, the vibration level shall not exceed half of the value calculated by equations 1.2-10a/b (API Std 617, par. 2.6.8.8) or 12.7 µm (0.5 mil) above the maximum value recorded at the maximum continuous speed, whichever is less. VENDOR #800: VENDOR comment to follow. PETROBRAS: No VENDOR #800 reply has been received. Subject closed. VENDOR #300: Agreed with PETROBRAS. PETROBRAS: Noted.

Closed 800

NI-2626, 6.2.3.6.1

Modification (2.6.8.8 of API Std 617). Change the last sentence by: At any speed greater than the maximum continuous speed, up to and including the trip speed of the driver, the vibration level shall not exceed the following value or 12.7 µm (0,5 mil) above the maximum value recorded at the maximum continuous speed, whichever is less… VENDOR: The Petrobras-Spec. rduces the allowable lateral relative shaft vibration during the MRT on 50% of the reqirement as specified in API617. The specified vibration limit cannot be achieved for all rotors. Significant additional efforts are needed afterwards in order to try to achieve the specified vibration limit, although there do not exist a technical need for that. Of course, the additional costs For possible additional efforts have to be considered.

PETROBRAS: Wrong deviation. Up to MCS, the acceptable limits are those of API 617. At any speed greater than the maximum continuous speed, up to and including the trip speed of the driver, the vibration level shall not exceed HALF of the value calculated by equations 1.2-10a/b (API Std 617, par. 2.6.8.8) or 12.7 µm (0.5 mil) above the maximum value recorded at the maximum continuous speed, whichever is less. VENDOR: Accepted. PETROBRAS: Noted.

Closed 600

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2.6.8.9

Electrical and mechanical runout shall be determined by rotating the rotor through the full 360 degrees supported in V blocks at the journal centers while continuously recording the combined runout with a non-contacting vibration probe and measuring the mechanical runout with a dial indicator at the centerline of each probe location and one probe-tip diameter to either side. Note: The rotor runout determined above generally may not be reproduced when the rotor is installed in a machine with hydrodynamic bearings. This is due to pad orientation on tilt pad bearings and effect of lubrication in all journal bearings. The rotor will assume a unique position in the bearings based on the slow roll speed and rotor weight. VENDOR: Runout shall be measured on lathe or V-block.

PETROBRAS: Lathe is not acceptable. VENDOR to follow API Std 617 requirements. VENDOR: VENDOR's comments is modified as follows, runout will be measured on V-blocked on lathe. PETROBRAS: Noted.

Closed 300

2.6.8.9

Electrical and mechanical runout shall be determined by rotating the rotor through the full 360 degrees supported in V blocks at the journal centers while continuously recording the combined runout with a non-contacting vibration probe and measuring the mechanical runout with a dial indicator at the centerline of each probe location and one probe-tip diameter to either side. Note: The rotor runout determined above generally may not be reproduced when the rotor is installed in a machine with hydrodynamic bearings. This is due to pad orientation on tilt pad bearings and effect of lubrication in all journal bearings. The rotor will assume a unique position in the bearings based on the slow roll speed and rotor weight. VENDOR: ... recording the combined runout with a non-contacting vibration probe and measuring the mechanical runout with a dial indicator at the centerline of each probe location.

PETROBRAS: Not acceptable. VENDOR to fully comply with this API Std 617 requirement. VENDOR: Confirmed. PETROBRAS: Noted.

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2.6.8.9

Electrical and mechanical runout shall be determined by rotating the rotor through the full 360 degrees supported in V blocks at the journal centers while continuously recording the combined runout with a non-contacting vibration probe and measuring the mechanical runout with a dial indicator at the centerline of each probe location and one probe-tip diameter to either side. Note: The rotor runout determined above generally may not be reproduced when the rotor is installed in a machine with hydrodynamic bearings. This is due to pad orientation on tilt pad bearings and effect of lubrication in all journal bearings. The rotor will assume a unique position in the bearings based on the slow roll speed and rotor weight. VENDOR: Total runout will be determined and recorded by rolling the rotor in a lathe after final machining is finished. This is because the shaft might be damaged if it is set in a V block and rotated.

PETROBRAS: Lathe is not acceptable. VENDOR to take all necessary countermeasures to avoid damage to the rotor when using V blocks for runout measurements. VENDOR #500: Confirmed, please refer to the attachment. [Annex 500-01, for PETROBRAS’ eyes only.] PETROBRAS: Attachment noted. Procedure accepted. VENDOR #300: Not enough information. PETROBRAS: VENDOR #300’s comment disregarded. Subject closed.

Closed 500

2.6.8.9

Electrical and mechanical runout shall be determined by rotating the rotor through the full 360 degrees supported in V blocks at the journal centers while continuously recording the combined runout with a non-contacting vibration probe and measuring the mechanical runout with a dial indicator at the centerline of each probe location and one probe-tip diameter to either side. Note: The rotor runout determined above generally may not be reproduced when the rotor is installed in a machine with hydrodynamic bearings. This is due to pad orientation on tilt pad bearings and effect of lubrication in all journal bearings. The rotor will assume a unique position in the bearings based on the slow roll speed and rotor weight. VENDOR: [1] Runout will be determined in the high speed balancing machine. [2] We don’t use V-blocks because of the inherent risk of damaging the rotor. Runout will be determined by rotating the rotor on a turning lathe. [3] V-blocks are not used due to the inherent risk of damaging the rotor. [4] The runout values will be certificated by means of measuring at low speed in the high speed balancing machine in accordance with the VENDOR balancing procedure.

PETROBRAS: [1] Only those balancing machines which do not impose downward loadings on the rotor journals are acceptable. [2] Lathe is not acceptable. [3] VENDOR to take all necessary countermeasures to avoid damage to the rotor when using V blocks for runout measurements. [4] Noted. VENDOR: Accepted. PETROBRAS: Noted.

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2.6.8.9

Electrical and mechanical runout shall be determined by rotating the rotor through the full 360 degrees supported in V blocks at the journal centers while continuously recording the combined runout with a non-contacting vibration probe and measuring the mechanical runout with a dial indicator at the centerline of each probe location and one probe-tip diameter to either side. Note: The rotor runout determined above generally may not be reproduced when the rotor is installed in a machine with hydrodynamic bearings. This is due to pad orientation on tilt pad bearings and effect of lubrication in all journal bearings. The rotor will assume a unique position in the bearings based on the slow roll speed and rotor weight. VENDOR: The combined run out (as measured by non-contact probe on its relevant track) will be measured supporting the rotor on bronze rollers in order to avoid shaft journal damages generated by the sliding on V block pads. The mechanical run out (as revealed by contact probe) is not measured on the probe track to avoid any risk of scratches on the burnished surface, however the combined run out measured by the inductive probe is already the sum of the electrical and mechanical components.

PETROBRAS: VENDOR to take all necessary countermeasures to avoid damage to the rotor when using V blocks for runout measurements. VENDOR has not replied. Subject closed.

Closed 900

2.6.8.11

If the vendor can demonstrate that electrical or mechanical runout is present, a maximum of 25% of the test level calculated from Equation 1.2-8 or 6.5 mm (0.25 mil), whichever is greater, may be vectorially subtracted from the vibration signal measured during the factory test. Where shaft treatment such as metalized aluminum bands have been applied to reduce electrical runout, surface variations (noise) may cause a high frequency noise component which does not have an applicable vector. The nature of the noise is always additive. In this case, the noise shall be mathematically subtracted. VENDOR: [1] Equation referenced in this paragraph of the API is considered to read “1.2-10”, not “1.2-8”. [2] Measured runout up to 0.5 mil may be vectorially subtracted from the vibration signal measured during the factory test.

PETROBRAS: [1] Correct. [2] Not acceptable. VENDOR #700: [1] Correct. [2] VENDOR comment to follow. PETROBRAS: No VENDOR reply has been received. Subject closed. VENDOR #300: Agreed to PETROBRAS. PETROBRAS: Noted.

Closed 700

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2.7.3.1

For gear couplings, the external thrust force shall be calculated from Equations 1.2-11a or 1.2-11b… VENDOR: For the calculation of tha axial thrust transmitted by a "gear type" coupling the actual coupling dimensions will be considered. Based on VENDOR's experience a friction factor f = 0.15 is assumed.

PETROBRAS: Not acceptable. VENDOR #300: No comment because we are not using gear type coupling. PETROBRAS: VENDOR #300’s comment disregarded. VENDOR #900 has not replied. Subject closed.

Closed 900

2.7.3.2

Thrust forces for flexible-element couplings shall be calculated on the basis of the maximum allowable deflection permitted by the coupling manufacturer. VENDOR: VENDOR calculates the coupling thrust with the maximum calculated deflection times 1.25 but not less than 2 mm.


Closed 400

2.7.4.1

Bearing housings shall be equipped with replaceable labyrinth-type end seals and deflectors where the shaft passes through the housing. Lip-type seals shall not be used. The seals and deflectors shall be made of spark-resistant materials. Seals and deflectors shall be designed to retain oil in the housing and prevent entry of foreign material into the housing. VENDOR: For applications with dry gas seal a separation seal (3 segmented carbon seals with buffer gas) are used to protect the dry gas seal. If the coupling guard is oil-tight, it is not essential to have an additional seal between bearing and coupling guard because the main oil outlet is in the bearing housing and not in the coupling guard. However, in the coupling guards are drain connections as well.


Closed 400

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2.7.4.1

Bearing housings shall be equipped with replaceable labyrinth-type end seals and deflectors where the shaft passes through the housing. Lip-type seals shall not be used. The seals and deflectors shall be made of spark-resistant materials. Seals and deflectors shall be designed to retain oil in the housing and prevent entry of foreign material into the housing. VENDOR: Oil tight coupling guards are provided as a standard, in which case minor leakages are acceptable. Oil tight coupling guards are provided as a standard, in which case minor leakages are acceptable. This leakages flows back to the oil tank.

PETROBRAS: Not acceptable. VENDOR to fully comply with this API Std 617 requirement. VENDOR: Confirmed. Comment will be withdrawn. PETROBRAS: Noted.

Closed 600

2.7.4.1

Bearing housings shall be equipped with replaceable labyrinth-type end seals and deflectors where the shaft passes through the housing. Lip-type seals shall not be used. The seals and deflectors shall be made of spark-resistant materials. Seals and deflectors shall be designed to retain oil in the housing and prevent entry of foreign material into the housing. VENDOR: Clarification: VENDOR provides a replaceable labyrinth type bearing housing end seal with a provision for a buffer gas. Limited leakage of oil may occur into the closed coupling guard.

PETROBRAS: Not acceptable. VENDOR to fully comply with this API Std 617 requirement. VENDOR: VENDOR to comply. PETROBRAS: Noted.

Closed 800

2.7.4.3

Oil connections on bearing housings shall be in accordance with 2.3.2.3. VENDOR: For VENDOR bearing housings the flanges of the oil connections conform to ISO 7005-1 or 7005-2 where applicable. However, in case of limited space on the bearing housing SAE connections will be used.


Closed 600

2.7.4.3

Oil connections on bearing housings shall be in accordance with 2.3.2.3. VENDOR: Exception: Oil connections on bearing housings are machined flats with capscrews and SAE flanges. Since the header piping is by VENDOR, the flanges for customer connections will conform to ISO 7005-1 or 7005-2.

PETROBRAS: Noted. Closed 800 PRELIM

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2.7.4.6

When specified, provisions for locally disconnecting bearing temperature sensors’ wiring within the bearing housing shall be provided. VENDOR: Unless specifically agreed in our offer, disconnecting RTDs at bearing housing may not be used.


Closed 600

2.8.3.5

The liquid-film seal (typical seals are shown in Figures 1.C-4 and 1.C-5 of Annex 1C) shall be provided with sealing rings or bushings and labyrinths. A sealing liquid shall be supplied. Liquid-film seals may be cylindrical-bushing seal as shown in Figure 1.C-4, or pumping seals as shown in Figure 1.C-5. Unless otherwise specified, an elevated tank shall be provided with the required static head to overcome system pressure losses (such as friction losses in internal passages and seal-oil piping) and maintain positive sealing pressure. The vendor shall state the height of the tank above the compressor centerline. Other means to maintain this differential pressure and positive seal may be used with the purchaser’s approval. VENDOR: When VENDOR compressors are provided with liquid-film seals with oil sealing system, an overhead seal-oil tank is not provided as a standard. Seal oil differential pressure is controlled by way of a differential pressure controller.

PETROBRAS: Not acceptable. VENDOR: VENDOR will provide dry-gas seals. PETROBRAS: Noted.

Closed 100

2.8.3.6

Seal-oil systems shall be in accordance with API Std 614, Chapters 1 and 2 (Special Purpose Oil Systems). VENDOR: When liquid-film seals are supplied, a combined lube and seal-oil system is provided. Refer to comments and exceptions to API 614, provided separately.

PETROBRAS: Not acceptable. Lube oil and seal oil systems shall be separated. This is a mandatory requirement. Exceptions will cause BIDDER's disqualification. VENDOR: VENDOR will provide dry-gas seals. PETROBRAS: Noted.

Closed 100

PRELIMIN

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2.8.4

Self-acting dry gas seal. VENDOR: Dry gas seals provided by VENDOR are tested per Annex 1D, “Testing of Gas Seals in Seal Vendor’s Shop – Normative” (refer to API 617, 7th edition, Annex 1C, “Typical Shaft End Seal Cross-Sectional Drawings – Informative, Figure 1.c-8 tandem gas seal) with the following exceptions:

PETROBRAS: Seals are tested by Seal manufacturer in accordance with seal manufacturer criteria. VENDOR to submit seal manufacturer deviations to PETROBRAS for review and approval. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

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2.8.4, 2.8.4.1

2.8.4.1. The self-acting dry gas seal may be a single, tandem, triple or double configuration depending on the application. The self-acting dry gas seal requires external seal gas but does not require any liquid for lubrication or cooling. Typical configurations are shown in Figures 1.C-6, 1.C-7, 1.C-8, and 1.C-9 of Annex 1C. Where toxic or flammable seal gases are used, an isolating seal is required to prevent uncontrolled leaks to the atmosphere or to the bearing housing. This isolating seal shall preferably be capable of acting as a backup seal should the primary seal fail during operation. The seal gas shall be filtered and shall be free of any contaminants that form residues. The seal gas source may be taken from the compressor discharge or inter-stage point. An alternate seal gas source may be used, and may be required during start-up or shutdown. The design of the gas seal support system is detailed in API Std 614. Note 1: Caution should be exercised if air is used as a purge or buffer gas to insure that explosive mixtures are not created when air is mixed with the seal outer leakage consisting of process gas. Note 2: Other variations are commonly used depending on the particular application. The seal will leak a small amount of seal gas, and may be unidirectional in operation. For testing considerations at the seal manufacturer’s shop for this type of seal, see Annex 1D. Note 3: If liquids may be formed or are present in the sealing gas, then coalescing filters and condensate traps may be required in the seal support module (see API Std 614, Chapter 4, 2.3.5 and 2.5). VENDOR: In case that significant seal gas leakage from primary seal is determined, compressor shall be tripped and inside of the casing shall be depressurized. Since uncontrolled gas leakage during depressurization period can be prevented by secondary seal, isolating seal will not be provided.

PETROBRAS: Basically not acceptable. Exceptions to be discussed, case by case, during clarification meetings before purchase order, considering service severity. VENDOR: Agreed to PETROBRAS’ comment. PETROBRAS: Noted.

Closed 300

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2.8.4.1

The self-acting dry gas seal may be a single, tandem, triple or double configuration depending on the application. The self-acting dry gas seal requires external seal gas but does not require any liquid for lubrication or cooling. Typical configurations are shown in Figures 1.C-6, 1.C-7, 1.C-8, and 1.C-9 of Annex 1C. Where toxic or flammable seal gases are used, an isolating seal is required to prevent uncontrolled leaks to the atmosphere or to the bearing housing. This isolating seal shall preferably be capable of acting as a backup seal should the primary seal fail during operation. The seal gas shall be filtered and shall be free of any contaminants that form residues. The seal gas source may be taken from the compressor discharge or inter-stage point. An alternate seal gas source may be used, and may be required during start-up or shutdown. The design of the gas seal support system is detailed in API Std 614. Note 1: Caution should be exercised if air is used as a purge or buffer gas to insure that explosive mixtures are not created when air is mixed with the seal outer leakage consisting of process gas. Note 2: Other variations are commonly used depending on the particular application. The seal will leak a small amount of seal gas, and may be unidirectional in operation. For testing considerations at the seal manufacturer’s shop for this type of seal, see Annex 1D. Note 3: If liquids may be formed or are present in the sealing gas, then coalescing filters and condensate traps may be required in the seal support module (see API Std 614, Chapter 4, 2.3.5 and 2.5). VENDOR: Cooling or heating may be required depending on the application.

PETROBRAS: Noted. Cooling and heating may also be required depending on the application. VENDOR: Noted. PETROBRAS: Noted.

Closed 600

NI-2626, 6.2.4.4

Addition (2.10 and 2.10.1 of API Std 617). Unless otherwise specified, seal-oil and lube-oil systems shall be separated. The means of preventing the interchanging of oil between the two systems shall be fully described in the vendor’s proposal. VENDOR: The use of Oil Seals is no longer state of the art and VENDOR will provide its compressors with DGS.


Closed 600

Item Section 3 – Accessories

PRELIMIN

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3.1.1

The driver shall be of the type specified, sized to meet the maximum specified operating conditions, including external gear or coupling losses, and shall be in accordance with applicable specifications. The driver(s) shall operate under the utility and site conditions specified by the inquiry. VENDOR: If the start-up conditions are not specified in the case of a motor driven compressor, the compressor shall start up after depressurized.


Closed 500

3.2

Couplings and guards. VENDOR: [1] Exceptions to the API 671 for the selected coupling will be submitted to the Purchaser for approval and/or comments. [2] The coupling between Gas Turbine and Centrifugal Compressors will be in accordance with Gas Turbine standards and subject to VENDOR approval.

PETROBRAS: [1] Deviations not sent with this PETROBRAS request will not be considered. [2] The VENDOR shall submit the proposed coupling for PETROBRAS approval in due time. VENDOR has not replied. Subject closed.

Closed 900

3.2.1

Unless otherwise specified, flexible couplings and guards between drivers and driven equipment shall be supplied by the manufacturer of the driven equipment. VENDOR: When a gas turbine or fluid coupling is applied, couplings and coupling guards, installed at the end of the gas turbine or fluid coupling, will be supplied by the gas turbine or fluid coupling manufacturer.

PETROBRAS: Noted. The compressor VENDOR is responsible for the coupling suitability to the service, including safety factor, torsional analysis, etc. VENDOR: Noted. PETROBRAS: Noted.

Closed 500

3.2.2

Couplings, coupling to shaft junctures, and coupling guards shall conform to API Std 671. The make, type, and mounting arrangement of the coupling shall be agreed upon by the purchaser and the vendor with unit responsibility of the driver and driven equipment. VENDOR: Coupling guards do not conform to API 671, "Special-Purpose Couplings for Petroleum, Chemical, and Gas Industry Services", with regard to baffles, slip-joint double O-rings, and rigidity to withstand 200 lb. (90.71 kg) of weight.

PETROBRAS: Acceptable for transportation services only. VENDOR shall guarantee coupling suitability to the service and no oil leakage. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

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3.2.4

The purchaser of the coupling shall provide or include a moment simulator, as required for the mechanical running test. VENDOR: A moment simulator is not provided.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR: VENDOR will conduct an analysis to reflect any dynamic performance difference between the coupling used for test and the project coupling. PETROBRAS: The main VENDOR shall provide or include the moment simulator for use during the MRT.

Closed 100

3.2.4

The purchaser of the coupling shall provide or include a moment simulator, as required for the mechanical running test. VENDOR: A moment simulator is not required for the mechanical test therefore not provided nor included.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR: This requirement makes only sense for driving machines such as motors or turbines which could be driven without an installed coupling hub. A compressor requires always a coupling to drive the machine. Therefore a simulator to simulate the coupling weight is not required for the compressor. PETROBRAS: The main VENDOR shall provide or include the moment simulator for use during the MRT.

Closed 400

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3.3.1.2.3

All machinery mounting surfaces on the mounting plate shall be machined flat and parallel to the axial plane(s) of the machinery mounting feet after fabrication and shall extend at least 25 mm (1 in.) beyond the outer three sides of the equipment feet. These mounting surfaces shall meet the following requirements: 1. Each mounting surface shall be machined to a finish of 6 mm (250 min.) arithmetic average roughness (Ra) or better. 2. To prevent a soft foot, when the machine is installed on the mounting plate, all mounting surfaces in the same horizontal plane shall be within 25 mm (0.001 in.). 3. Each mounting surface shall be machined within a flatness of 13 mm per 330 linear mm (0.0005 in. per linear ft) of mounting surface. 4. Different mounting planes shall be parallel to each other within 50 mm (0.002 in.). 5. Hold-down bolt holes shall be drilled perpendicular to the mounting surfaces, machined or spot faced to a diameter suitable for a fully eccentric washer next to the hole to allow for equipment alignment. The hole shall be 15 mm (1/2 in.) larger in diameter than the hold down bolt. VENDOR: Based on many years of successful installation and operating experience, Bidder standard baseplate / fabrication and machining tolerances for mounting surfaces are as follows: 1) To prevent a soft foot, when the machine is installed on the mounting plate, all mounting surfaces in the same horizontal plane shall be within .010”. 2) Each mounting surface shall be machined within a flatness of 0.1mm per 1000 linear mm, or .001” (.025 mm) in 12 linear inches (305 mm). 3) Different mounting planes shall be parallel to each other within ± .010” (.254 mm).

PETROBRAS: Not acceptable. VENDOR to follow API Std 617 requirements. VENDOR: VENDOR can meet the requirements in this paragraph provided that measurements are taken at the baseplate manufacturer's facility. PETROBRAS: Noted.

Closed 200

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3.3.1.2.3

All machinery mounting surfaces on the mounting plate shall be machined flat and parallel to the axial plane(s) of the machinery mounting feet after fabrication and shall extend at least 25 mm (1 in.) beyond the outer three sides of the equipment feet. These mounting surfaces shall meet the following requirements: 1. Each mounting surface shall be machined to a finish of 6 mm (250 min.) arithmetic average roughness (Ra) or better. 2. To prevent a soft foot, when the machine is installed on the mounting plate, all mounting surfaces in the same horizontal plane shall be within 25 mm (0.001 in.). 3. Each mounting surface shall be machined within a flatness of 13 mm per 330 linear mm (0.0005 in. per linear ft) of mounting surface. 4. Different mounting planes shall be parallel to each other within 50 mm (0.002 in.). 5. Hold-down bolt holes shall be drilled perpendicular to the mounting surfaces, machined or spot faced to a diameter suitable for a fully eccentric washer next to the hole to allow for equipment alignment. The hole shall be 15 mm (1/2 in.) larger in diameter than the hold down bolt. VENDOR: Exception: 3. Each mounting surface shall be machined within a flatness of 25.4 µm per 330 linear mm (0.001 in. per linear foot). 4. Different mounting planes shall be parallel to each other within 254 µm (0.010 in.). All: All measurements are to be non-witnessed and are to be taken while clamped to the set-up table.

PETROBRAS: [3 & 4] Not acceptable. VENDOR to follow API Std 617 requirements. [All] Noted. However PETROBRAS will take into account VENDOR's experience and successful measurements on previous jobs before deciding whether the measurements will be witnessed or not. VENDOR: Clarification: All dimensions are to be taken and recorded while the baseplate is on the machine set-up table. PETROBRAS: Noted.

Closed 800

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3.3.1.2.3

All machinery mounting surfaces on the mounting plate shall be machined flat and parallel to the axial plane(s) of the machinery mounting feet after fabrication and shall extend at least 25 mm (1 in.) beyond the outer three sides of the equipment feet. These mounting surfaces shall meet the following requirements: 1. Each mounting surface shall be machined to a finish of 6 mm (250 min.) arithmetic average roughness (Ra) or better. 2. To prevent a soft foot, when the machine is installed on the mounting plate, all mounting surfaces in the same horizontal plane shall be within 25 mm (0.001 in.). 3. Each mounting surface shall be machined within a flatness of 13 mm per 330 linear mm (0.0005 in. per linear ft) of mounting surface. 4. Different mounting planes shall be parallel to each other within 50 mm (0.002 in.). 5. Hold-down bolt holes shall be drilled perpendicular to the mounting surfaces, machined or spot faced to a diameter suitable for a fully eccentric washer next to the hole to allow for equipment alignment. The hole shall be 15 mm (1/2 in.) larger in diameter than the hold down bolt. VENDOR: Point 5: the hole shall be 12 mm larger in diameter than the hold down bolt.

PETROBRAS: Noted. Closed 900

3.3.1.2.11

Mounting plate surfaces that are to be grouted to concrete shall have 50 mm radiused (2 in. radiused) minimum outside corners (in the plan view). See Figures 1.3-1, 1.3-2, 1.3-3 and 1.3-4. VENDOR: Mounting plates are designed so as not to require grouting; thus corners are sharp. Another system than in Figures 1.3-1 to 1.3-4 is used to fasten the baseplate and align the machine set.

PETROBRAS: If grouting is specified, mounting plates shall follow API requirements. Otherwise, sharp corners are acceptable. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

PRELIMIN

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3.3.1.2.15

Unless otherwise specified, the equipment vendor shall prepare the mounting plates by commercially abrasive blasting all grout contacting surfaces in accordance with ISO 8501 Grade Sa2 (SSPC SP 6) and shall precoat these surfaces with a inorganic zinc silicate in preparation for epoxy grout. Note: Inorganic zinc silicate is compatible with epoxy grout, does not exhibit limited life after application as does most epoxy primers and is environmentally acceptable. VENDOR: As intended, a prime coat of paint will be applied to those faces that will come in contact with the grouting. The substrate preparatory treatment shall be as pre EN-ISO 12944-4=SSIPC-VIC SP10 Grade SA2,5. The prime coat of paint will be with two-component epoxy-resin zinc primer, which will also be compatible with an epoxy-based grouting.

PETROBRAS: Noted. VENDOR: Closed.

Closed 400

3.3.1.2.15

Unless otherwise specified, the equipment vendor shall prepare the mounting plates by commercially abrasive blasting all grout contacting surfaces in accordance with ISO 8501 Grade Sa2 (SSPC SP 6) and shall precoat these surfaces with a inorganic zinc silicate in preparation for epoxy grout. Note: Inorganic zinc silicate is compatible with epoxy grout, does not exhibit limited life after application as does most epoxy primers and is environmentally acceptable. VENDOR: Clarification: VENDOR will not prepare the contacting surfaces for epoxy grout unless epoxy grout is specifically called for in the project specifications.

PETROBRAS: Noted.

Closed 800

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3.3.2.1

When a baseplate is specified, the purchaser will indicate the major equipment to be mounted on it. A baseplate shall be a single fabricated steel unit, unless the purchaser and the vendor mutually agree that it may be fabricated in multiple sections. Multiple-section baseplates shall have machined and doweled mating surfaces which shall be bolted together to ensure accurate field reassembly. Note: A baseplate with a nominal length of more than 12 m (40 ft) or a nominal width of more than 4 m (12 ft) may have to be fabricated in multiple sections because of shipping restrictions. VENDOR: VENDOR provides the complete compressor set package, including driver gear (if required), and compressor, all mounted on a skid which may be single or two skids bolted together to form a single skid. The joint between the two skids (when provided) is manufactured to VENDOR’s design.

PETROBRAS: Acceptable for transportation services only, provided the VENDOR submits joint between the two skids design for PETROBRAS approval in due time. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

3.3.2.1

When a baseplate is specified, the purchaser will indicate the major equipment to be mounted on it. A baseplate shall be a single fabricated steel unit, unless the purchaser and the vendor mutually agree that it may be fabricated in multiple sections. Multiple-section baseplates shall have machined and doweled mating surfaces which shall be bolted together to ensure accurate field reassembly. Note: A baseplate with a nominal length of more than 12 m (40 ft) or a nominal width of more than 4 m (12 ft) may have to be fabricated in multiple sections because of shipping restrictions. VENDOR: Exception: VENDOR will only machine and dowel mating surfaces of multiple-section baseplates and bolt them together when specifically required by the Purchaser to do so.


3.3.2.4

When specified, nonskid decking or grating covering all walk and work areas shall be provided on the top of the baseplate. Note: If, after grouting, the purchaser plans to completely fill the baseplate with cement as a finished surface, decking or grating is not required. VENDOR: Maintenance of small items requires access to the base plate; therefore, non-skid decking is not provided.


Closed 100 PRELIMIN

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3.3.2.5

When specified, the baseplate shall be designed for mounting on structural columns and shall be sufficiently rigid without continuous grouting. The purchaser and the vendor shall mutually agree on the baseplate design. VENDOR: Continuous grouting is required on compressors with 24 inch nozzles or smaller, to withstand piping forces.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR #700: [1] Only applicable to pipeliner RF 24 compressors. Other pipeliners are not applicable. The pipeliner compressors mount directly on a plinth and not on a baseframe. [2] Comment not applicable to barrel compressors and can be withdrawn. PETROBRAS: Noted. Valid for transportation services only, for the referred flange size and non-barrel type models. VENDOR #300: Not enough information. PETROBRAS: VENDOR #300’s comment disregarded. VENDOR #700 has not replied. Subject closed.

Closed 700

3.3.2.6.1

When leveling pads or targets are provided, the pads or targets shall be accessible for field leveling with the equipment mounted and the baseplate on the foundation. The leveling pads and targets shall have protective removable covers. VENDOR: Leveling targets are clear coated for protection.

PETROBRAS: VENDOR to clarify. VENDOR #700: Instead of protective removable covers, the targets are clear coated with paint. PETROBRAS: Not acceptable. VENDOR #300: Not agreed. PETROBRAS: VENDOR #300’s comment disregarded. VENDOR #700 has not replied. Subject closed.

Closed 700

PRELIMIN

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3.3.2.8

When the baseplate is intended to be grouted onto a concrete foundation, adequate access shall be provided into each compartment so all load carrying structural members can be properly grouted. Decking or grating must be removable for access to internal structural members. VENDOR: Baseplates are designed with bottom sealing plates without access ports for grouting. Bottom sealing plates will permit utilizing grout flow for even grout distribution underneath baseplate with minimum waste, as well as obviate need for access ports.

PETROBRAS: Basically acceptable. Nevertheless VENDOR shall submit plans, instructions and acceptance criteria to purchaser related to grouting procedure during installation and commissioning phase. VENDOR #700: [1] The pipeliner compressors mount directly on a plinth and not on a baseframe. Baseplate comments are not applicable due to this. [2] OK. PETROBRAS: Noted. Valid for transportation services only. Nevertheless, VENDOR shall submit plans, instructions and acceptance criteria to purchaser related to installation procedures. VENDOR #300: Not enough information. PETROBRAS: VENDOR #300’s comment disregarded. VENDOR #700 has not replied. Subject closed.

Closed 700

3.3.2.9

When specified, the bottom of the baseplate shall have machined mounting pads. These pads shall be machined in a single plane after the baseplate is fabricated. Note: These machined mounting pads are necessary when the baseplate is mounted on sub-soleplates or structural steel members to facilitate field leveling. VENDOR: Mounting pads on the bottom of the base plate are machined before fabrication.

PETROBRAS: VENDOR to clarify. VENDOR #100: PIL 181. Package Tie Down Options: Onshore and Offshore Installation. VENDOR #300: Not enough information. PETROBRAS: PIL 181 not clarified. If it is a document with procedures, it has not been received. Subject closed.

Closed 100

PRELIMIN

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3.3.2.10

When specified, sub-sole plates shall be provided by the vendor. VENDOR: Sub-sole plates are not provided.

PETROBRAS: VENDOR to provide previous experience in PETROBRAS similar applications during the bid phase. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

3.3.2.11

Unless otherwise specified, oil reservoirs shall be separate from the baseplate. VENDOR: Unless otherwise stated in the proposal, the oil reservoir is integral with the package base plate.


Closed 100

3.3.3.1

When soleplates are specified, they shall meet the requirements of 3.3.3.1.1 through 3.3.3.1.4. VENDOR: Sole plates and sub-sole plates are not provided. Refer to comment to Paragraph 3.3.2.1.

PETROBRAS: Not acceptable. VENDOR #100: VENDOR supplies a complete baseplate with all the necessary items mounted in place of sole plate. VENDOR #300: Not enough information. PETROBRAS: VENDOR #100’s clarification acceptable for transportation services only. VENDOR #300’s comment disregarded. Subject closed.

Closed 100

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3.4

Controls and instrumentation. VENDOR: Subject to mutual agreement between vendor and purchaser.

PETROBRAS: Deviations not sent with this PETROBRAS request will not be considered. VENDOR: Instrumentation will be according to data sheet and PID given with the quotation. PETROBRAS: Not acceptable. Instrumentation shall be as specified.

Closed 600

3.4.1.4

Instrumentation and controls shall be designed and manufactured for use in the area classification (class, group, and division or zone) specified by the purchaser and shall comply with any local codes and regulations. VENDOR: Clarification: The Purchaser must provide any local codes and regulations that are extraordinary or specific to the jobsite.


3.5.1.1

Auxiliary piping supplied by the vendor shall be in accordance with Tables 1 and 2 of Chapter 1 of Std API 614. VENDOR: Piping is not in accordance with API 614. VENDOR pipe fabrication is in general accordance with ASME B31.3, under which 5% random radiographic inspection is performed and hydrostatic test pressure is maintained less than five minutes.

PETROBRAS: Not acceptable. VENDOR has not replied. Subject closed.

Closed 100

3.5.1.1

Auxiliary piping supplied by the vendor shall be in accordance with Tables 1 and 2 of Chapter 1 of Std API 614. VENDOR: API 614 applies with VENDOR exceptions.

PETROBRAS: Out of scope of this PETROBRAS document. VENDOR #600: Confirmed. Comment will be withdrawn. VENDOR #300: Not enough information. PETROBRAS: VENDOR #600’s confirmation noted. VENDOR #300’s comment disregarded. Subject closed.

Closed 600 PRELIMIN

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3.5.1.2

Auxiliary systems furnished shall be in accordance with API Std 614, Chapters 1 and 2 (Special Purpose Oil Systems), Chapters 1 and 3 (General Purpose Oil Systems) and Chapters 1 and 4 (Dry Gas Seal Module Systems), as specified in the subsequent chapters of this standard. Other systems, if furnished shall be mutually agreed upon. VENDOR: See comments to API 614 and VENDOR’s proposal for descriptions of auxiliary systems.

PETROBRAS: Out of scope of this PETROBRAS document. VENDOR #300: Not enough information. PETROBRAS: VENDOR #100 has not replied. VENDOR #300’s disregarded. Subject closed.

Closed 100

3.5.2

Instrument piping, if furnished, shall be in accordance with Chapters 1 and 2 of API Std 614. VENDOR: All on-skid instrument connections are accomplished using stainless steel tubing. Isolating valves are sized for the tube size in which they are installed. Refer to VENDOR’s engineering schematics for more information.


Closed 100

3.6

Special tools. VENDOR: Special tools are offered for purchase, depending upon customer’s need.


Closed 100

3.6.2

When special tools are provided, they shall be packaged in separate, rugged boxes and marked “Special tools for (tag/item number).” Each tool shall be stamped or tagged to indicate its intended use. VENDOR: Special tools are identified by part number. Refer to manuals for intended use.


Closed 200

Item Section 4 – Inspection, testing, and preparation for shipment

4.2.1

The vendor shall keep the following data available for examination by the purchaser or his representative upon request for at least 5 years… VENDOR: The need to furnish and maintain quality control certifications, tests and inspection records, and data to be established at time of order.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR: Noted. PETROBRAS: Noted.

Closed 100 PRELIMIN

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4.2.1.1

Pressure-containing parts shall not be painted until the specified hydrotest of the parts is completed. When a helium leak test after hydrotest but before final assembly is specified, this requirement shall also apply. VENDOR: After non-destructive testing and before hydrostatic pressure testing, one layer of primer can be applied.

PETROBRAS: Not acceptable. VENDOR: Noted. Original comment withdrawn by VENDOR. PETROBRAS: Noted.

Closed 400

4.2.1.1

Pressure-containing parts shall not be painted until the specified hydrotest of the parts is completed. When a helium leak test after hydrotest but before final assembly is specified, this requirement shall also apply. VENDOR: May be hydrotested after prime coat is applied.

PETROBRAS: Not acceptable. VENDOR: Confirmed. Comment will be withdrawn. PETROBRAS: Noted.

Closed 600

4.2.1.1

Pressure-containing parts shall not be painted until the specified hydrotest of the parts is completed. When a helium leak test after hydrotest but before final assembly is specified, this requirement shall also apply. VENDOR: Exception: Casings have primer applied prior to hydrotest, as permitted by ASME.

PETROBRAS: Not acceptable. VENDOR: To comply with requirement. PETROBRAS: Noted.

Closed 800

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4.2.2

Material inspection. VENDOR: Clarification: VENDOR procedures and acceptance criteria for rotating components are proprietary and may be reviewed only at a VENDOR facility.

PETROBRAS: Basically not acceptable, because it is a vague statement. Deviations shall be clearly stated case by case, item by item, and included in proposal. VENDOR: VENDOR is not a nondestructive testing (NDT) contractor. We are an OEM manufacturer of turbomachinery with over 100 years of experience. NDT is integral to our manufacturing process. VENDOR’s NDT procedures and processes were developed to ensure a quality product is delivered to our customers. The processes are continually reviewed and refined. All procedures are written in accordance with ASME and ASNT SNT TC1A. All NDT inspectors are Level II. VENDOR also has two Level III personnel on staff. VENDOR will determine the appropriate NDT methods and acceptance criteria for each component tested. VENDOR NDT procedures and acceptance criteria are used daily for all customers, including PETROBRAS on several recent jobs. All procedures are approved by a Level III and are available for review while on VENDOR premises. They are proprietary and not available for external distribution. PETROBRAS: PETROBRAS cannot understand VENDOR’s reply since procedures have been provided for PETROBRAS review for all previous jobs. Refer to former pre-inspection meetings with PETROBRAS.

Closed 800

4.3.1.1

Equipment shall be tested in accordance with 4.3.2 through 4.3.7. Other tests that may be specified by the purchaser are described in 4.3.8. VENDOR: For compressor casing not in stainless steel material painting is applied to protect the machine after casing fabrication and before hydro test.

PETROBRAS: Not acceptable. VENDOR #300: Agreed to PETROBRAS. PETROBRAS: VENDOR #900 has not replied. VENDOR #300’s comment noted. Subject closed.

Closed 900 PRELIMIN

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4.3.2.1

Pressure-containing parts shall be tested hydrostatically with liquid at a minimum of 1.5 times the maximum allowable working pressure but not less than 140 kPa gauge (20 psig). VENDOR: Exception: For atmospheric inlet applications for axial compressors, the inlet casing and stator housing with variable stator vanes are not considered to be pressure containing parts for hydrostatic test purposes. Only the discharge casing will be hydrostatically tested.

PETROBRAS: Noted. VENDOR #300: Not applicable to our products. PETROBRAS: VENDOR #300’s comment noted. Subject closed.

Closed 800

4.3.2.3

The chloride content of liquids used to test austenitic stainless steel materials shall not exceed 50 parts per million. To prevent deposition of chlorides on austenitic stainless steel as a result of evaporative drying, all residual liquid shall be removed from tested parts at the conclusion of the test. VENDOR: Chloride content of hydrotest liquids may be 80 PPM.

PETROBRAS: Not acceptable. VENDOR #300: Agreed to PETROBRAS. PETROBRAS: VENDOR #100 has not replied. VENDOR #300’s comment noted. Subject closed.

Closed 100

4.3.3.1

Each impeller shall be subjected to an overspeed test at not less than 115% of maximum continuous speed for a minimum duration of 1 min. Impeller dimensions identified by the manufacturer as critical (such as bore, eye seal, and outside diameter) shall be measured before and after each overspeed test. All such measurements and the test speeds shall be recorded and submitted for the purchaser’s review following the test. Any permanent deformation of the bore or other critical dimension outside drawing tolerances might be cause for rejection. VENDOR: Clarification: Rejection of impellers due to deformation will be per standard VENDOR criteria.

PETROBRAS: VENDOR shall inform PETROBRAS the acceptance criteria before impeller overspeed test. VENDOR #300: Agreed to PETROBRAS. VENDOR #800: Noted. PETROBRAS: Noted. Subject closed.

Closed 800

4.3.5

Gas seals shall be testing at seal vendor’s shop per requirements of Annex 1D. VENDOR: Clarification: Gas seal test procedures will be provided for customer approval.

PETROBRAS: Noted.

Closed 800 PRELIMIN

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4.3.6.1

During the mechanical running test, the requirements of 4.3.6.1.1 through 4.3.6.1.5 shall be met. VENDOR: VENDOR gas compressors are factory tested in accordance with VENDOR's Engineering Specification ES 1597. This specification shall apply in lieu of this paragraph.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR #300: Not enough information. PETROBRAS: VENDOR #100 has not replied. VENDOR #300’s comment disregarded. Subject closed.

Closed 100

NI-2626, 6.4.1.2

Addition (4.3.6.1.1 of API Std 617). Real Time Analyzer (FFT) must be fully available for PETROBRAS use during all tests, as specified on the data sheets: a) all vibration and phase signals to be available for connection; b) all cables to be identified; All Real-Time data (vibration, speed, phase signals etc.) to be recorded during the whole MRT and URT: — tape or disc recording to be submitted to PETROBRAS. The following data shall be available, recorded and printed (or plotted): a) all vibration and phase signals shall be recorded during the whole test; b) unfiltered & filtered vibration amplitude and phase angle X speed diagrams (bode and polar ´plots); c) orbits (if available); d) frequency spectra taken during relevant phenomena (surge, choke etc.); e) “waterfall” cascade plots for rotor startup and coastdown; f) raw data table for the whole test (instant values of all measured variables printed in columns versus elapsed test time on lines); g) slow-roll run out (and phase angle) measurements taken during test; h) transient data trend plots for the whole test (graphs with all measured variables shown in several trend lines, versus elapsed test time). VENDOR: FFT full availability for PETROBRAS use during test is possible but if any additional equipment has to be purchased, e.g. ADRE-Box, it will have a cost impact that need to be backcharged to PETROBRAS. Exact requirements TBD and mutually agreed.

PETROBRAS: ADRE is preferred, not required. Equipment similar to VENDOR's will suffice. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

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4.3.6.1.2

Synchronous vibration amplitude and phase angle versus speed for deceleration shall be plotted before and after the 4-hour run. Both the synchronous (one per revolution) and overall vibration levels shall be plotted. When specified, these data shall also be furnished in polar form. The speed range covered by these plots shall be from trip speed to 400 rpm. VENDOR: Test time at maximum continuous speed is typically 15 minutes after operating conditions have stabilized. Vibration plots on run down and during run up are plotted from maximum continuous speed to 0% speed.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. Minimum speed for the plots could be 0 RPM. VENDOR #300: Agreed to PETROBRAS. PETROBRAS: VENDOR #100 has not replied. VENDOR #300’s comment noted. Subject closed.

Closed 100

4.3.6.1.2

Synchronous vibration amplitude and phase angle versus speed for deceleration shall be plotted before and after the 4-hour run. Both the synchronous (one per revolution) and overall vibration levels shall be plotted. When specified, these data shall also be furnished in polar form. The speed range covered by these plots shall be from trip speed to 400 rpm. VENDOR: Clarification: The speed range minimum will be 400 rpm or the minimum speed allowed by the gas seal vendor, whichever is higher.

PETROBRAS: Noted.

Closed 800

4.3.6.1.4

The following seal flow data shall be taken during the compressor mechanical running test to assure that the seals are installed and operating properly… VENDOR: The contract seals are used for the factory test. The inner seal oil leakage rate is not measured when oil seals are used. This leakage rate can be measured at customer’s request for an additional cost.

PETROBRAS: Noted. VENDOR #100: Noted. VENDOR #300: During mechanical running test, conditions around DGS cartridge will be completely different from those of site. So, there is no meaning to measure those. PETROBRAS: Measurements have been performed at VENDOR #300’s test bed and witnessed by PETROBRAS for more than 15 years. Therefore comment has no meaning and has been disregarded by PETROBRAS. Subject closed.

Closed 100

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4.3.6.1.4

The following seal flow data shall be taken during the compressor mechanical running test to assure that the seals are installed and operating properly… VENDOR: [1] Dry Gas Seal Performance is demonstrated on separate tests in the workshop of the seal manufacturer. [2] During the mechanical running test, seal gas data will only be taken for operational reasons on the discretion of the test engineer.

PETROBRAS: [1] Noted. [2] Not acceptable. VENDOR to follow API requirements. Note: The guaranteed static seal leakage shall be checked during the assembled compressor gas leakage test. VENDOR #600: [1] Noted. [2] Confirmed. Useless… VENDOR #300: During mechanical running test, conditions around DGS cartridge will be completely different from those of site. So, there is no meaning to measure those. PETROBRAS: Regarding VENDOR #600’s comment no. 2: measurements are not useless. It is the only way to verify seal integrity (without disassembling) after so many hours of operation, during performance (PT type II) and mechanical running tests (MRT I, MRT II, URT I, and URT II). Regarding VENDOR #300’s comment: measurements have been performed at VENDOR #300’s test bed and witnessed by PETROBRAS for more than 15 years. Therefore comment has no meaning and has been disregarded by PETROBRAS. Subject closed.

Closed 600

4.3.6.1.4.a

For compressors with oil seals, inner oil leakage shall be measured at each seal. VENDOR: Exception: The iso-sleeve seal inner oil leakage rate will only be determined if a performance test is purchased.

PETROBRAS: Noted as a clarification, not as a deviation.

Closed 800

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4.3.6.1.4.c

For tandem dry gas seals, flow in the primary and secondary vent line from each seal shall be measured. VENDOR: Tandem dry gas seals are fully tested in a test rig at the seal manufacturer’s facility. The seals are subjected to actual speeds and pressures that will be experienced in the field. Leakage rate is recorded, and seal behavior observed. Primary vent flows will be confirmed during the API 617 static seal test.

PETROBRAS: Not acceptable. VENDOR #700: In addition to seal vendor factory tests, during the compressor mechanical test, seal gas flows are measured. VENDOR #300: During mechanical running test, conditions around DGS cartridge will be completely different from those of site. So, there is no meaning to measure those. PETROBRAS: VENDOR #700’s reply noted. Regarding VENDOR #300’s comment: measurements have been performed at VENDOR #300’s test bed and witnessed by PETROBRAS for more than 15 years. Therefore comment has no meaning and has been disregarded by PETROBRAS. Subject closed.

Closed 700

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NI-2626, 6.4.1.4

Substitution (4.3.6.1.4 of API Std 617). The following seal flow data shall be taken during the compressor mechanical running test and performance test to assure that the seals are installed and operating properly: a) for compressors with oil seals, inner oil leakage, pressure and temperature shall be measured at each seal; b) for single dry gas seals, flow, pressure and temperature in each vent line from each seal shall be measured. If a buffer gas seal is used, injection flow, pressure and temperature for each seal shall also be measured; c) for tandem dry gas seals, flow, pressure and temperature in the primary and secondary vent line from each seals hall be measured. If a buffer gas for primary and secondary seal is used, injection flow, pressure and temperature for each seal shall also be measured; d) for double dry gas seals, the pressure, temperature and total flow to each seal shall be measured; NOTE 1 Seal performance at contract conditions is normally demonstrated in separate tests by the seal manufacturer (see 2.8 for the requirements). The guaranteed static seal leakage shall be checked during the assembled compressor gas leakage test. NOTE 2 Vent flows for single or tandem seals may include buffer or separation gas, in addition to seal leakage. VENDOR: Seal flow data by skid tests can be taken but provisions need to be arranged. This has to be specified in the bid phase and confirmed latest at the time of order.

PETROBRAS: Vendor to provide flowmeters and take the proper measurements during tests, especially GLT. VENDOR #400: During skid test, flows that are measured on-site will be measured during testing. However, the job DGS-rack will not be modified in order to provide additional measurements. Primary Dry gas seal leakage flow will be measured with job equipment, if available. According API617, Chapter 1 clause 4.3.6.1.4 Note 2, this flow will include buffer gas for secondary seal (if applicable). About the Secondary Dry gas seal leakage flow, installing additional flow measurement could influence the behaviour of the secondary seal and separation seal. In rare case of a seal failure, safety of unit could be compromised (e.g. pressure build up in measuring line). Therefore we recommend not to do this measurement. During single compressor testing (off job-skid), all gas flows into the Dry gas seal will be measured. VENDOR #300: During mechanical running test, conditions around DGS cartridge will be completely different from those of site. So, there is no meaning to measure those. PETROBRAS: Regarding VENDOR #400’s comment: to verify seal integrity measurements during all tests (dynamic and static) are necessary, regardless of seal support system to be used during tests. Refer also to PETROBRAS’ comment on the par. 4.3.6.1.4 above. Regarding VENDOR #300’s comment: measurements have been performed at VENDOR #300’s test bed and witnessed by PETROBRAS for more than 15 years. Therefore comment has no meaning and has been disregarded by PETROBRAS. Subject closed.

Closed 400

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4.3.6.1.5

When specified, lube-oil and seal-oil inlet pressures and temperatures shall be varied through the range permitted in the compressor operating manual. This shall be done during the 4-hour test. This option, when specified, does not constitute a waiver of the other specified test requirements. VENDOR: Exception: When specified (ref. Chapter 1, para. 4.3.6.1.5), lube oil temperature will be varied about the nominal test temperature to simulate the field-specified acceptable variation in viscosity range.

PETROBRAS: Lube oil temperature and pressure variations are always required and specified by PETROBRAS. VENDOR #300: Agreed with VENDOR. VENDOR #800: VENDOR to comply. PETROBRAS: VENDOR #800’ reply noted. VENDOR #300’s comment disregarded. Subject closed.

Closed 800

NI-2626, 6.4.1.6

New (4.3.6.1.6). During MRT the highest bearing surface metal temperature shall not exceed 100 °C (212 °F) at maximum continuous speed. VENDOR: Max T=100°C might be too high for the gears, whereas experience shows it is not a problem for the compressors.

PETROBRAS: The metal temperature shall not be higher than 100°C. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 400

NI-2626, 6.4.1.6

New (4.3.6.1.6). During MRT the highest bearing surface metal temperature shall not exceed 100 °C (212 °F) at maximum continuous speed. VENDOR: VENDOR endorse this design criteria but in some cases this may be exceeded.

PETROBRAS: The metal temperature shall not be higher than 100ºC. VENDOR: Accepted. PETROBRAS: Noted.

Closed 600

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4.3.6.2.1

All hydrodynamic bearings shall be removed, inspected, and reassembled after the mechanical running test is completed. VENDOR: The bearings and seals are not removed after test.

PETROBRAS: Not acceptable. VENDOR: VENDOR can provide at additional cost a re-test of the unit, but we believe that shipping the unit "as tested" proves to be a good practice. PETROBRAS: Not acceptable.

Closed 100

4.3.6.2.1

All hydrodynamic bearings shall be removed, inspected, and reassembled after the mechanical running test is completed. VENDOR: On overhung style compressors, inboard bearings are not removed due to the benefits of shipping a proven mechanical assembly.

PETROBRAS: Out of scope of this PETROBRAS document. VENDOR: [1] OK [pipeline]. [2] OK, not applicable to barrel compressors.

Closed 700

4.3.6.2.2

When specified, shaft end seals shall be removed for inspection following a successful running test. Note: Removal and inspection of some seal types (such as cartridges) may require that the seal be returned to the seal manufacturer’s facility. VENDOR: It is VENDOR standard practice not to remove and inspect seals after a successful running test.

PETROBRAS: Acceptable. However, if excessive leakage or any other abnormality is detected, upon purchaser’s discretion, dry-gas seals shall be returned to seal manufacturer for complete disassembly inspection. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

4.3.6.2.2

When specified, shaft end seals shall be removed for inspection following a successful running test. Note: Removal and inspection of some seal types (such as cartridges) may require that the seal be returned to the seal manufacturer’s facility. VENDOR: Tandem dry gas seals are self-contained assemblies and are not disassembled for inspection.

PETROBRAS: Acceptable. However, if excessive leakage or any other abnormality is detected, upon purchaser’s discretion, dry-gas seals shall be returned to seal manufacturer for complete disassembly inspection. VENDOR: OK, if determined to be attributed due to cartridge issues. PETROBRAS: Noted.

Closed 700 PRELIMIN

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NI-2626, 6.4.1.7

Substitution (4.3.6.2.2 of API Std 617). Shaft end seals shall be removed for inspection following a successful running test. a) conventional seals shall be fully disassembled (strip tested); b) if required by initial visual inspection, upon purchaser’s discretion, dry-gas seals shall be returned to seal manufacturer for complete disassembly inspection. VENDOR: Removal and inspection of DGS's after successful tests doesn't pose a problem. If DGS's need to be completely dismantled, this can be done only under DGS supplier representative. Cost and time impact applies.

PETROBRAS: Agreed. Noted. Closed 400

4.3.6.2.3

If replacement or modification of bearings or seals or dismantling of the case to replace or modify other parts is required to correct mechanical or performance deficiencies, the initial test will not be acceptable, and the final shop tests shall be run after these replacements or corrections are made. A mechanical retest is not required when the compressor case must be dismantled to comply with the requirements of 4.3.6.2.2. VENDOR: Minor scuffs and scratches may occur on the bearing surfaces. Subsequent minor cosmetic repairs to bearing parts do not justify repetition of the test. If melting or smearing, overheating or distinct wear occurs in the babbitt of bearing shoes, these parts shall be replaced. The cause of the defects must be investigated, eliminated and the test run shall be repeated.


Closed 600

4.3.8.2

The compressor casing shall be tested for gas leakage with helium at the maximum allowable working pressure. The test shall be conducted with the casing submerged in water. The maximum allowable working pressure shall be maintained for a minimum of 30 min., with no bubbles permitted. As an alternative, a nonsubmerged soap-bubble test may be performed if approved by the purchaser. Note: This test is done immediately after hydrotest. VENDOR: Helium test is not performed.

PETROBRAS: Acceptable for transportation services only. VENDOR #100: VENDOR can provide at additional cost a re-test of the unit, but we believe that shipping the unit "as tested" is proven to be a good practice. VENDOR #300: VENDOR misunderstands the requirement. PETROBRAS: Not accepted. API Std 617 to be followed.

Closed 100 PRELIMIN

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4.3.8.2

The compressor casing shall be tested for gas leakage with helium at the maximum allowable working pressure. The test shall be conducted with the casing submerged in water. The maximum allowable working pressure shall be maintained for a minimum of 30 min., with no bubbles permitted. As an alternative, a nonsubmerged soap-bubble test may be performed if approved by the purchaser. Note: This test is done immediately after hydrotest. VENDOR: If Helium leak test is specified, the test will be conducted with soap bubble method under non-submerged condition.


Closed 300

4.3.8.2

The compressor casing shall be tested for gas leakage with helium at the maximum allowable working pressure. The test shall be conducted with the casing submerged in water. The maximum allowable working pressure shall be maintained for a minimum of 30 min., with no bubbles permitted. As an alternative, a nonsubmerged soap-bubble test may be performed if approved by the purchaser. Note: This test is done immediately after hydrotest. VENDOR: If a helium test is required a soap bubble test will be done.


Closed 400

4.3.8.2

The compressor casing shall be tested for gas leakage with helium at the maximum allowable working pressure. The test shall be conducted with the casing submerged in water. The maximum allowable working pressure shall be maintained for a minimum of 30 min., with no bubbles permitted. As an alternative, a nonsubmerged soap-bubble test may be performed if approved by the purchaser. Note: This test is done immediately after hydrotest. VENDOR: When a helium test is specified, a non-submerged soap-bubble test will be carried out.


Closed 500

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4.3.8.2

The compressor casing shall be tested for gas leakage with helium at the maximum allowable working pressure. The test shall be conducted with the casing submerged in water. The maximum allowable working pressure shall be maintained for a minimum of 30 min., with no bubbles permitted. As an alternative, a nonsubmerged soap-bubble test may be performed if approved by the purchaser. Note: This test is done immediately after hydrotest. VENDOR: A non submerged soap bubble test will be performed with a mixture of 80% nitrogen and 20% helium.

PETROBRAS: A non submerged soap bubble test is acceptable. However, the gas for this test shall be 100% helium, as specified. VENDOR: Helium is technically possible however VENDOR intends to simulate the mole[cular] weight as much as possible to the original process gas conditions. Therefore the before mentioned mixture shall apply for Natural Gas conditions. Only for special low molecular weights a test with pure Helium will be considered. PETROBRAS: Noted.

Closed 600

4.3.8.2

The compressor casing shall be tested for gas leakage with helium at the maximum allowable working pressure. The test shall be conducted with the casing submerged in water. The maximum allowable working pressure shall be maintained for a minimum of 30 min., with no bubbles permitted. As an alternative, a nonsubmerged soap-bubble test may be performed if approved by the purchaser. Note: This test is done immediately after hydrotest. VENDOR: Clarification: The compressor is too large for a submerged test. A non-submerged soap bubble test will be conducted.

PETROBRAS: Noted.

Closed 800

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4.3.8.2

The compressor casing shall be tested for gas leakage with helium at the maximum allowable working pressure. The test shall be conducted with the casing submerged in water. The maximum allowable working pressure shall be maintained for a minimum of 30 min., with no bubbles permitted. As an alternative, a nonsubmerged soap-bubble test may be performed if approved by the purchaser. Note: This test is done immediately after hydrotest. VENDOR: Due to capability constraints, this test shall be carried with casing submerged in water in the followings: - Single-section compressor: casing size lower or equal to 450; - Multiple-section compressor: casing size lower or equal to 400. Compressor bigger than above-cited size shall have nonsubmerged soap-bubble test.

PETROBRAS: Noted. VENDOR #300: Not agreed. PETROBRAS: VENDOR #300’s comment disregarded. Subject closed.

Closed 900

4.3.8.5

The compressor shall be dismantled, inspected, and reassembled after satisfactory completion of the mechanical running test. The purchaser will specify whether the gas test shall be performed before or after the post-test inspection. Note: The merits of post-test inspection of compressor internals should be evaluated against the benefits of shipping a unit with proven mechanical assembly and casing joint integrity. VENDOR: VENDOR does not disassemble the compressor after testing.


Closed 100

4.3.8.5

The compressor shall be dismantled, inspected, and reassembled after satisfactory completion of the mechanical running test. The purchaser will specify whether the gas test shall be performed before or after the post-test inspection. Note: The merits of post-test inspection of compressor internals should be evaluated against the benefits of shipping a unit with proven mechanical assembly and casing joint integrity. VENDOR: All bearings and shaft seals shall be removed, inspected, and reassembled after the mechanical running test has been successfully completed. Cartridge type dry gas seals shall be removed and be individually packed for delivery. (Disassembling of dry gas seal cartridge will not be done.)


Closed 300 PRELIMIN

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4.3.8.6

The details of the full-pressure/full-load/full-speed test shall be developed jointly by the purchaser and the vendor. This test may be substituted for the mechanical running test. VENDOR: During shop load test for each machine, operating at its maximum continuous speed or at any operating speed within the specific operating range, the peak to peak amplitude of unfiltered vibration in any plane, measured on the shaft and relative to each radial bearing, shall not exceed the value in equation 1 or 50 microns, whichever is less: A = 25.4 x (24000 / MCS)1/2 A = Amplitude of unfiltered vibrations in micrometers peak-to-peak. MCS = Maximum continuous speed, in revolution per minutes. At any speed greater than the maximum continuous speed up to and including the trip speed (where applicable) the vibration shall not exceed 150 percent of the maximum value recorded at the maximum continuous speed.

PETROBRAS: Not acceptable. VENDOR has not replied. Subject closed.

Closed 900

NI-2626, 6.4.1.8

Substitution (4.3.8.8 of API Std 617). Spare parts such as rotors, bearings, and seals shall be inspected and tested under same requirements of main components. Equivalent reports shall be issued as well. Spare rotors need not be performance tested, except when complete spare bundles are purchased. Complete spare bundles shall be performance tested using the same procedure as the main bundle. VENDOR: Confirmed, however with regard to any potential cost savings VENDOR suggest to do a performance test in accordance to PTC 10 for each design just once.

PETROBRAS: Not acceptable. PTC-10 test shall be performed as required. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

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NI-2626, 6.4.1.9

New (4.3.8.9 - Stability Test). The purpose of this entire new item is to provide the minimum requirements for the execution of a Factory Stability Test (FST), in order to measure the real stability margin of the machine, identifying the sister modes (forward and backward) and their respective log decrements. The log decrement shall be measured, at least, in two different operational conditions, in order to plot the measured real applied cross-coupled stiffness vs. Log decrement and the extrapolated produced curve, to the minimum log decrement at worst design conditions (see 2.6.5.9). The presentation of the results shall include a plot of applied cross-coupled stiffness vs. Log decrement, showing the measured values and the expected values for similar conditions. Equipment shall be tested in accordance with 4.3.8.9.1 through 4.3.8.9.6. VENDOR: Plotting against the cross stiffness does not make any sense, this would suggest the cross stiffness to be beneficial to the rotordynamic stability. LogDec shall be plotted against density or pressure.

PETROBRAS: It is PETROBRAS understanding that density and pressure will be the key factors to properly obtain the figures of the labyrinth force. By adding all individual figures of each labyrinth forces, equivalent cross coupling can be attained and then plotted. VENDOR #400: To be discussed during detail engineering. VENDOR #300: This topic needs discussion during detail engineering. PETROBRAS: Noted.

Closed 400

NI-2626, 6.4.1.9

New (4.3.8.9 - Stability Test). The purpose of this entire new item is to provide the minimum requirements for the execution of a Factory Stability Test (FST), in order to measure the real stability margin of the machine, identifying the sister modes (forward and backward) and their respective log decrements. The log decrement shall be measured, at least, in two different operational conditions, in order to plot the measured real applied cross-coupled stiffness vs. Log decrement and the extrapolated produced curve, to the minimum log decrement at worst design conditions (see 2.6.5.9). The presentation of the results shall include a plot of applied cross-coupled stiffness vs. Log decrement, showing the measured values and the expected values for similar conditions. Equipment shall be tested in accordance with 4.3.8.9.1 through 4.3.8.9.6. VENDOR: Confirmed, however with regard to any potential cost savings VENDOR suggest to do a stability test only for very critical machines as agreed between PB and VENDOR.

PETROBRAS: Noted. VENDOR #600: If a rotor stability test is specified, a complete unit test at full load, full speed, full pressure will be performed instead to verify sufficient damping of the rotor. VENDOR #300: This topic needs discussion during detail engineering. PETROBRAS: Regarding VENDOR #600’s comment: if a rotor stability test is specified, such test shall be performed since it is the only way to measure actual stability margins. VENDOR #300’s comment disregarded. Subject closed.

Closed 600

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NI-2626, 6.4.1.16.1

New (4.3.8.9.3.1). When an active magnetic bearing is used for the excitation, its assembly on the shaft shall not significantly change the rotor response characteristics. The manufacturer shall submit for purchaser approval the proposed device and the expected changes in the rotor response prior to the test. The equipment measured unfiltered vibration, during the mechanical running and performance tests, with the assembled device, before applying any load, shall not exceed the limits of 2.6.8.8. The manufacturer shall send a procedure informing how the AMB will be adjusted/calibrated and how the applied force will be measured. Prior to the tests, the accuracy of input force measurements shall be verified. The manufacturer shall submit the AMB calibration report for purchaser review. VENDOR: "The manufacturer shall submit the AMB calibration report for purchaser review"--> NOT APPLICABLE

PETROBRAS: Not acceptable. VENDOR: [Former comment not applicable.] Prior to the test a procedure (of the damping measurements) is sent with the max. allowable vibration level during the excitation which is the basis for the determination of the force during the test. During the test a low force is first applied in order to be well below the specified vibration limits. This force is then further increased in order to record the vibrations with the best possible accuracy without any rubbing at the seals. Prior to the test the magnetic bearing and the corresponding equipment (cables, cabinet) is inspected by the magnetic bearing supplier. The service report will be submitted. PETROBRAS: Withdrawal of previous comment has been noted and accepted. Revised comment noted, accepted. Please provide procedures in advance in order to include them in this document (for Petrobras use only) and save time with comments. Subject closed.

Closed 400

NI-2626, 6.4.1.16.4

New (4.3.8.9.3.4). The manufacturer shall present in the lateral vibration report, the expected orbits for both modes (forward and backward) at MCS, from zero to the maximum expected cross-coupling (0 %, 50 %, 100 %) for the average clearance case. The definition of excitation direction shall be based in those orbits. VENDOR: Paragraph shall not be applicable.

PETROBRAS: Not acceptable. VENDOR: VENDOR will include in the lateral analysis for 0 to max calculated seals cross coupling the calculated forward and backward eigenvectors modshapes (showing the orbits and their sense of rotation) and relevant associated logarithmic decrement, considering MCS speed and average seals clearance. PETROBRAS: Noted.

Aclosed 400

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NI-2626, 6.4.1.19.1

New (4.3.8.9.6.1 - Model Verification). If the measured value is above the predicted one, no correction in the model is necessary. The vendor shall correct the model if it fails to meet the following criteria: Any expected log decrement for the forward mode, for both cases (base stability and performance test conditions), calculated according 4.3.8.9.3.2, shall be inside the range of the measured log decrement (δm ± 0.03). VENDOR: "Any expected log decrement for the forward mode, for both cases (base stability and performance test conditions), calculated according 4.3.8.9.3.2, shall be inside the range of the measured log decrement (δm ± 0.03)." Replace "(…) performance test conditions (…)" by "(…) pressurized test conditions (…)"

PETROBRAS: VENDOR is correct. Sometimes PT is not fully pressurized. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

NI-2626, 6.4.1.19.1

New (4.3.8.9.6.1 - Model Verification). If the measured value is above the predicted one, no correction in the model is necessary. The vendor shall correct the model if it fails to meet the following criteria: Any expected log decrement for the forward mode, for both cases (base stability and performance test conditions), calculated according 4.3.8.9.3.2, shall be inside the range of the measured log decrement (δm ± 0.03). VENDOR: "...shall be inside the range of the measured log decrement (δm ± 0.03)" 1. Possible for base case (if base case can be run) 2. Not possible for full load since there is a high inaccuracy measurement and calculation at high damping (for d> 0.50)

PETROBRAS: 1. Noted. Base case should always be possible to be run. 2. If expected log dec is greater than 0.2 and even so test has been still required by PETROBRAS, then the acceptance criteria shall be mutually agreed upon by PETROBRAS and VENDOR, after the order, with no extra costs to PETROBRAS. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

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NI-2626, 6.4.1.19.2

New (4.3.8.9.6.2 - Test Acceptance). The highest difference between the expected value and the measured log decrement (δm) for each case (base stability and pressurized test conditions) will be the correction factor (δcf) to be applied to the calculated log decrement (δf) for the worst condition (see 2.6.5.9) at maximum continuous speed and design pressure (see figure below). The equipment acceptance criteria shall be that the final corrected log decrement (δ’f), at worst condition (see 2.6.5.9), is greater than 0.1… VENDOR: According to comments for 6.4.1.9, the plot shall be against density or pressure. Determination of correction factors following the same philosophy.

PETROBRAS: See reply to 6.4.1.9. VENDOR #400: Noted. VENDOR #300: This topic needs discussion during detail engineering. PETROBRAS: Both comments noted. Of course, discussions after order (during detail design engineering) are necessary, but scope of supply shall be already adjusted and agreed. Subject closed.

Closed 400

NI-2626, 6.4.1.19.2

New (4.3.8.9.6.2 - Test Acceptance). The highest difference between the expected value and the measured log decrement (δm) for each case (base stability and pressurized test conditions) will be the correction factor (δcf) to be applied to the calculated log decrement (δf) for the worst condition (see 2.6.5.9) at maximum continuous speed and design pressure (see figure below). The equipment acceptance criteria shall be that the final corrected log decrement (δ’f), at worst condition (see 2.6.5.9), is greater than 0.1… VENDOR: The coefficient Qf is calculated according VENDOR's equation (and not according Wachel's equation which is inaccurate).

PETROBRAS: Accuracy to be demonstrated. Otherwise, API 617 equations shall be followed. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

PRELIMIN

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4.4, 4.4.1, 4.4.3.2

4.4. Preparation for shipment. 4.4.1. Equipment shall be suitably prepared for the type of shipment specified, including blocking of the rotor when necessary. Blocked rotors shall be identified by means of corrosion-resistant tags attached with stainless steel wire. The preparation shall make the equipment suitable for 6 months of outdoor storage from the time of shipment, with no disassembly required before operation, except for inspection of bearings and seals. If storage for a longer period is contemplated, the purchaser will consult with the vendor regarding the recommended procedures to be followed. 4.4.3.2. Exterior machined surfaces shall be coated with a suitable rust preventive. VENDOR: Painting to the exterior surface of compressor casing may be performed before mechanical running test (after hydrostatic test of the casing). This will save the time from mechanical running test completion to the cargo ready.

PETROBRAS: Wrong paragraph number. VENDOR: Agreed to PETROBRAS' comment. PETROBRAS: Noted.

Closed 300

4.4.3.1

Exterior surfaces, except for stainless steel or machined surfaces, shall be given at least one coat of the manufacturer’s standard finish paint. The paint shall not contain lead or chromates. VENDOR: Painting to the exterior surface of compressor casing may be performed before mechanical running test (after hydrostatic test of the casing). This will save the time from mechanical running test completion to the cargo ready.


Closed 300

PRELIMIN

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NI-2626, 6.4.2.4

Addition (4.4.3.1 of API Std 617). After testing and final inspections, spare rotors shall be wrapped, packed in steel containers, sealed and pressurized / purged with Nitrogen gas. Should any rust preventive be required at packing and shipment stage, volatile products shall be applied. Containers shall be provided with N2 pressure indication, vent, drain and refill connections and shall be equipped with a pressure safety valve and a Nitrogen cylinder and pressure control valve, to ensure adequate Nitrogen pressure inside the storage container. Container design shall be suitable for both horizontal and vertical storage. Neither TFE nor PTFE shall be used between the rotor and the cradle at the support areas. VENDOR: After testing and final inspections, spare rotors shall be wrapped, packed in steel containers, sealed and purged with Nitrogen gas.

PETROBRAS: Noted. VENDOR #500: Noted. VENDOR #300: Wrapping is not necessary. PETROBRAS: Wrapping is required. Depressurized containers are only acceptable if required for sea shipping. For air / land shipping and storage, pressurization / repressurization will always be required. Subject closed.

Closed 500

4.4.3.3

The interior of the equipment shall be clean and free from scale, welding spatter, and foreign objects. The selection and application of preservatives or rust preventives shall be mutually agreed upon by the purchaser and the vendor. VENDOR: VENDOR standard procedure applies.

PETROBRAS: PETROBRAS base requirements follow API specifications. Other procedures shall be submitted to PETROBRAS for approval during bid stage. VENDOR: Confirmed. PETROBRAS: Noted.

Closed. 600

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4.4.3.5

Flanged openings shall be provided with metal closures at least 5 mm (3/16 in.) thick, with elastomeric gaskets and at least four full-diameter bolts. For studded openings, all nuts needed for the intended service shall be used to secure closures. VENDOR: Suction and discharge ports are protected using wood covers with rubber gaskets.

PETROBRAS: Bolted wooden closures may be used for opening protection against impacts during shipment, but flanged openings shall be provided with metal closures - e.g., paddle blinds - about 5 mm (3/16 in) thick, properly sealed in order to prevent entrance of foreign materials. As those closures will only be removed at the stage of mounting of definitive gaskets or joints, they shall neither obstruct nor restrain any work related to the installation of suction, discharge and auxiliary piping. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

4.4.3.5

Flanged openings shall be provided with metal closures at least 5 mm (3/16 in.) thick, with elastomeric gaskets and at least four full-diameter bolts. For studded openings, all nuts needed for the intended service shall be used to secure closures. VENDOR: Flanged openings are provided with wooden closures.

PETROBRAS: Bolted wooden closures may be used for opening protection against impacts during shipment, but flanged openings shall be provided with metal closures - e.g., paddle blinds - about 5 mm (3/16 in) thick, properly sealed in order to prevent entrance of foreign materials. As those closures will only be removed at the stage of mounting of definitive gaskets or joints, they shall neither obstruct nor restrain any work related to the installation of suction, discharge and auxiliary piping. VENDOR #700: OK, metal closures will be provided, approx. 3/16" thickness. Full diameter bolts may not be used for flange diameters exceeding 12". VENDOR #300: Agreed with VENDOR. PETROBRAS: Noted. Subject closed.

Closed 700

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4.4.3.6

Threaded openings shall be provided with steel caps or solid-shank steel plugs. In no case shall nonmetallic (such as plastic) plugs or caps be used. VENDOR: Threaded openings may be covered or plugged with plastic caps or plugs.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR #100: Can be offered for additional cost. VENDOR #300: Agreed with PETROBRAS. PETROBRAS: Not cost addition is accepted. API requirements to be followed. Subject closed.

Closed 100

4.4.3.6

Threaded openings shall be provided with steel caps or solid-shank steel plugs. In no case shall nonmetallic (such as plastic) plugs or caps be used. VENDOR: All threaded field customer connections are provided with plastic caps or plugs.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR: OK. API spec will be followed. PETROBRAS: Noted.

Closed 700

4.4.6

One copy of the manufacturer’s standard installation instructions shall be packed and shipped with the equipment. VENDOR: Will be shipped separately.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

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4.4.6, 5.3.5.2

5.3.5.2. All information required for the proper installation of the equipment shall be compiled in a manual that must be issued no later than the time of final certified drawings. For this reason, it may be separate from the operation and maintenance instructions. This manual shall contain information on alignment and grouting procedures, (normal and maximum utility requirements), centers of mass, rigging procedures and other installation data. All drawings and data specified in 5.2.2 and 5.2.3 that are pertinent to proper installation shall be included as part of this manual. One extra manual, over and above the specified quantity, shall be included with the first equipment shipment. VENDOR: The Installation Manual, with standard instructions and separately packaged, is sent to the customer when the unit ships.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR: The installation manuals are not completed by the time certified drawings are issued. Delivery dates will be determined via mutual agreement of the SDRL documents. PETROBRAS: PETROBRAS sees no issues regarding the matter. During documents review stage, sample manuals shall be issued for comments and approval (just format and contents, not actual data). Therefore, there shall be enough time for VENDOR to prepare actual installation manuals in accordance with client´s comments to be shipped with first equipment, as per API Std. Subject closed.

Closed 700

Item Section 5 – Vendor’s data

PRELIMIN

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5

Vendor’s data. VENDOR: VENDOR’s standard drawing form and the schedule control system shall be used for prompt communication. The kinds of drawings, documents and data will be discussed at the vendor coordination meeting.

PETROBRAS: VENDOR is allowed to render documentation according to VENDOR's proprietary format, provided that: a) ALL REQUIRED information and data contents are furnished as specified; b) PETROBRAS' job logo is included (VENDOR’S DWG may be pasted onto PETROBRAS' blank drawing template or form); c) PETROBRAS' requirements on drawings and documents size & format are followed. d) Minimum contents to be submitted for review / comments / approval and submission schedule to follow list of minimum documents required for the accomplishment of contract milestones, as provided by Material Requisition. Proposal document list shall provide a table of equivalence between PETROBRAS’ list and VENDOR’s, regarding document names and contents. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 500

PRELIMIN

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5

Vendor’s data. VENDOR: Documentation provided is as per agreed documentation schedule.

PETROBRAS: VENDOR is allowed to render documentation according to VENDOR's proprietary format, provided that: a) ALL REQUIRED information and data contents are furnished as specified; b) PETROBRAS' job logo is included (VENDOR’S DWG may be pasted onto PETROBRAS' blank drawing template or form); c) PETROBRAS' requirements on drawings and documents size & format are followed. d) Minimum contents to be submitted for review / comments / approval and submission schedule to follow list of minimum documents required for the accomplishment of contract milestones, as provided by Material Requisition. Proposal document list shall provide a table of equivalence between PETROBRAS’ list and VENDOR’s, regarding document names and contents. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 500

5.2.3.L

The following data shall be included in the proposal… L. A list of machines, similar to the proposed machine(s) that have been installed and operating under conditions analogous to those specified in the inquiry. VENDOR: A comparison of the proposed compressor to other compressors owned by the purchaser is not included.

PETROBRAS: The list of compressors already supplied to PETROBRAS is not required, just preferable. Accomplishment to API requirement will suffice. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

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5.2.4

Performance curves shall be submitted for each section (between purchaser’s process nozzles) of each casing as well as an overall curve for the train. These curves shall encompass the map of operations, with any limitations indicated thereon. All curves shall be marked “PREDICTED.” VENDOR: Exception: Overall train performance curves are not provided.

PETROBRAS: Not acceptable. VENDOR #300: Not enough information. VENDOR #800: VENDOR to comply. PETROBRAS: Vendor # 300: API to be followed. Vendor # 800: Noted. Subject closed.

Closed 800

5.2.4.1

Curves for variable-speed compressors shall include the following: discharge pressure; power; polytropic head; and polytropic efficiency versus inlet capacity (from predicted surge point to 115% rated capacity) at minimum operating speed and 80%, 90%, 100%, and 105% speed, and indicating the effect of specified inlet pressures, temperatures, and molecular weights. Any specified operating points shall be noted within the envelope of the performance curve predicted. VENDOR: VENDOR curves are plotted using isentropic head instead of polytropic head.

PETROBRAS: Not acceptable. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

5.3.1.1

Contract data shall be furnished by the vendor in accordance with the agreed VDDR form (Annex B of each chapter). VENDOR: Bidder interpretation and criteria for meeting the requirements of Annex B are detailed in Bidder Standard Specification which will be included in the proposal.

PETROBRAS: VENDOR to refer to PETROBRAS' VDDR. VENDOR: Acknowledged. PETROBRAS: Noted.

Closed 200

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5.3.1.2

Each drawing shall have a title block in its lower right-hand corner with the date of certification, identification data as specified in 5.1.2, the revision number and date, and the title. Similar information shall be provided on all other documents including sub vendor items. VENDOR: Title block and identification data will only be on page one of a multipage drawing or document. BOM's, data sheets, and sub-vendor items may have a cover page with this information.


Closed 200

5.3.2.1.5

When specified, the vendor shall supply curves of balance piston line differential pressure versus thrust load. VENDOR: Balance piston line differential pressure versus thrust load curves is not provided.

PETROBRAS: Not acceptable. Curves are required when applicable. VENDOR #100: Can be offered at additional cost. VENDOR #300: Not necessary. PETROBRAS: Not accepted, curves are required when applicable, at no extra cost to PETROBRAS Subject closed.

Closed 100

5.3.2.1.6

The vendor shall supply balance piston leakage based on design clearances and twice design clearances for the rated condition. VENDOR: Balance piston leakage rates are not provided.

PETROBRAS: Not acceptable. Calculation sheets are required when applicable. VENDOR #100: Can be offered at additional cost. VENDOR #300: Not necessary. PETROBRAS: Not accepted, calculation sheets are required when applicable, at no extra cost to PETROBRAS Subject closed..

Closed 100

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5.3.4.1

The vendor shall submit complete parts lists for all equipment and accessories supplied. These lists shall include part names, manufacturers unique part numbers, materials of construction (identified by applicable international standards). Each part shall be completely identified and shown on appropriate cross-sectional, assembly-type cutaway or exploded-view isometric drawings. Interchangeable parts shall be identified as such. Parts that have been modified from standard dimensions or finish to satisfy specific performance requirements shall be uniquely identified by part number. Standard purchased items shall be identified by the original manufacturer’s name and part number. VENDOR: Manufacturer's unique part numbers for accessories are not provided.

PETROBRAS: Not acceptable. VENDOR #300: VENDOR keeps track of the revisions of the latest requirements. If provided, this can potentially create problems for the customer by ordering the wrong part number or by having parts that are not correctly calibrated to our standards. VENDOR #300: Agreed with VENDOR #100. PETROBRAS: PETROBRAS re-states comment. API Std. text is absolutely clear. What is interchangeable between jobs and what is not shall be properly identified as so. PETROBRAS sees no issues regarding compliance with such API Std. paragraph. Subject closed.

Closed 100

5.3.5.2

All information required for the proper installation of the equipment shall be compiled in a manual that must be issued no later than the time of final certified drawings. For this reason, it may be separate from the operation and maintenance instructions. This manual shall contain information on alignment and grouting procedures, (normal and maximum utility requirements), centers of mass, rigging procedures and other installation data. All drawings and data specified in 5.2.2 and 5.2.3 that are pertinent to proper installation shall be included as part of this manual. One extra manual, over and above the specified quantity, shall be included with the first equipment shipment. VENDOR: Installation manual will be available after final issue of drawings.


Closed 200

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5.3.5.2

All information required for the proper installation of the equipment shall be compiled in a manual that must be issued no later than the time of final certified drawings. For this reason, it may be separate from the operation and maintenance instructions. This manual shall contain information on alignment and grouting procedures, (normal and maximum utility requirements), centers of mass, rigging procedures and other installation data. All drawings and data specified in 5.2.2 and 5.2.3 that are pertinent to proper installation shall be included as part of this manual. One extra manual, over and above the specified quantity, shall be included with the first equipment shipment. VENDOR: [1] A separate Installation Manual is supplied. The Installation Manual covers generally valid information about mobilization and preparation of the jobsite and erection/ assembly of the machine unit. [2] Erection procedures are not submitted by VENDOR if erection is carried out or supervised by VENDOR. In these cases, all required instructions are given by VENDOR erection personnel.

PETROBRAS: [1] Complete manual to be supplied inside the crate. [2] Not acceptable. Erection/assembly written instructions are required, regardless of whether erection/assembly is carried out or supervised by VENDOR or others. VENDOR’s reply not received. VENDOR to refer to PETROBRAS' VDDR. Subject closed.

Closed 400

5.3.5.3

A manual containing all required operating and maintenance instructions shall be supplied not later than 2 weeks after all specified tests have been successfully completed. VENDOR: The Operating and Maintenance Manual (VENDOR designation: "Operating Instructions") is supplied at the same time as the VENDOR machine unit.

PETROBRAS: VENDOR to refer to PETROBRAS' VDDR. VENDOR’s reply not received. Subject closed.

Closed 400

5.3.5.4

When specified, the vendor shall provide the purchaser with a technical data manual within 30 days of completion of shop testing. See description in Annex B of each of the listed chapters for minimum requirements of this manual: a. Chapter 2, line 53. b. Chapter 3, line 57. c. Chapter 4, line 54. VENDOR: A Technical Data Manual is not supplied by VENDOR. Documents 'a' to 'f' are part of other documentation.

PETROBRAS: VENDOR to clarify. Please refer to PETROBRAS' VDDR. Paragraph number does not comprise items from 'a' to 'f'. VENDOR’s reply not received. Subject closed.

Closed 400

Item Annex 1A – Reference list of U.S., ISO and international standards (normative)

PRELIMIN

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-

Reference list of U.S., ISO, and international standards (normative). VENDOR: Separate comments to a mutually agreed set of standards will apply.

PETROBRAS: VENDOR to submit separate list. VENDOR’s reply not received. Subject closed.

Closed 600

Item Annex 1D – Testing of gas seals in seal vendor’s shop (normative)

-

Testing of gas seals in seal vendor's shop (normative). VENDOR: The seal test will be done according seal manufacturer standard.

PETROBRAS: Not acceptable. Compressor vendor and/or seal manufacturer to follow API requirements. Any deviations to be submitted for PETROBRAS review before the order. VENDOR #400: In VENDOR's point of view the seal testing requirements of API 617 doesn't make a sense in most requirements. Therefore VENDOR generated a standard test procedure to test the DGS which guarantees a check of all safety and design criteria related to the seal. VENDOR suggests to supply this procedure for purchaser’s approval. VENDOR #300: Agreed to PETROBRAS. PETROBRAS: PETROBRAS re-states comment above. PETROBRAS accepts to discuss different criteria (either VENDOR’s or SUBVENDOR’s) but only before the order. Otherwise, API to be followed. Subject closed.

Closed 400

PRELIMIN

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-

Testing of gas seals in seal vendor's shop (normative). VENDOR: Seals will be tested in line with VENDOR standard test procedure for dry gas seals.

PETROBRAS: Not acceptable. Compressor vendor and/or seal manufacturer to follow API requirements. Any deviations to be submitted for PETROBRAS review before the order. VENDOR: In general DGS test procedure will comply with API considering comments and exceptions made by the DGS manufacturer such as John Crane, Flowserve, or EagleBurgmann. PETROBRAS: PETROBRAS re-states comment above. PETROBRAS accepts to discuss different criteria (either VENDOR’s or SUBVENDOR’s) but only before the order. Otherwise, API to be followed. Subject closed.

Closed 600

3.a

3. Dynamic test procedure. a. With the seal gas at the maximum specified pressure and temperature, and the primary vent at the minimum specified back pressure, increase the speed from stand still to maximum continuous speed (MCS) and run for at least 15 min., or until the primary seal leakage reaches steady state. Record data. VENDOR: Seal temperature will be ambient. Heated tests are available at additional cost. Minimum specified backpressure is subjected to test rig capability based on actual seal leakage.

PETROBRAS: Not acceptable. PETROBRAS base requirements follow API specifications. VENDOR #300: Not Agreed. Limitation of Seal vendor’s test rig capacity will be applied. PETROBRAS: PETROBRAS re-states comment above. No additional costs will be accepted. Regarding test bed limitations, they shall be submitted to PETROBRAS for review and acceptance during bid stage. Deviations not previously advised will not be considered. Subject closed.

Closed 100

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Note (between 3.e

and 3.f)

3. Dynamic test procedure. Note: The compressor manufacturer, based on his own standards and/or the user specification, can specify the seal gas temperature as the seal manufacturer’s standard, if that has been proved acceptable, or the maximum seal gas temperature anticipated in the field. This may vary widely, and a judgement needs to be made by the purchaser of the seal as to whether the seal gas temperature in the field will be high enough that it should be simulated in the seal test. VENDOR: It is difficult to control temperature in a dead end cavity of gas seal test rig, even heated gas is supplied, due to low leakage that is only flow at the test rig. The temperature increase is by natural windage and is controlled by water jacket cooling of the test rig.

PETROBRAS: Not acceptable. VENDOR #500: Confirmed, depend on dry gas seal size. VENDOR #300: Not Agreed. Limitation of Seal vendor’s test rig capacity will be applied. PETROBRAS: PETROBRAS re-states comment above. No additional costs will be accepted. Regarding test bed limitations, they shall be submitted to PETROBRAS for review and acceptance during bid stage. Deviations not previously advised will not be considered. Subject closed.

Closed 500

3.f

3. Dynamic test procedure. f. Perform two consecutive shutdowns and restarts to maximum continuous speed as fast as possible to trip speed and then reducing the speed to maximum continuous speed. Hold the speed for 5 min. or until the leakage reaches steady state. Record a complete set of data at rest and at speed. Maintain primary seal gas pressure and secondary seal gas pressure from item e above. VENDOR: Seal gas pressures will be maintained as indicated in 3.a, not 3.e.

PETROBRAS: Not acceptable. PETROBRAS base requirements follow API specifications. VENDOR #300: Not Agreed. Limitation of Seal vendor’s test rig capacity will be applied. PETROBRAS: PETROBRAS re-states comment above. No additional costs will be accepted. Regarding test bed limitations, they shall be submitted to PETROBRAS for review and acceptance during bid stage. Deviations not previously advised will not be considered. Subject closed.

Closed 100

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5.b

5. Static test verification. b. Repeat 2 – static test pressure. VENDOR: Static test pressure test can be repeated (per paragraph 2) for an additional charge.

PETROBRAS: Not acceptable. PETROBRAS base requirements follow API specifications. VENDOR: Static test pressure will vary depending on customer needs (which items, frequency, test time, etc). For this reason is offered at additional cost. PETROBRAS: PETROBRAS re-states comment above. No additional costs will be accepted. Subject closed.

Closed 100

Item Annex 1E – Typical material specifications (informative)

-

Typical material specifications. VENDOR: Equivalent DIN materials may be used.

PETROBRAS: Acceptable provided that materials are equivalent to or better than ASTM/ASME. Equivalence table to be included in proposal. VENDOR: Noted. PETROBRAS: Noted.

Closed 600

Chapter 2 – Centrifugal and axial compressors Item Section 1 – General

1.1

This chapter, in conjunction with Chapter 1 of this standard, covers the minimum requirements for centrifugal and axial compressors for pipeline or process air or gas services. VENDOR: Only the paragraphs related to centrifugal compressor are applied. Requirements particularly for axial compressor are not considered in vendor’s proposal.


Item Section 2 – Basic design PRELIMIN

ARY





2.1.1.1

The sectional head-capacity characteristic curve shall rise continuously from the rated point to predicted surge. The compressor, without the use of a bypass, shall be suitable for continuous operation at any capacity at least 10% greater than the predicted surge capacity shown in the proposal. VENDOR: The surge line may be defined as the minimum capacity at which the head curve no longer rises. Some specified operating points may require recycle to accommodate other specified operating points.

PETROBRAS: There shall be no recirculation flow for any of the specified operating points, except for the minimum. VENDOR: Acknowledged. PETROBRAS: Noted.

Closed 200

2.1.1.1

The sectional head-capacity characteristic curve shall rise continuously from the rated point to predicted surge. The compressor, without the use of a bypass, shall be suitable for continuous operation at any capacity at least 10% greater than the predicted surge capacity shown in the proposal. VENDOR: Clarification: For axial compressors, the surge point evaluated for compliance with the required 10% capacity margin shall be at the rated head, not on a constant speed or constant stator position line.

PETROBRAS: Out of scope of this PETROBRAS document. VENDOR #300: Agreed to PETROBRAS. VENDOR #800: Noted.

Closed 800

2.1.1.1

The sectional head-capacity characteristic curve shall rise continuously from the rated point to predicted surge. The compressor, without the use of a bypass, shall be suitable for continuous operation at any capacity at least 10% greater than the predicted surge capacity shown in the proposal. VENDOR: Exception: A continuously rising head-capacity characteristic curve is not guaranteed. Specific head rise requirements must be mutually agreed upon.

PETROBRAS: Not acceptable. PETROBRAS: VENDOR’s reply not received. PETROBRAS re-states comment above. Subject closed.

Closed 800

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2.1.1.1, 4.3.3.1.2

4.3.3.1.2. For variable speed machines, head and capacity shall have zero negative tolerance at the normal operating point (or other point as specified), and the power at this point shall not exceed 104% of the vendor predicted shaft power value. This tolerance shall be inclusive of all test tolerances. Surge shall comply with provisions of 2.1.1.1. Note: Both of the performance test codes referred to have provision for calculating inaccuracy based on instrumentation and procedures. These test inaccuracies are already included in the above tolerance and, therefore, are not to be further additive. VENDOR: Range to surge shown on the head capacity characteristic curve is expected, not guaranteed. Please refer to performance guarantee contained in proposal

PETROBRAS: Noted. However, actual surge phenomena shall be detected during shop performance test. VENDOR: During the performance test at the factory, the compressor will be brought to surge on the test stand under reduced power/speed conditions in order to obtain the surge location. Surge range is not guaranteed as compared to the maps provided during the proposal. PETROBRAS: Actual surge margins outside expected limits shall be discussed prior to test approval. Subject closed.

Closed 700

2.3.1.1

The purchaser will specify the relief valve setting. The maximum allowable working pressure of the casing shall be at least equal to the specified relief valve setting. VENDOR: The maximum allowable working pressure (design pressure) is fixed and specified in the API 617 datasheet.

PETROBRAS: Not acceptable. MAWP and design pressure are not the same, by definition, as per API requirements. Some PURCHASER's plant conditions (e.g. settle out pressure, flare back pressure etc.) may affect VENDOR's calculation of compressor MAWP. VENDOR: Confirmed that there might be a deviation of design pressure and MAWP. Both values will be stated in compressor data sheets. PETROBRAS: Noted. It is PETROBRAS understanding that VENDOR’s only deviation was regarding definitions of MAWP and design pressure. Everything else from such API paragraph requirement will be accomplished without deviations. Subject closed.

Closed 600

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2.3.1.1.1

When a relief valve setting is not specified, the maximum allowable working pressure shall be at least 1.25 times the maximum specified discharge pressure (gauge). System protection shall be furnished by the purchaser. VENDOR: Maximum specified discharge pressure is the highest discharge pressure indicated on sheet 1 of the customer data sheets.

PETROBRAS: Correct assumption. Please note that some PURCHASER's plant conditions (e.g. settle out pressure, flare back pressure etc.) may affect VENDOR's calculation of compressor MAWP. VENDOR: Acknowledged. PETROBRAS: Noted.

Closed 200

2.3.1.1.1

When a relief valve setting is not specified, the maximum allowable working pressure shall be at least 1.25 times the maximum specified discharge pressure (gauge). System protection shall be furnished by the purchaser. VENDOR: The maximum allowable working pressure (design pressure) is fixed and specified in the API 617 datasheet

PETROBRAS: Not acceptable. MAWP and design pressure are not the same, by definition, as per API requirements. Some PURCHASER's plant conditions (e.g. settle out pressure, flare back pressure etc.) may affect VENDOR's calculation of compressor MAWP. VENDOR: Confirmed that there might be a deviation of design pressure and MAWP. Both values will be stated in compressor data sheets. PETROBRAS: Noted. It is PETROBRAS understanding that VENDOR’s only deviation was regarding definitions of MAWP and design pressure. Everything else from such API paragraph requirement will be accomplished without deviations. Subject closed.

Closed 600

2.3.1.1.1

When a relief valve setting is not specified, the maximum allowable working pressure shall be at least 1.25 times the maximum specified discharge pressure (gauge). System protection shall be furnished by the purchaser. VENDOR: Clarification: Refer to the compressor data sheets for the maximum casing design pressure.

PETROBRAS: Please note that some PURCHASER's plant conditions (e.g. settle out pressure, flare back pressure etc.) may affect VENDOR's calculation of compressor MAWP. VENDOR: Noted. PETROBRAS: Noted.

Closed 800 PRELIMIN

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2.3.1.2

Casings designed for more than one maximum allowable pressure level (split pressure-level casings) are permitted only in process air service with an atmospheric pressure inlet. Split pressure-level casings are not permitted in other services unless specifically approved by the purchaser. If approved, the vendor shall define the physical limits and the maximum allowable working pressure of each section of the casing. VENDOR: Exception: For the casing configuration quoted in this proposal maximum allowable pressures are [x] psig for the inlet end and [y] psig for the discharge end due to design limitations. A split hydrotest is required.

PETROBRAS: Suction region shall be designed and tested using the highest MAWP as a reference for the 1.5 x hydrostatic test pressure. Therefore a split hydrotest is not acceptable. VENDOR: Noted. PETROBRAS: Noted.

Closed 800

2.3.1.5

Casings designed for more than one maximum allowable pressure level (split pressure-level casings) are permitted only in process air service with an atmospheric pressure inlet. Split pressure-level casings are not permitted in other services unless specifically approved by the purchaser. If approved, the vendor shall define the physical limits and the maximum allowable working pressure of each section of the casing. VENDOR: The use of O-rings or ring grooves shall not be subject to purchaser’s approval. O-ring seals are used for certain combinations of frame size and working pressure.

PETROBRAS: The use of O-rings shall be discussed, case by case, during bid stage, considering service severity (contamination, corrosiveness, etc.). VENDOR: Noted. PETROBRAS: Noted.

Closed 400

2.3.1.5

Casings designed for more than one maximum allowable pressure level (split pressure-level casings) are permitted only in process air service with an atmospheric pressure inlet. Split pressure-level casings are not permitted in other services unless specifically approved by the purchaser. If approved, the vendor shall define the physical limits and the maximum allowable working pressure of each section of the casing. VENDOR: O-rings with grooves machined at seal cartridge parts are applied for axial split compressors.

PETROBRAS: Acceptable. VENDOR: Noted. PETROBRAS: Noted.

Closed 500

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2.3.1.5

Casings designed for more than one maximum allowable pressure level (split pressure-level casings) are permitted only in process air service with an atmospheric pressure inlet. Split pressure-level casings are not permitted in other services unless specifically approved by the purchaser. If approved, the vendor shall define the physical limits and the maximum allowable working pressure of each section of the casing. VENDOR: VENDOR Standard is a metal-to-metal joint with a suitable sealing compound. However, depending on the application, a seal element which is retained in a groove may be used.

PETROBRAS: The use of O-rings shall be discussed, case by case, during bid stage, considering service severity (contamination, corrosiveness, etc.). VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

2.3.1.5

Casings designed for more than one maximum allowable pressure level (split pressure-level casings) are permitted only in process air service with an atmospheric pressure inlet. Split pressure-level casings are not permitted in other services unless specifically approved by the purchaser. If approved, the vendor shall define the physical limits and the maximum allowable working pressure of each section of the casing. VENDOR: Exception: For the compressors quoted, an O-rings is/are required on the horizontal joints.

PETROBRAS: The use of O-rings shall be discussed, case by case, during bid stage, considering service severity (contamination, corrosiveness, etc.). VENDOR: Noted. PETROBRAS: Noted.

Closed 800

2.3.1.7

Socket-head, or spanner-type bolting shall not be used externally unless specifically approved by the purchaser. VENDOR: In cases of limited space socket-head bolting will be used.

PETROBRAS: Socket-head, slotted-nut, or spanner-type bolting shall not be externally used. Exceptions to be discussed, case by case, during bid stage, considering space limitations and assembly/disassembly issues. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

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2.3.1.7

Socket-head, or spanner-type bolting shall not be used externally unless specifically approved by the purchaser. VENDOR: Due to space constraints on the compressor, socket head bolts are widely used for auxiliary connections

PETROBRAS: Socket-head, slotted-nut, or spanner-type bolting shall not be externally used. Exceptions to be discussed, case by case, during bid stage, considering space limitations and assembly/disassembly issues. VENDOR #700: VENDOR uses SAE flanges on auxiliary connection for bearing feed/drain, seal gas lines, casing drains. VENDOR #300: Not Agreed. Agreed with VENDOR. PETROBRAS: VENDOR #300’s comment disregarded. PETROBRAS re-states comment above. Subject closed.

Closed 700

2.3.1.7

Socket-head, or spanner-type bolting shall not be used externally unless specifically approved by the purchaser. VENDOR: Exception: VENDOR uses socket head bolting in areas of limited access such as bearing housing attachment and seal housing bolting to the endwall.

PETROBRAS: Socket-head, slotted-nut, or spanner-type bolting shall not be externally used. Exceptions to be discussed, case by case, during bid stage, considering space limitations and assembly/disassembly issues. VENDOR #300: Not Agreed. Agreed with VENDOR. VENDOR #800: Noted. PETROBRAS: VENDOR #300’s comment disregarded. PETROBRAS re-states comment above. Subject closed.

Closed 800

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2.3.2.1

Casing connections will be in accordance with 2.3.2, in Chapter 1 of this standard. VENDOR: All connections shall be designed at least for the max stage working pressure or settle out pressure whichever is higher. See datasheets.

PETROBRAS: All connections shall be designed, and tested, considering the highest MAWP or plant settle out pressure, whichever is greater. Other requirements as per API Std 617. VENDOR #400: See comment to API 617 para. 2.3.2.1.1 chapter 1. VENDOR #300: Not Agreed. Agreed with VENDOR. PETROBRAS: PETROBRAS re-states comment above. Refer to PETROBRAS’ comment on Chapter 1, paragraph 2.3.2.1.1. VENDOR #300’s comment disregarded. Subject closed.

Closed 400

2.3.2.3.1

Auxiliary connections shall be at least DN 20 (3/4-in. nominal pipe size). For socket-welded construction, a 2-mm (1/16-in.) gap, as measured prior to welding, shall be left between the pipe end and the bottom of the socket in the casing. Note: See 2.3.2.1.3 of Chapter 1 for allowable connection sizes. VENDOR: For auxiliary connection size and type, refer to API 617 datasheet.

PETROBRAS: Not acceptable. VENDOR: VENDOR does not do socket welded. VENDOR uses Swadgelock. PETROBRAS: Noted.

Closed 100

2.3.2.3.1

Auxiliary connections shall be at least DN 20 (3/4-in. nominal pipe size). For socket-welded construction, a 2-mm (1/16-in.) gap, as measured prior to welding, shall be left between the pipe end and the bottom of the socket in the casing. Note: See 2.3.2.1.3 of Chapter 1 for allowable connection sizes. VENDOR: Exception: Some endwall connections are 1/2 inch due to space limitations.

PETROBRAS: Exceptions to be discussed, case by case, during bid stage, considering space limitations and assembly/disassembly issues. VENDOR: Noted. PETROBRAS: Noted.

Closed 800

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2.3.2.3.2

Threaded connections for pipe sizes DN 20 (3/4-in. NPT) through DN 40 (11/2-in. NPT) size are permissible with the approval of the purchaser. Note: See 2.3.2.3.5 of Chapter 1 for additional requirements. VENDOR: Some auxiliary connections are also threaded without the use of flanges and without seal welding and should not be subject to purchaser approval.

PETROBRAS: Not acceptable for hydrogen-rich or other services where the use of threaded connections is not allowed by applicable specifications. The use of threaded connections for other services shall be discussed, case by case, during bid stage, considering severity (contamination, corrosiveness, etc.), safety, and environmental issues. VENDOR: Threaded connection will not be used for process gas connection. Only Nitrogen / Instrument Air connection for DGS separation seal will be threaded. PETROBRAS: Threaded connections which might be exposed to process gas in case of failures are not acceptable. Subject closed.

Closed 400

2.3.2.4

When specified, connections for borescopic examination shall be supplied in mutually agreeable locations. VENDOR: The standard pipeline compressor doesn't have connections for borescopic examination, but can be included as an option.


Closed 600

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2.3.4.1

The compressor shall be designed to withstand external forces and moments on each nozzle calculated per Equations 2.E-1a or 2.E-1b and 2.E-2 of Annex 2E. The vendor shall furnish the allowable forces and moments for each nozzle in tabular form. VENDOR: Compressor is designed to withstand nozzle loads of 15 times NEMA.

PETROBRAS: VENDOR to confirm "15 times NEMA" loads as stated. PETROBRAS will accept 15 x NEMA SM 23 loads provided that annex 2E equations are accomplished as well. VENDOR #600: Confirmed for pipeline applications. VENDOR #300: Not Agreed. We can confirm 8 x NEMA 23. Too high nozzle load and moment may affect the behavior of AVM. PETROBRAS: Both comments noted. Subject closed.

Closed 600

2.3.4.1

The compressor shall be designed to withstand external forces and moments on each nozzle calculated per Equations 2.E-1a or 2.E-1b and 2.E-2 of Annex 2E. The vendor shall furnish the allowable forces and moments for each nozzle in tabular form. VENDOR: No table of allowable Forces and Moments on compressor nozzles is provided, since any combination of Forces and Moments respecting Annex 2E is acceptable. If Forces and Moments in Purchaser's piping calculation exceed the limits stated in Annex 2E, Purchaser will submit such Forces and Moments to VENDOR for verification.

PETROBRAS: Not acceptable. Calculation sheet and table with allowable loads, for each nozzle, to be included in equipment documentation (normally provided with arrangement drawings) during design review stage. VENDOR’s reply not received. Subject closed.

Closed 900

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2.3.4.2

Casing and supports shall be designed to have sufficient strength and rigidity to limit coupling movement caused by imposing allowable forces and moments to 50 µm (0.002 in.). VENDOR: Deflection allowance for supports will be designed to 25% of coupling vendor’s allowable misalignment.

PETROBRAS: Not acceptable. VENDOR #700: VENDOR comment to follow. VENDOR #300: Not agreed. Agreed with VENDOR. PETROBRAS: VENDOR #700’s reply not received. VENDOR #300’s comment disregarded. PETROBRAS re-states comment above. Subject closed.

Closed 700

2.4.1

When specified or required to meet specified operating conditions, Adjustable Inlet Guide Vanes (AIGVs) on centrifugal compressors or variable stators on axial compressors shall be supplied. All or some of the stator blade rows may be adjustable. PETROBRAS: For this compressor no Adjustable Inlet Guide Vanes (AIGVs) will be used. By speed variation of the driver operating conditions can be adjusted.


Closed 600

2.5.1

Each assembled rotor shall be clearly marked with a unique identification number. This number shall be on the non-drive end of the shaft or in another accessible area that is not prone to maintenance damage. VENDOR: Rotor identification is on the face of the balance piston, near the discharge end of the rotor.


Closed 100

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2.5.2

Unless other shaft protection is approved by the purchaser, renewable components shall be furnished at interstage close-clearance points. Sleeves, spacers or bushings shall be made of materials that are corrosion-resistant in the specified service. VENDOR: Renewable shaft sleeves shall not be provided at interstage close clearance points. The use of rotating lab. (see chapter 1 2.5.7) eliminates the necessity for shaft sleeves. Depending on frame size and working pressure renewable stator rings may be provided at lab. seals. The stationary interstage labyrinths do not contact the shaft and thus sleeves are not required.

PETROBRAS: During normal running conditions, no contact is expected. However, in case of rubbing due to excessive deflections, Petrobras does not accept the shaft proper to be damaged. Therefore, sleeves are required. VENDOR: Sleeves are not foreseen with VENDOR's compressor design and would cause an enormous change of the entire VENDOR compressor design. Rubbing is avoided by designing the clearance of the labyrinth higher than possible excessive deflections that can occur during service. PETROBRAS: PETROBRAS prefers stationary labyrinths. In this case, sleeves may not be required. Subject closed.

Closed 400

2.5.2.1

Shaft sleeves shall be provided under shaft end seals. Sleeves shall be treated to resist wear and sealed to prevent gas leakage between the shaft and sleeve. VENDOR: Exception: Sleeves are not used under iso-carbon shaft end seals and Pos-E-Sep separation seals. Stainless steel sleeves under babbitted seals are not desirable due to wire wooling effects.


2.5.2.2

Shaft sleeves shall be provided under interstage seals. Closed impeller eye seals/bushings, which are stationary, do not require replaceable sleeves. VENDOR: See 2.5.2.

PETROBRAS: See 2.5.2. VENDOR: See 2.5.2. PETROBRAS: See 2.5.2. Subject closed.

Closed 400

2.5.2.2

Shaft sleeves shall be provided under interstage seals. Closed impeller eye seals/bushings, which are stationary, do not require replaceable sleeves. VENDOR: This requirement is not applicable to VENDOR's design as the rotating part of the interstage labyrinth is part of the impeller hub.


Closed 600 PRELIMIN

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2.5.2.2

Shaft sleeves shall be provided under interstage seals. Closed impeller eye seals/bushings, which are stationary, do not require replaceable sleeves. VENDOR: Exception: Sleeves are not possible under interstage labyrinth seals for axial compressors.

PETROBRAS: Noted. Out of scope.

Closed 800

2.5.3.1

Shafts for non through-bolt rotors shall be made of one-piece, heat treated steel that is suitably machined. Shafts that have a finished diameter larger than 200 mm (8 in.) shall be forged steel. Shafts that have a finished diameter of 200 mm (8 in.) or less shall be forged steel or hot rolled barstock, providing such barstock meets all quality and heat treatment criteria established for shaft forgings. VENDOR: Hot rolled steel bar stock that has equal or superior qualities to forged may be used.

PETROBRAS: PETROBRAS base requirements follow API specifications. Regarding hot rolled steel bar stock shafts, VENDOR to demonstrate successful experience with shaft finished diameters larger than 200 mm (8 in). Experience diagrams to be provided during proposal stage for PETROBRAS review and approval. VENDOR: Acknowledged. PETROBRAS: Noted.

Closed 200

2.5.3.3

Proven methods of axial compressor rotor construction shall be offered. This includes solid (one-piece), disk-on-shaft, or stub shaft using throughbolt, disk or drum construction, or other approved means. VENDOR: VENDOR centrifugal compressors use a proven through-bolt rotor construction.

PETROBRAS: Process compressors shall be provided with non through-bolt rotors and solid (one single piece) shafts. The use of modular (through-bolt) rotors for gas transportation (pipeline) centrifugal compressors is not automatically acceptable. PETROBRAS may agree with their use only for some particular applications. Therefore, such modular designs shall be submitted for PETROBRAS approval, case-by-case. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

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2.5.4.1

A balance piston, balance line, and porting shall be provided if required to reduce axial loads on the thrust bearings. A separate pressure-tap connection or connections shall be provided to indicate the pressure in the balancing chamber, not in the balance line. VENDOR: No separate pressure-tap connection(s) are included, but can be included as an option.

PETROBRAS: Not acceptable. API requirement to be followed. VENDOR #600: A separate pressure-tap connection(s) is not recommended since there are space limitations depending on the machine size. Furthermore, the pressure measured in this chamber is the suction pressure of the compressor which is available due to other measurements. VENDOR #300: Agreed with PETROBRAS. PETROBRAS: PETROBRAS re-states comment above. Subject closed.

Closed 600

2.5.4.3

When specified, a pressure tap connection shall be supplied in the downstream end of the balance line to allow measurement of differential pressure in the balance line. Note: This connection may not be in the compressor supply, it might be in the process piping. VENDOR: Can be included as an option.

PETROBRAS: Disregard the bullet. Paragraph 2.5.4.3 text is mandatory. VENDOR #600: A separate pressure-tap connection(s) is not recommended since there are space limitations depending on the machine size. Furthermore, the pressure measured in this chamber is the suction pressure of the compressor which is available due to other measurements. VENDOR #300: Agreed with comment. Pressure tap on balance line is not recommended. PETROBRAS: Pressure-tap is required but may be shipped loosed as per API text. Subject closed.

Closed 600

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2.5.6.1

The blade natural frequencies shall not coincide with any source of excitation from 10% below minimum allowable speed to 10% above maximum continuous speed. If this is not feasible, blading shall be designed with stress levels low enough to allow unrestricted operation, at any specified operating speed for the minimum service life defined in 2.1.2 of Chapter 1. This shall be verified by Goodman diagrams or their equivalent. The vendor shall identify unacceptable speeds. Note: Excitation sources include fundamental and first harmonic passing frequencies of rotating and stationary blades upstream and downstream of each blade row, gas passage splitters, irregularities in vane and nozzle pitch at horizontal casing flanges, and the first seven rotor speed harmonics. VENDOR: Exception: VENDOR axial compressor blades are designed to avoid interference of fundamental modes with running speed and the first two harmonics of running speed and passing frequencies of stator blades immediately upstream. The blades have been shown by analysis and experience to have sufficient strength to withstand other excitation frequencies without damage within the recommended operating map.

PETROBRAS: Out of scope of this PETROBRAS document.

Closed 800

2.6

Dynamics shall be in accordance with 2.6 of Chapter 1. VENDOR: Bidder interpretation and criteria for meeting the requirements of this section are detailed in Bidder Standard Specification which will be included in the proposal.

PETROBRAS: Refer to PETROBRAS replies to specific deviations. VENDOR: The referenced bidder specification is not a deviation to the API standard. It is a procedure that goes into detail about how VENDOR complies with the specification requirements and is only presented for clarification. PETROBRAS: Please provide standard specification for PETROBRAS review and comments before any bid. Subject closed.

Closed 200

2.7.1.1.1

Unless otherwise specified, hydrodynamic bearings shall have flood lubrication. VENDOR: This offering has directed lube bearings.


Closed 200 PRELIMIN

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2.7.1.1.1

Unless otherwise specified, hydrodynamic bearings shall have flood lubrication. VENDOR: Directly lubricated bearings will be applied for radial and thrust bearings of centrifugal compressors and radial bearings of integrally geared compressors, in order to reduce its mechanical losses.


Closed 500

2.7.1.1.1

Unless otherwise specified, hydrodynamic bearings shall have flood lubrication. VENDOR: VENDOR Radial Bearings are designed with flood lubrication but the Thrust Bearings are of directed lube design.


Closed 600

2.7.1.1.1

Unless otherwise specified, hydrodynamic bearings shall have flood lubrication. VENDOR: To reduce power losses, non-flooded bearings may be used on small high speed compressors.

PETROBRAS: To be discussed during proposal stage. VENDOR #300: Agreed with VENDOR. PETROBRAS: Noted. Arrangement will be evaluated in case by case basis.

Closed 700

2.7.1.1.2

When specified, active magnetic bearings shall be provided. Note: Annex 4F gives application considerations for use of active magnetic bearings. These bearings are not specifically being recommended for equipment included in this chapter of this standard, although some users may decide to incorporate this technology into their units. VENDOR: Standard pipeline compressor cannot be equipped with active magnetic bearings.


Closed 600

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2.7.1.3

As a design criteria, bearing metal temperatures shall not exceed 100°C (212°F) at specified operating conditions with a maximum inlet oil temperature of 50°C (120°F). Vendors shall provide bearing temperature alarm and shutdown limits on the datasheets. VENDOR: VENDOR compressor packages typically use air-to-oil coolers that produce oil temperatures in excess of 120°F (48.88°C) and bearing metal temperatures above 212°F (100°C). See data sheets for alarm and shutdown levels recommended by the bearing manufacturer.

PETROBRAS: Not acceptable. Refer to NI-2626, paragraph 6.4.1.6. VENDOR #100: Item Description Temperature Setpoint 1 Lube Oil High Temperature Shutdown 165°F 2 Lube Oil High Temperature Alarm 160°F 3 Lube Oil Cooler Max. Outlet Temperature 150°F 4 Temperature Control Valve Setpoint 135°F 5 Low Oil Temperature Alarm 110°F There has to be at least a 10°F difference between this and the oil cooler outlet temperature in order for the cooler to work. VENDOR #300: Agreed with VENDOR. PETROBRAS: VENDOR #300’s comment disregarded. PETROBRAS re-states comment above. Main reason is due to necessity of using ordinary, common, easily available Babbitt alloys with ordinary, common, mineral oils. Subject closed.

Closed 100

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2.7.1.3

As a design criteria, bearing metal temperatures shall not exceed 100°C (212°F) at specified operating conditions with a maximum inlet oil temperature of 50°C (120°F). Vendors shall provide bearing temperature alarm and shutdown limits on the datasheets. VENDOR: VENDOR endorses this design criterion, but in some cases the measured temperatures may exceed this limit.

PETROBRAS: PETROBRAS base requirements follow API specifications. Other limits shall be submitted to PETROBRAS for approval during bid stage. Refer to NI-2626, paragraph 6.4.1.6. VENDOR #600: Accepted. Explanation: Bearing pad temperature should not exceed 105°C at normal continuous operation. Alarm and trip settings at site are 115 and 125°C. VENDOR #300: Agreed with VENDOR. PETROBRAS: VENDOR #300’s comment disregarded. PETROBRAS re-states comment above. Main reason is due to necessity of using ordinary, common, easily available Babbitt alloys with ordinary, common, mineral oils. Subject closed.

Closed 600

2.7.1.3

As a design criteria, bearing metal temperatures shall not exceed 100°C (212°F) at specified operating conditions with a maximum inlet oil temperature of 50°C (120°F). Vendors shall provide bearing temperature alarm and shutdown limits on the datasheets. VENDOR: Clarification: VENDOR uses a maximum criterion of 111oC (232oF) for bearing metal temperature predictions with an oil supply temperature of 60oC (140oF) with ISO Grade 46 oil. Actual results will vary within VENDOR's historical tolerance range.

PETROBRAS: PETROBRAS base requirements follow API specifications. Other limits shall be submitted to PETROBRAS for approval during bid stage. Refer to NI-2626, paragraph 6.4.1.6. VENDOR #300: Agreed with VENDOR. PETROBRAS: VENDOR #300’s comment disregarded. VENDOR #800’s has not replied. Subject closed.

Closed 800

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2.7.1.3

As a design criteria, bearing metal temperatures shall not exceed 100°C (212°F) at specified operating conditions with a maximum inlet oil temperature of 50°C (120°F). Vendors shall provide bearing temperature alarm and shutdown limits on the datasheets. VENDOR: This requirement is intended applicable only for all operating conditions stated in compressor datasheet.

PETROBRAS: Noted. VENDOR #300: Not enough information. PETROBRAS: VENDOR #300’s comment disregarded. Subject closed.

Closed 900

2.7.2.1

Sleeve or pad radial bearings shall be used and shall be split for ease of assembly. The use of non-split designs requires the purchaser’s approval. The bearings shall be precision bored with steel-backed babbitted replaceable liners, pads, or shells. The bearing design shall not require removal of the coupling hub to permit replacement of the bearing liners, pads, or shells unless approved by purchaser. VENDOR: Bearings are of the non-split design, however; VENDOR shaft ends are designed using a spline which permits the removal of the coupling hub with ordinary hand and maintenance tools, making the removal and replacement of the bearing and hub an easy task.


Closed 100

2.7.2.1

Sleeve or pad radial bearings shall be used and shall be split for ease of assembly. The use of non-split designs requires the purchaser’s approval. The bearings shall be precision bored with steel-backed babbitted replaceable liners, pads, or shells. The bearing design shall not require removal of the coupling hub to permit replacement of the bearing liners, pads, or shells unless approved by purchaser. VENDOR: The coupling hub has to be removed to replace the bearing pads for the radial split casing compressors.

PETROBRAS: Noted. VENDOR: Noted. VENDOR: The coupling hub has to be removed to replace the bearing pads for the radial split casing compressors, and the axial split casing compressors with end head plates. PETROBRAS: Noted.

Closed 500

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2.7.2.1

Sleeve or pad radial bearings shall be used and shall be split for ease of assembly. The use of non-split designs requires the purchaser’s approval. The bearings shall be precision bored with steel-backed babbitted replaceable liners, pads, or shells. The bearing design shall not require removal of the coupling hub to permit replacement of the bearing liners, pads, or shells unless approved by purchaser. VENDOR: Exception #1: For the compressors quoted, the journal bearing pads are chrome-copper backed. Exception #2: The compressor quoted uses KMC deflection pad bearings that do not have replaceable pads.

PETROBRAS: These are particular deviations which may not be acceptable depending on service characteristics. Basically, PETROBRAS requirements follow API specifications. Other materials shall be submitted to PETROBRAS for approval during bid stage, considering handled gas composition. VENDOR #300 [Regarding exception #1]: Agreed with PETROBRAS. VENDOR #800: [Both] Noted. PETROBRAS: [Both] Noted.

Closed 800

2.7.2.1

Sleeve or pad radial bearings shall be used and shall be split for ease of assembly. The use of non-split designs requires the purchaser’s approval. The bearings shall be precision bored with steel-backed babbitted replaceable liners, pads, or shells. The bearing design shall not require removal of the coupling hub to permit replacement of the bearing liners, pads, or shells unless approved by purchaser. VENDOR: For not-to-drive-end side, compressors with outboard thrust collar will have the journal bearing housing barrel type (i.e. non-split).

PETROBRAS: This is a particular deviation which may not be acceptable depending on service characteristics. Basically, PETROBRAS requirements follow API specifications. Other designs shall be submitted to PETROBRAS for approval during bid stage. VENDOR’s reply not received. Subject closed.

Closed 900

2.7.2.1, 2.7.4.1

2.7.4.1. Rotor support system parts (bearings, bearing housings, bearing carriers, and bearing brackets) shall be separable from the casing, axially split, non-pressurized (vented to atmosphere), and furnished with plugged connections for dry air or inert gas purge to any atmospheric labyrinth seals. Axially split bearing housings shall have a metal-to-metal split joint whose halves are located by means of cylindrical dowels. The removal of the top half of the casing of an axially split machine or the head of a radially split unit shall not be required for replacement of these elements. VENDOR: To improve dynamic stability, non-split bearings are used.

PETROBRAS: PETROBRAS requirements follow API specifications. Other designs shall be submitted to PETROBRAS for approval during bid stage. VENDOR: OK. PETROBRAS: Noted.

Closed 700 PRELIMIN

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2.7.2.2

When specified, tilting pad bearings shoes shall be copper-alloy backed. VENDOR: VENDOR standard design is to use steel backed bearing pads. See also 2.7.3.7.

PETROBRAS: Noted. For some applications, copper-alloy backed configurations may not be acceptable depending on service characteristics. Basically, PETROBRAS requirements follow API specifications. Other materials shall be submitted to PETROBRAS for approval during bid stage. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

2.7.2.3

When specified, copper-alloy bearings shall have hardened steel inserts for support. VENDOR: Exception: When this is specified on the compressor data sheets, we must take exception.

PETROBRAS: Exception noted.

Closed 800

2.7.2.5, 2.7.4.1

2.7.2.5. The removal of the top half of the casing of an axially split machine or the head of a radially split unit shall not be required for replacement of these elements. VENDOR: Overhung style compressors require removal of the head to replace non-drive end bearings.

PETROBRAS: Noted.

Closed 700

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2.7.3.1

Thrust bearings shall be steel-backed, babbitted multiple segments designed for equal thrust capacity in both axial directions and arranged for continuous pressurized lubrication to each side. Both sides shall be tilting pads, incorporating a self-leveling feature, which ensures that each pad carries an equal share of the thrust load even with minor variation in pad thickness. Note: Some low inlet pressure overhung compressors or axials may not need to meet the equal thrust load bi-directional criteria. VENDOR: Based upon VENDOR’s experience with each compressor and each bearing type, VENDOR will provide either a tilt pad or a flex pad design thrust bearing based upon the bearing having the best operating experience for the application.

PETROBRAS: Not acceptable. VENDOR: VENDOR can provide either thrust or journal tilt bearing. PETROBRAS: PETROBRAS re-states comment above. API to be followed. Subject closed.

Closed 100

2.7.3.1

Thrust bearings shall be steel-backed, babbitted multiple segments designed for equal thrust capacity in both axial directions and arranged for continuous pressurized lubrication to each side. Both sides shall be tilting pads, incorporating a self-leveling feature, which ensures that each pad carries an equal share of the thrust load even with minor variation in pad thickness. Note: Some low inlet pressure overhung compressors or axials may not need to meet the equal thrust load bi-directional criteria. VENDOR: Thrust bearings for MODEL X, MODEL Y and MODEL Z compressors are copper-alloy backed.

PETROBRAS: This is a particular deviation which may not be acceptable depending on service characteristics. Basically, PETROBRAS requirements follow API specifications. Other designs shall be submitted to PETROBRAS for approval during bid stage. VENDOR: Noted. To be discussed on case-by-case basis. PETROBRAS: Noted for transportation services only. Subject closed.

Closed 100

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2.7.3.1

Thrust bearings shall be steel-backed, babbitted multiple segments designed for equal thrust capacity in both axial directions and arranged for continuous pressurized lubrication to each side. Both sides shall be tilting pads, incorporating a self-leveling feature, which ensures that each pad carries an equal share of the thrust load even with minor variation in pad thickness. Note: Some low inlet pressure overhung compressors or axials may not need to meet the equal thrust load bi-directional criteria. VENDOR: On through-driven compressors, the self-leveling feature may be limited to the normally loaded side, thus minimizing overhung moment and maintaining a satisfactory separation margin to the second lateral mode(s). Pad thickness tolerances are closely maintained in all such arrangements.

PETROBRAS: To be clarified. VENDOR to provide drawings and specifications, and submit deviation with proposal. VENDOR #700: Details will be discussed during the Proposal phase. VENDOR #300: Not enough information. PETROBRAS: VENDOR #300’s comment disregarded. Regarding VENDOR #700’s comment: Noted for transportation services only. Subject closed.

Closed 700

2.7.3.1

Thrust bearings shall be steel-backed, babbitted multiple segments designed for equal thrust capacity in both axial directions and arranged for continuous pressurized lubrication to each side. Both sides shall be tilting pads, incorporating a self-leveling feature, which ensures that each pad carries an equal share of the thrust load even with minor variation in pad thickness. Note: Some low inlet pressure overhung compressors or axials may not need to meet the equal thrust load bi-directional criteria. VENDOR: Exception: For the compressors quoted, the thrust bearing pads are chrome-copper backed.

PETROBRAS: This is a particular deviation which may not be acceptable depending on service characteristics. Basically, PETROBRAS requirements follow API specifications. Other designs shall be submitted to PETROBRAS for approval during bid stage. VENDOR #300: Agreed with PETROBRAS. VENDOR #800: Noted. PETROBRAS: Noted for general process services only. When handling ammonia-based gases, materials shall be discussed case by case. Subject closed.

Closed 800

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2.7.3.1

Thrust bearings shall be steel-backed, babbitted multiple segments designed for equal thrust capacity in both axial directions and arranged for continuous pressurized lubrication to each side. Both sides shall be tilting pads, incorporating a self-leveling feature, which ensures that each pad carries an equal share of the thrust load even with minor variation in pad thickness. Note: Some low inlet pressure overhung compressors or axials may not need to meet the equal thrust load bi-directional criteria. VENDOR: Exception: Axial compressors and single stage overhung compressors have directional thrust loads and do not require the inactive thrust bearing to be as large as the active thrust bearing. Please refer to the data sheets for thrust bearing size.

PETROBRAS: Out of scope of this PETROBRAS document.

Closed 800

2.7.3.4

Thrust bearings shall be arranged to allow axial positioning of each rotor relative to the casing and setting the bearings’ clearance. VENDOR: Multi casing arrangements with a common thrust bearing do not allow separate axial positioning of each rotor. The preferred casing arrangement uses axially rigid couplings between casings and gear box or driver with a common thrust bearing.

PETROBRAS: Not acceptable. VENDOR #400: A multi casing arrangement with a common thrust bearing is a very special design of a machine train. If such a train will be offered this point needs to be discussed case by case. VENDOR #300: Agreed with PETROBRAS. PETROBRAS: PETROBRAS re-states comment above. Subject closed.

Closed 400

2.7.3.5

Each pad within one side of the thrust bearing, shall be designed and manufactured with dimensional precision that will allow interchange or replacement of the individual pads. Note: Instrumented and offset pivot designs do not allow interchange side to side. VENDOR: [1] VENDOR recommend that the complete bearing be replaced when replacement is required and not just a single pad. [2] Flex pad bearings require the complete bearing be replaced and not a single pad.

PETROBRAS: [1] It is PETROBRAS understanding that VENDOR refers to a complete set of pads, not the complete bearing. [2] Noted. VENDOR: [1] Noted. [2] Noted.

Closed 100 PRELIMIN

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2.7.3.6

When specified, or as approved by purchaser, directed lube may be used in lieu of flooded lube. Note: Directed lube has advantages in power requirement, but has small passages with greater potential to plug. VENDOR: Directed lube may be used at vendor’s decision at the design stage.


Closed 300

2.7.3.6

When specified, or as approved by purchaser, directed lube may be used in lieu of flooded lube. Note: Directed lube has advantages in power requirement, but has small passages with greater potential to plug. VENDOR: See 2.7.1.1.1. VENDOR Radial Bearings are designed with flood lubrication but the Thrust Bearings are of directed lube design.


Closed 600

2.7.3.7

When specified, thrust bearings pads shall be copper-alloy backed and shall have hardened steel inserts for support. VENDOR: VENDOR standard design is to use steel backed bearing pads. See also 2.7.2.2.

PETROBRAS: Noted. For some applications, copper-alloy backed configurations may not be acceptable depending on service characteristics. Basically, PETROBRAS requirements follow API specifications. Other materials shall be submitted to PETROBRAS for approval during bid stage. VENDOR: Confirmed.

Closed 600

2.7.4.1

Rotor support system parts (bearings, bearing housings, bearing carriers, and bearing brackets) shall be separable from the casing, axially split, non-pressurized (vented to atmosphere), and furnished with plugged connections for dry air or inert gas purge to any atmospheric labyrinth seals. Axially split bearing housings shall have a metal-to-metal split joint whose halves are located by means of cylindrical dowels. The removal of the top half of the casing of an axially split machine or the head of a radially split unit shall not be required for replacement of these elements. VENDOR: The bearing housing is vented to atmosphere through the lube oil system.

PETROBRAS: Not acceptable. VENDOR #100: PETROBRAS to clarify why this is a concern. VENDOR #300: VENDOR proposal may be acceptable. PETROBRAS: There shall be separated lines for each bearing housing venting and for each oil supply inlet point. Subject closed.

Closed 100 PRELIMIN

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2.7.4.1

Rotor support system parts (bearings, bearing housings, bearing carriers, and bearing brackets) shall be separable from the casing, axially split, non-pressurized (vented to atmosphere), and furnished with plugged connections for dry air or inert gas purge to any atmospheric labyrinth seals. Axially split bearing housings shall have a metal-to-metal split joint whose halves are located by means of cylindrical dowels. The removal of the top half of the casing of an axially split machine or the head of a radially split unit shall not be required for replacement of these elements. VENDOR: [1] For some applications a non split bearing bracket is used. [2] The separation labyrinths between bearing housing and coupling guard have no provisions for purging. This is not necessary since the separation labyrinths are designed to retain oil in the housing (see Chapter1, § 2.7.4.1). The coupling enclosures are fully enclosed and oil tight. Minor oil leakages to the coupling enclosure are acceptable and reverted to the oil tank.

PETROBRAS: [1] Noted. [2] Not acceptable. VENDOR to follow API requirements. VENDOR: [1] Noted. [2] Comment cannot be withdrawn, as this is VENDOR standard design. Coupling guards are oil tight, no oil spills to the surroundings of the compressor. Design can be presented during clarification meeting. PETROBRAS: [1] Noted. [2] Not acceptable. PETROBRAS recent experience with some bearing housing design by VENDOR #600 justifies such caution. Subject closed.

Closed 600

2.7.4.1

Rotor support system parts (bearings, bearing housings, bearing carriers, and bearing brackets) shall be separable from the casing, axially split, non-pressurized (vented to atmosphere), and furnished with plugged connections for dry air or inert gas purge to any atmospheric labyrinth seals. Axially split bearing housings shall have a metal-to-metal split joint whose halves are located by means of cylindrical dowels. The removal of the top half of the casing of an axially split machine or the head of a radially split unit shall not be required for replacement of these elements. VENDOR: For AXIAL SPLIT COMPRESSOR with welded head flange design, bearing housings are not separable from the casing. The bearing can be fully inspected, removed and replaced.

PETROBRAS: Acceptable only when the use of separable bearing housings from the casing is demonstrated as technically unfeasible. VENDOR’s reply not received. Subject closed.

Closed 900

2.7.4.2

Shaft support structures bolted to casings shall be steel. However, if the compressor casing is manufactured from cast or ductile iron, the bearing housing support structures may be made from the same material. VENDOR: For side inlet compressors, external drive end bearing support may be grey iron.

PETROBRAS: Not acceptable. VENDOR: Bearing supports are case steel. Grey iron was a typo error. PETROBRAS: Noted.

Closed 700 PRELIMIN

ARY





NI-2626, 7.1.3

Substitution (2.8 and 2.8.3 of API Std 617). Shaft seals and shaft sleeves shall be accessible for inspection and replacement without removing the top half of the casing of an axially split compressor or the heads of a radially split unit. Whenever feasible, this requirement shall apply to overhung designs as well. VENDOR: Shaft seals and bearings can be accessible for inspection and replacement without removing the top half of the casing of an axially split compressor or the heads of a radially split unit. Shaft sleeve at shaft end is not applicable for dry gas seal application.


Closed 500

2.8.2

Purchaser will specify the type of shaft end seal to be provided and all operating conditions including start-up, shutdown and settle out conditions. VENDOR: Compressor will be supplied with tandem dry gas seals.

PETROBRAS: Purchaser specification will state the type of seal to be used. VENDOR: Confirmed, however some STANDARD applications will have their own standards. Any modification will result in a non-standard machine with impact on cost and delivery time. PETROBRAS: Not acceptable. VENDOR to comply with PETROBRAS specification regarding type of seal and seal system arrangement during bid stage. Subject closed.

Closed 600

2.8.3

Shaft end seals and, when specified, shaft sleeves shall be accessible for inspection and for replacement without removing the top half of the casing for an axially split compressor or the heads of a radially split unit. VENDOR: For some applications Labyrinth Seals are used instead of Dry Gas Seals. For axially split compressors the Labyrinth Seals can be built in a staggered two-piece design. For inspection and replacement of these Labyrinth Seals removing of top half of the compressor casing is necessary.

PETROBRAS: Not acceptable. Purchaser specification will state the type of seal to be used. Labyrinth seals only acceptable for air services. VENDOR: Confirmed, however some STANDARD applications will have their own standards. Any modification will result in a non-standard machine with impact on cost and delivery time. PETROBRAS: Not acceptable. VENDOR to comply with PETROBRAS specification regarding type of seal and seal arrangement system during bid stage. Subject closed.

Closed 600

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2.10.1

The purchaser will specify whether the seal-oil and lube-oil systems are to be separate or combined. If separate systems are specified, the means of preventing interchange of oil between the two systems shall be described in the vendor’s proposal. VENDOR: When the compressor is provided with oil film seals, the lube and seal oil system are combined.

PETROBRAS: Not acceptable. VENDOR: Dry-gas seals apply. PETROBRAS: PETROBRAS clarifies that even when oil-based seal systems are specified, they shall be fully separated from lube oil systems. Compressed gas shall by no means get in contact with lubricant oil. Subject closed.

Closed 100

2.10.2

Purchaser will specify type and properties of oil to be used. Unless otherwise specified, the lubricant shall be a hydrocarbon oil, of viscosity Grade 32, in accordance with ISO 8068. VENDOR: Hydrocarbon oil of viscosity Grade 46 is proposed for quoted compressors.

PETROBRAS: Oil viscosity choice shall be mutually agreed upon by PETROBRAS, compressor VENDOR, and driver SUPPLIER. VENDOR: Agreed to PETROBRAS’ comment. PETROBRAS: Noted.

Closed 300

2.10.2

Purchaser will specify type and properties of oil to be used. Unless otherwise specified, the lubricant shall be a hydrocarbon oil, of viscosity Grade 32, in accordance with ISO 8068. VENDOR: Unless specifically mentioned in our bid the viscosity grade will be 46 or 68.

PETROBRAS: Oil viscosity choice shall be mutually agreed upon by PETROBRAS, compressor VENDOR, and driver SUPPLIER. VENDOR: Confirmed. PETROBRAS: Noted.

Closed 600

2.10.2

Purchaser will specify type and properties of oil to be used. Unless otherwise specified, the lubricant shall be a hydrocarbon oil, of viscosity Grade 32, in accordance with ISO 8068. VENDOR: Hydrocarbon oil viscosity grade 46 may also be used.

PETROBRAS: Oil viscosity choice shall be mutually agreed upon by PETROBRAS, compressor VENDOR, and driver SUPPLIER. VENDOR’s reply not received. Subject closed.

Closed 900

Item Section 3 – Accessories

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3.4.7.1

Unless otherwise specified, radial shaft vibration and axial-position transducers and bearing temperature sensors shall be supplied, installed, and calibrated in accordance with API Std 670. VENDOR: Keyphasors are not available on overhung or thru-driven compressors.

PETROBRAS: Phase reference probes are required as specified. Deviation will be acceptable whenever the phase reference probe mounting is demonstrated as technically unfeasible. VENDOR: Generally not an issue however details will be discussed during the proposal phase. PETROBRAS: Noted for transportation services only. Usually phase sensors are required for every different shaft rotations, starting from the driver end. Subject closed.

Closed 700

3.4.7.1

Unless otherwise specified, radial shaft vibration and axial-position transducers and bearing temperature sensors shall be supplied, installed, and calibrated in accordance with API Std 670. VENDOR: Deviations to API 670, par. 6.2.1.1: - [1] For standardization reasons, on compressors equipped with internal thrust bearing the spare radial probes may not be located 180 degrees radially from primary probes. Anyway, they shall always be mounted 90 degrees apart from one another. - [2] According to VENDOR standard configuration, the compressor will be equipped with one phase reference probe only.

PETROBRAS: [1] Noted. [2] Not acceptable. Train components (driver, driven, gears, etc.) shall be fitted with one phase reference probe per each different rotation speed. The sensors shall be mounted on drivers, gearboxes, clutches, or mechanical variable speed drivers. VENDOR #300: Agreed with PETROBRAS. PETROBRAS: VENDOR #900 has not replied. Subject closed.

Closed 900

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NI-2626, 7.2.2

Addition (3.5 and 3.5.1.2 of API Std 617). Complete liquid injection system manifold and control devices shall be supplied whenever such system is specified. Liquid injection system shall be, as a minimum, according to the following requirements: a) fluid type and source: as specified on the data sheets, injection liquid may be either supplied by a process stream or suctioned from a reservoir; b) injection points: unless otherwise specified, there shall be an injection point at each stage/casing inlet and at each impeller entrance; c) distribution of flow: unless otherwise specified, 60 % of required flow shall be assigned to stage/casing inlet(s) and 40 % distributed to impeller entrances, considering respective pressure levels; d) required fluid flow: unless otherwise specified or, else, recommended by the vendor, injection liquid flow shall be within 1 % - 3 % of compressor rated mass flow; e) nozzles: unless otherwise specified, injection nozzles shall be of the full-cone atomizing type, with size 90 % less than 100 µ, maximum size of 120 µ. Whenever feasible, nozzles shall be replaceable while compressor is in operation; f) injection manifold and controls: as specified on the data sheets, injection system may require pressurization, filtration, cooling (or heating), piping, valves, reservoir, instruments and other accessories needed for proper operation. According to this Standard, system configuration and scope of supply shall be based (where applicable or analogous) on API Std 614 requirements for a seal oil system with multiple levels of supply pressure and without return lines; g) construction materials: in accordance with compressor requirements or, unless otherwise specified, in 300 stainless steel, as a minimum; h) injection flows shall be continuous. VENDOR: To be discussed on a project-by-project basis.


Closed 500

Item Section 4 – Inspection, testing, and preparation for shipment PRELIMIN

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4.3.1, 4.3.1.2.1

4.3.1. Mechanical running test. 4.3.1.2.1. The equipment shall be operated at speed increments of approximately 10% from zero to the maximum continuous speed and run at the maximum continuous speed until bearing metal temperatures and shaft vibrations have stabilized. Note: Operating equipment at or near critical speeds should be avoided. For axial compressors, other speeds at or near blade resonant frequencies (see 2.5.6.1) should also be avoided. VENDOR: The mechanical running test will be performed with shop test motor. The compressor will be operated at speeds from approx.75% to the maximum continuous speed in 10% increments and run at the maximum continuous speed until bearings, lube oil temperature and shaft vibrations have stabilized.

PETROBRAS: Basically acceptable. The testing procedure shall be submitted for approval during detailing design phase. VENDOR: Agreed to PETROBRAS' comment. PETROBRAS: Closed.

Closed 300

4.3.1.1.1

The contract shaft seals and bearings shall be used in the machine for the mechanical running test, except that the atmospheric breakdown bushing(s) on oil seals may be replaced with a test bushing, if required. Note: Low-pressure mechanical testing may require increased clearance or fewer elements for proper heat removal. VENDOR: The contract atmospheric side seal rings may not be used for the mechanical running test because of reduced low pressure (vacuum condition) mechanical test, which is different from the actual operating condition. The details will be shown on the test procedure at the detail design stage.

PETROBRAS: Noted, when the test is performed under vacuum conditions. VENDOR: Agreed to PETROBRAS' comment. PETROBRAS: Closed.

Closed 300

4.3.1.1.2

Oil viscosity, pressures, temperatures and filtration shall be within the range of operating values recommended in the vendor’s operating instructions for the unit being tested. Oil flow rates to each oil seal and bearing housing shall be measured. VENDOR: In case of string testing with the job header line for lube oil supply, only the overall flow rate to the compressor string will be measured.

PETROBRAS: Not acceptable. Individual flow rates are required even for string tests. Exception may be accepted in case of some gas turbine drivers. VENDOR: Confirmed but details shall be mutually agreed subject to the driver (VSD, Steam Turbine, Gas Turbine). PETROBRAS: Noted.

Closed 600 PRELIMIN

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4.3.1.1.2

Oil viscosity, pressures, temperatures and filtration shall be within the range of operating values recommended in the vendor’s operating instructions for the unit being tested. Oil flow rates to each oil seal and bearing housing shall be measured. VENDOR: Exception: When specified (ref. Chapter 1, para. 4.3.6.1.5), lube oil temperature will be varied about the nominal test temperature to simulate the field-specified acceptable variation in viscosity range.

PETROBRAS: Basically, not acceptable. Deviations on temperature ranges shall be stated and demonstrated during bid stage. Refer also to PETROBRAS comment on chapter 1, paragraph 4.3.6.1.5, above. VENDOR #300: Agreed with VENDOR. VENDOR #800: This exception is only applicable when grades of oil other than ISO VG32 oil @ normal nominal supply temperature/pressure are used. Historically, the PETROBRAS jobs we have done usually if not always use ISO VG32 oil at normal nominal supply temperature/pressure, so it is likely a moot point. The issue for us is that we only have ISO VG32 oil on the test floor, and so, if the project is using anything other than ISO VG32 at normal supply conditions, we still use the ISO VG32 oil, but we adjust the supply temperature to match the required viscosity based on the project's actual oil grade and conditions. PETROBRAS: VENDOR #300’s comment disregarded. VENDOR #800’s comment noted. Subject closed.

Closed 800

4.3.1.1.7

Testing with the contract coupling(s) is preferred. If this is not practical, the mechanical running test shall be performed with coupling(s) or simulators, that have overhung moments within 10% of the contract coupling(s). The axial and circumferential location of the drive coupling hub on the shaft shall be marked or measured before starting the test. VENDOR: Factory testing is conducted using a slave coupling and spacer, which do not simulate the weight or overhung moment of the contract hardware. An idling adapter is not used or provided.

PETROBRAS: Not acceptable, unless VENDOR demonstrates that the use of either the contract coupling or coupling devices, such as overhung moment simulators or idling adapters, is technically unfeasible during bid stage. VENDOR: VENDOR will conduct an analysis to reflect any dynamic performance difference between the coupling used for test and the project coupling. PETROBRAS: PETROBRAS re-states comment above. Subject closed.

Closed 100 PRELIMIN

ARY





4.3.1.1.8

All contract vibration probes, transducers, oscillator-demodulators, and accelerometers shall be used during the test. VENDOR: Exception: Since our test floor monitors are by Bently Nevada, the job probes and oscillator-demodulators will be replaced with Bently Nevada equipment for testing.


NI-2626, 7.3.1.1.1

Addition (4.3.1.1.9 of API Std 617). An additional Real time Analyzer (RTA), connected with the Vendor’s monitoring system, shall be fully available for PETROBRAS use (PETROBRAS own analysis) during all tests. PETROBRAS may, under its discretion, use its own data acquisition equipment, Vendor’s additional analyzer, or both. All vibration and phase signals shall be available for connection. All cables shall be identified. ¹ ADRE™ system is preferred for data collecting and monitoring. If vendor uses another system, then visualization (or translation into ADRE™ files) software shall be included as well. All files regarding recorded tests, successful or not, shall be copied to a CD and given to PETROBRAS. VENDOR: RTA full availability for PETROBRAS use during test is possible but if any additional equipment has to be purchased, e.g. ADRE-Box, it will have a cost impact that need to be backcharged to PETROBRAS. Exact requirements TBD and mutually agreed.

PETROBRAS: Not acceptable. As per answer to comment on paragraph 6.4.1.2. VENDOR: Noted. PETROBRAS: Noted.

Closed 400

4.3.1.2.1

The equipment shall be operated at speed increments of approximately 10% from zero to the maximum continuous speed and run at the maximum continuous speed until bearing metal temperatures and shaft vibrations have stabilized. Note: Operating equipment at or near critical speeds should be avoided. For axial compressors, other speeds at or near blade resonant frequencies (see 2.5.6.1) should also be avoided. VENDOR: Speed increments of 10% are not used. Please see VENDOR Test Specification for details.

PETROBRAS: PETROBRAS base requirements follow API specifications. Other procedures shall be submitted to PETROBRAS for approval during bid stage. VENDOR: Noted. PETROBRAS: Noted.

Closed 100

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4.3.1.2.1

The equipment shall be operated at speed increments of approximately 10% from zero to the maximum continuous speed and run at the maximum continuous speed until bearing metal temperatures and shaft vibrations have stabilized. Note: Operating equipment at or near critical speeds should be avoided. For axial compressors, other speeds at or near blade resonant frequencies (see 2.5.6.1) should also be avoided. VENDOR: If the maximum required shaft power at test conditions exceeds 900 kW, the test bed electrical motor accelerates the compressor without any holds to about 60 percent of maximum continuous speed. From 60 percent up to maximum continuous speed, the speed will be raised in 10 percent increments.


Closed 600

4.3.1.2.1

The equipment shall be operated at speed increments of approximately 10% from zero to the maximum continuous speed and run at the maximum continuous speed until bearing metal temperatures and shaft vibrations have stabilized. Note: Operating equipment at or near critical speeds should be avoided. For axial compressors, other speeds at or near blade resonant frequencies (see 2.5.6.1) should also be avoided. VENDOR: The minimum operating speed of the test bed driver will determine the minimum test speed. From minimum to maximum test speed of the compressor, data will be taken at approximately 10% speed increments.


Closed 700

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4.3.1.2.1

The equipment shall be operated at speed increments of approximately 10% from zero to the maximum continuous speed and run at the maximum continuous speed until bearing metal temperatures and shaft vibrations have stabilized. Note: Operating equipment at or near critical speeds should be avoided. For axial compressors, other speeds at or near blade resonant frequencies (see 2.5.6.1) should also be avoided. VENDOR: The shop test is performed using a shop E-motor or steam turbine driver. The torque can be transmitted by hydraulic coupling and therefore the minimum operating test speed will not in any case be lower than 30% of rated speed (100%).

PETROBRAS: Noted.

Closed 900

NI-2626, 7.3.1.1.2

Addition (4.3.1.2.1 of API Std 617). Equipment specified to be driven at job site by constant speed drivers shall be tested at manufacturer’s shop with variable speed drivers as well. Tests shall be conducted as if variable speeds were to be used at job site, for PETROBRAS reference and information only (not an acceptance criterion). PETROBRAS will use rated speed results for the acceptance of constant speed equipment. VENDOR: The equipment will be operated at speed increments of approximately 10% from zero to 100% speed and run at 100% speed until bearing metal temperatures and shaft vibrations have stabilized, when a shop driver is used.


Closed 500

4.3.1.2.2

The speed shall be increased to trip speed and the equipment shall be run for a minimum of 15 min. VENDOR: VENDOR does not run to trip speed. The speed is limited to the maximum continuous speed; generating a speed signal equal to the trip speed tests the trip. At customer’s request, this test can be performed as a sales order special.

PETROBRAS: Not acceptable. VENDOR: PETROBRAS to clarify if this is not acceptable because it is a Sales Order Special or if it is because VENDOR does not run to trip speed? PETROBRAS: It is not acceptable because it is not in accordance with API Std 617. Subject closed.

Closed 100 PRELIMIN

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4.3.1.2.3

The speed shall be reduced to the maximum continuous speed, and the equipment shall be run for 4 hours continuous operation. VENDOR: VENDOR’s run time at maximum continuous speed is 15 minutes, per VENDOR’s Specification.

PETROBRAS: Not acceptable. VENDOR #100: 4 Hours test can be done at additional cost. VENDOR #300: Agreed with PETROBRAS. PETROBRAS: PETROBRAS re-states comment above. No additional costs will be accepted. Subject closed.

Closed 100

4.3.1.2.3

The speed shall be reduced to the maximum continuous speed, and the equipment shall be run for 4 hours continuous operation. VENDOR: Clarification: [1] Following the 15 minute run at trip speed, the compressor will be decelerated to 400 rpm (in order to comply with the requirements of paragraph 4.3.6.1.2 in Chapter 1), and then accelerated to maximum continuous speed. To further comply with this requirement, the compressor will be accelerated to trip speed following the four-hour test and then decelerated to 400 rpm. [2] In the case that bi-directional dry gas seals are utilized, the compressor will be decelerated to 400 rpm or the minimum speed allowed by the seal vendor, whichever is higher.

PETROBRAS: In order to fully comply with both chapters, 1 and 2, two accelerations to trip speed shall be required: one just before the four-hour MRT, and the other, just after. As a reference, see Figure 1 of NI-2626. VENDOR #300: For minimum operating speed. Agreed with VENDOR. VENDOR #800: VENDOR to comply. PETROBRAS: VENDOR #300’s comment is correct regarding item [2]. VENDOR #800’s comment noted. PETROBRAS fully agrees with statement of VENDOR #800 regarding minimum speed allowed by seal, depending on type. In other words minimum speed shall be that one which will ensure proper lift on seal faces at specified test conditions. Subject closed.

Closed 800

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4.3.1.3.2

While the equipment is operating at maximum continuous speed, or other speed required by the test agenda, vibration data shall be acquired to determine amplitudes at frequencies other than synchronous. This data shall cover a frequency range from 0.25 – 8 times the maximum continuous speed. If the amplitude of any discrete, nonsynchronous vibration exceeds 20% of the allowable vibration as defined in 2.6.8.8 of Chapter 1, the purchaser and the vendor shall mutually agree on requirements for any additional testing and on the equipment’s acceptability. VENDOR: If vaneless diffusers are used and if the pressure rise of any operating point of any stage within the compressor section exceeds 10 bar: Some high pressure applications develop rotating diffuser stall which may cause forced, non synchronous shaft vibrations. This phenomen is by its nature non destabilizing but the resulting vibrations may exceed the 20% limitation as stated in API 617, 7th edition, chapter 2 paragraph 4.3.1.3.2 but will not exceed the API level according chapter 1, paragraph 2.6.8.8.

PETROBRAS: Not acceptable. VENDOR: For stages with vane less diffusers there may be a zone on the performance map at which rotating diffuser stall is present. At onset of stall the steady axisymmetric character of flow within the diffuser is replaced by rotating zones of high and low pressure. Due to the rotating pressure pattern fluctuating radial forces are imposed on the impeller. The excitations due to rotating diffuser stall can lead to forced rotor vibrations. Unlike self excited rotor vibrations, forced rotor vibrations don’t have a negative impact on rotor stability. However it should be noted that the excitations due to rotating diffuser stall can certainly result in rather high forced sub synchronous rotor vibrations, depending on the amount of stall cells and the dynamic pressure in the diffusers. The amplitudes of these sub synchronous rotor vibrations can easily exceed the 20% limitation for non synchronous rotor vibrations as mentioned in API 617, 7th edition, chapter 2, paragraph 4.3.1.3.2 . PETROBRAS: Not acceptable. API limits to be strictly followed, as properly mentioned above by VENDOR. Subject closed.

Closed 600

4.3.1.3.3

The mechanical running test shall verify that lateral critical speeds conform to the requirements of Chapter 1, 2.6.2. VENDOR: In the event the 1st critical speed cannot be detected with the compressor running in the normal configuration, the calculated value will be stamped on the nameplate.

PETROBRAS: Not acceptable. VENDOR’s reply not received. Subject closed.

Closed 900

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4.3.1.3.4

Shop verification of the unbalanced response analysis shall be performed in accordance with Chapter 1, 2.6.2. VENDOR: Shop verification of unbalance response analysis can be conducted at additional cost.

PETROBRAS: Not acceptable. VENDOR to follow API requirements. VENDOR #100: Shop verification of unbalance response analysis can be conducted at additional cost. VENDOR #300: Agreed with PETROBRAS. PETROBRAS: PETROBRAS re-states comment above. No additional costs will be accepted. Subject closed.

Closed 100

4.3.1.3.4

Shop verification of the unbalanced response analysis shall be performed in accordance with Chapter 1, 2.6.2. VENDOR: See exception to para. 2.6.3.1, Chapter 1. ([1] A verification test of the unbalanced response analysis shall only be performed if the separation margins according to para 2.6.2.10 are not fulfilled. [2] If required, the verification test can be performed on one of the rotors with a coupling unbalance during the mechanical shop testing in the test bed, or in the vacuum bunker after high speed balancing.)

PETROBRAS: [1] Not acceptable. [2] Usually, only URT1 is specified, but URT2 would also be necessary if URT1 results should not suffice to validate rotordynamic model. The Unbalance Response Test (URT) can be performed after Mechanical Running Test (MRT) or after High speed balancing (HSB) at Vendor’s choice. In this case, a specific rotordynamic model, for High speed bench support stiffness shall be provided prior to the test. VENDOR: See comment to API 617 para. 2.6.2.2 chapter 1. PETROBRAS: According to Chapter 1, 2.6.2.2, VENDOR confirmed PETROBRAS comment. Subject closed.

Closed 400

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NI-2626, 7.3.1.2.b

Addition (4.3.2 and 4.3.2.3 of API Std 617). VENDOR: Not necessary. The casing will be hydrotested during manufacturing at 1.5 x max casing design temperature.

PETROBRAS: Not acceptable. GLT shall be performed as required. VENDOR: If no problems occur during the test run the seal shall not be dismantled after completion of the mechanical running test. In VENDOR's point of view the merits of a GLT at discharge pressure is minor compared to the benefits of shipping a unit with proven mechanical assembly and integrity. In addition the only useful check that could be done with a GLT at discharge pressure is to proof the tightness of the main discharge nozzle and the drain nozzles. Indeed those nozzles will be dismantled after testing => no benefit in the end. All other casing joints especially the casing covers will never be exposed to a higher pressure than max. suction or settle out pressure. Therefore a leak test of those casing parts at discharge pressure gains no benefit. Therefore VENDOR highly recommends to desist from this test to save time and money. PETROBRAS: Seal leakage measurement during GLT is not useless. It is the only way to verify seal integrity (without disassembling) after so many hours of operation, during performance (PT type II) and mechanical running tests (MRT I, MRT II, URT I, and URT II). Subject closed.

Closed 400

4.3.2.1

After the mechanical running test is completed, each completely assembled compressor casing intended for toxic, hazardous, or flammable service shall be tested as required in 4.3.2.2 and/or, when specified, 4.3.2.3. Note: These tests are intended to verify the integrity of the casing joint. Some shaft seal designs are not gas tight. Therefore, leakage from these seals is acceptable. VENDOR: Assembled compressor leak test may be performed with air or nitrogen.

PETROBRAS: Leak test performed with air is not acceptable. API Std 617 to be followed. VENDOR: VENDOR will conduct this test with Nitrogen. PETROBRAS: Noted.

Closed 100

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4.3.2.2

The assembled compressor (including end seals) shall be pressurized, with an inert gas, to the maximum sealing pressure or the maximum seal design pressure, as agreed upon by the purchaser and the vendor; held at no less than this pressure for a minimum of 30 min. and subjected to a soap-bubble test, or alternate method, to check for gas leaks. The test shall be considered satisfactory when no casing or casing joint leaks are observed. Note: Test gas mole weight should approximate or be less than contract gas mole weight. Helium for low mole weight contract gas, and nitrogen or refrigerant gas for high mole weight should be considered. VENDOR: The dry gas seal will be dismantled after the leakage test and separate shipped (original seal manufacturer box) if the compressor will not be purged with nitrogen.

PETROBRAS: Wrong deviation. Disregarded. VENDOR: Agreed - comment could be deleted. PETROBRAS: Noted.

Closed 400

4.3.2.2

The assembled compressor (including end seals) shall be pressurized, with an inert gas, to the maximum sealing pressure or the maximum seal design pressure, as agreed upon by the purchaser and the vendor; held at no less than this pressure for a minimum of 30 min. and subjected to a soap-bubble test, or alternate method, to check for gas leaks. The test shall be considered satisfactory when no casing or casing joint leaks are observed. Note: Test gas mole weight should approximate or be less than contract gas mole weight. Helium for low mole weight contract gas, and nitrogen or refrigerant gas for high mole weight should be considered. VENDOR: VENDOR Standard Drawing and Data Schedule shall apply to assure optimal engineering sequence.

PETROBRAS: Wrong deviation. Disregarded.

Closed 400

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4.3.2.2

The assembled compressor (including end seals) shall be pressurized, with an inert gas, to the maximum sealing pressure or the maximum seal design pressure, as agreed upon by the purchaser and the vendor; held at no less than this pressure for a minimum of 30 min. and subjected to a soap-bubble test, or alternate method, to check for gas leaks. The test shall be considered satisfactory when no casing or casing joint leaks are observed. Note: Test gas mole weight should approximate or be less than contract gas mole weight. Helium for low mole weight contract gas, and nitrogen or refrigerant gas for high mole weight should be considered. VENDOR: Nitrogen will be used in all assembled compressor gas leak tests, unless contract gas mole weight is less than 10.

PETROBRAS: Noted. For MW between 10 and 28, VENDOR should consider the use of a mixture of inert gases. VENDOR: Noted.

Closed 700

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4.3.2.2, 4.3.2.3

Assembled compressor gas leakage test. Exception: Gas test after mechanical run is not conducted on compressors with labyrinth or carbon ring main casing seals.

PETROBRAS: Noted for air compressors using labyrinths. For any compressor using mechanical seals or carbon ring seals GLT shall be performed according to API Std 617 options stated on paragraph 4.3.2.3. As a reference, see NI-2626. VENDOR: VENDOR cannot perform a gas leak test on a compressor with carbon ring main casing seals with the carbon rings installed in the compressor due to the fact that the carbon ring seal is a leaking seal. Please note that this exception is not referring to compressors using dry gas seals with a carbon ring separation seal. This exception is referring to compressor that only has a carbon ring main casing seal. If our position is not acceptable, Paragraph 4.3.2.3 states that the test can be done without the seals installed. If it is acceptable to PETROBRAS that the test be done with the seals removed, then we could probably do the required test using a sealing plug in place of the carbon ring seals. This would be a cost adder and may have delivery impact. PETROBRAS: Noted regarding oil-based carbon ring seals. Test may be performed without seals, as above. However, tests with dry gas seals remain required to be performed with seals assembled. In either case, neither additional costs nor schedule delays will be accepted. Subject closed.

Closed 800

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4.3.2.2, 4.3.2.3

Assembled compressor gas leakage test. VENDOR: Clarification: [1] The final gas test pressure will not exceed the maximum sealing pressure required for this service. [2] Due to cost, availability, and handling issues, only nitrogen, air or helium would be used for the gas pressure test.

PETROBRAS: [1] It is PETROBRAS understanding that dry gas seals are mounted when final test pressure does not exceed the maximum sealing pressure. See API Std 617, paragraph 4.3.2.3. [2] Gas pressure test performed with air is not acceptable. For MW between 10 and 28, VENDOR should consider the use of a mixture of inert gases. VENDOR: [1] PETROBRAS is correct in their understanding that the dry gas seal are installed for gas test when the test pressure does not exceed the maximum sealing pressure. [2] We should clarify that Helium and Nitrogen are standard gases used for gas test and that Helium is typically used for low mole weight machines. However, with the recent limitations with the global supply of helium, VENDOR may need to consider other alternatives to using pure helium in the future. PETROBRAS: Noted.

Closed 800

4.3.2.3

When specified, the assembled compressor (with or without end seals installed) shall be pressurized with an inert gas to the maximum specified discharge pressure, held at this pressure for a minimum of 30 min., and subjected to a soap bubble test, or alternate method, to check for gas leaks. The test shall be considered satisfactory when no casing or casing joint leaks are observed. Note: The requirements of 4.3.2.2 and 4.3.2.3 may necessitate two separate tests. VENDOR: When specified, this test may have to be limited to the pressure limit of the shaft seals or the test will be conducted on the casing assembly only.

PETROBRAS: Disregard the bullet. Paragraph 4.3.2.3 is always required and specified by PETROBRAS. Either one or two tests may be required depending on maximum sealing pressure or maximum seal design pressure (as agreed), and maximum specified discharge pressure, as per API Std 617, paragraphs 4.3.2.2 and 4.3.2.3. Special consideration shall be given to multiple-casing trains (compressors arranged in tandem), where first train may need to withstand second train discharge pressure. In these cases, requirements of API RP 520 and 521 shall always be considered. VENDOR: Noted.

Closed 700

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4.3.3.2

Such components as compressors, gears, drivers, and auxiliaries that make up a complete unit shall be tested together during the mechanical running test. A separate auxiliary test may be performed with the purchaser’s approval. The complete unit test may be performed in place of, or in addition to, separate tests of individual components as specified by the purchaser. When specified, torsional vibration measurements shall be made to verify the vendor’s analysis. VENDOR: If the complete unit test is specified, job overhead tanks such as seal oil head tank and lube oil head tank will not be used during this test, but shop facility to be used.


Closed 300

4.3.3.2

Such components as compressors, gears, drivers, and auxiliaries that make up a complete unit shall be tested together during the mechanical running test. A separate auxiliary test may be performed with the purchaser’s approval. The complete unit test may be performed in place of, or in addition to, separate tests of individual components as specified by the purchaser. When specified, torsional vibration measurements shall be made to verify the vendor’s analysis. VENDOR: If this test option is specified only the compressor, driver and gear if applicable will participate in the test unless offered otherwise. A test of the oil unit is not included.

PETROBRAS: Not acceptable. The extent of the complete unit test shall depend on the particular scope of supply, as specified, job by job. VENDOR: Our point is that we see no benefit from including job oil unit into the complete unit / string test. The oil unit functionality will be tested separately at oil unit manufacturer's shop. Stationary oil unit in our testing facility is sufficient for nearly all applications. PETROBRAS: Noted. However, the extent of the complete unit test shall depend on the particular scope of supply, as specified, job by job.

Closed 600

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4.3.3.2

Such components as compressors, gears, drivers, and auxiliaries that make up a complete unit shall be tested together during the mechanical running test. A separate auxiliary test may be performed with the purchaser’s approval. The complete unit test may be performed in place of, or in addition to, separate tests of individual components as specified by the purchaser. When specified, torsional vibration measurements shall be made to verify the vendor’s analysis. VENDOR: Clarification: When torsional vibration measurements are specified, any torsional test shall verify that actual separation margins are at least 5% from any excitation source defined in the torsional analysis report. This is based on analytical requirements of 10% margin and accuracy limits of +/-5%. Any failure of achieving this separation margin shall be justified by stress analysis.

PETROBRAS: Wrong paragraph number. Refer to chapter 1, paragraph 2.6.7.5. Not acceptable. VENDOR to follow API Std 617 requirements. VENDOR #300: VENDOR need to correct their Clarification. PETROBRAS: VENDOR #300’s comment disregarded. VENDOR #800 has not replied. Subject closed.

Closed 800

4.3.3.4

For units with external gears, the contract gear shall be tested with the machine(s) during the mechanical running test, as specified. VENDOR: Basically, gear itself is mechanical running tested individually in gear supplier's shop per API 613.

PETROBRAS: Not acceptable. MRT for gearbox is covered by API Std 613 and its own data sheet. However, when paragraph 4.3.3.4 is required, both gear (after being accepted during its own solo run MRT) and compressor MRTs shall be performed together. VENDOR: Confirmed, when paragraph 4.3.3.4 is required, both gear and compressor MRTs is performed together. PETROBRAS: Noted.

Closed 500

Item Figure 2.1-1a – Illustration of terms

-

VENDOR: The flow capability extend to 115% from CRP is not always reachable, depending on compressor service. The maximum flow capacity is specified in the contract curves.

PETROBRAS: Noted. Acceptability will be judged during bid analysis, case by case, item by item. VENDOR’s reply not received. Subject closed.

Closed 900 PRELIMIN

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Note 3

The compressor rated point (CRP) is the intersection on the 100% speed line corresponding to the highest flow of any operating point; point C in the illustration. VENDOR: Exception: VENDOR defines the compressor "rated power" to be the highest power required by any specified operating case and "rated capacity" to be the volume flow associated with the rated power.

PETROBRAS: Not acceptable. API definitions to be followed. VENDOR: Noted. PETROBRAS: Noted.

Closed 800

Note 4

The head-capacity curve at 100% speed shall extend to at least 115% of the capacity of the CRP. Head-capacity curves at other speeds shall be extended to equivalent capacity at each speed. For example, the head-capacity curve at 105% speed shall be extended to at least 1.05 times 1.15 times the capacity of the CRP; the head-capacity curve at 90% speed shall be extended at least 0.9 times 1.15 times capacity of the CRP; and so on. These points define the “approximate capacity limit” curve. VENDOR: This requirement may not be applicable to some of the compressors applications, especially, for heavy molecular weight gas operation. Please refer to compressor performance curve offered in our proposal. The CRP is defined as a specified maximum flow operating point, and not a virtual point shown in this figure.

PETROBRAS: Noted. Acceptability will be judged during bid analysis, case by case, item by item. VENDOR: Noted. PETROBRAS: Noted.

Closed 500

Note 4

The head-capacity curve at 100% speed shall extend to at least 115% of the capacity of the CRP. Head-capacity curves at other speeds shall be extended to equivalent capacity at each speed. For example, the head-capacity curve at 105% speed shall be extended to at least 1.05 times 1.15 times the capacity of the CRP; the head-capacity curve at 90% speed shall be extended at least 0.9 times 1.15 times capacity of the CRP; and so on. These points define the “approximate capacity limit” curve. VENDOR: Exception: The head-capacity curve at 100% speed may not extend to 115% of the CRP, depending on the required operating conditions and the proposed staging. Please refer to the performance curves for predicted overload capacity.

PETROBRAS: Noted. Acceptability will be judged during bid analysis, case by case, item by item. VENDOR’s reply not received. Subject closed.

Closed 800

Item Annex 2B – Centrifugal and axial compressor vendor drawing and data requirements

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-

VENDOR: Clarification: [1] Items 2, 3, 4 and 5 are provided in the instruction manual and are not for record only. [2] Items 7, 10 and 16 are normally provided on one P&I diagram. [3] Items 7, 10 and 16 Bills of Materials will consist of instrument data sheets and component data sheets separately compiled into a document submission. [4] Items 22 and 24 are issued as a single document. [5] Item 28 will be shown on the coupling outline drawing and/or the coupling data sheets. [6] Item 34 is provided in the proposal. [7] Item 36 is to be provided by the Purchaser. [8] Item 37 is provided on the data sheets.

PETROBRAS: [1] Items 2, 3, 4, and 5: not acceptable. Those items are for review and approval by PETROBRAS. It is recognized that part numbers are for reference only. [2] Noted. [3] Noted, only for instruments. Bill of materials for other components and appurtenances to be provided as specified. [4] Noted. [5] Noted. [6] Noted. [7] PETROBRAS does not approve components. Instead, PETROBRAS does approve drawings and schematics of components, accessories, appurtenances, spare parts, and so on. [8] Not acceptable. VENDOR: [1] Items 2, 3, 4, 5: VENDOR submits these for information only. VENDOR can submit them during the job versus just including in the manual, however all customer contract information and equipment item numbers will be noted on a cover sheet only and not on the drawing. [3] Items 7, 10, 16: We should be able to comply for additional cost impact. [7] Item 36: Noted. PETROBRAS: [1] Not acceptable. [3] No cost impacts are acceptable. [7] Noted. Subject closed.

Closed 800

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- VENDOR: Exception: In lieu of Annex 2B, please refer to VENDOR's preliminary drawing and document list provided in our quotation.

PETROBRAS: Deviation disregarded. List not received. VENDOR: Please find attached standard D&D list. [Annex 800-01, for PETROBRAS eyes only.] PETROBRAS: Noted.

Closed 800

51

Installation manual. VENDOR: A separate Installation Manual is supplied. The Installation Manual covers generally valid information about mobilization and preparation of the jobsite and erection/ assembly of the machine unit. Erection procedures are not submitted by VENDOR if erection is carried out or supervised by VENDOR. In these cases, all required instructions are given by VENDOR erection personnel.

PETROBRAS: Erection procedures shall always be provided. VENDOR #300: Agreed with PETROBRAS. PETROBRAS: VENDOR #400 has not replied. Subject closed.

Closed 400

52

Operating and maintenance manual. VENDOR: The Operating and Maintenance Manual (VENDOR designation: "Operating Instructions") is supplied at the same time as the VENDOR machine unit.

PETROBRAS: Noted, considering this is the final revision with actual contents. However, previous revisions, with sample contents, shall be submitted for PETROBRAS review and comments during detailed design stage. VENDOR’s reply not received. Subject closed.

Closed 400

53

Technical data manual. VENDOR: A Technical Data Manual is not supplied by VENDOR. Documents a to f are part of other documentation.

PETROBRAS: Not acceptable. VENDOR’s reply not received. Subject closed.

Closed 400

Item Annex 2D – Inspector’s check list PRELIMIN

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-

VENDOR: Clarification: VENDOR reserves the right to furnish data and limit customer inspections to those items mutually agreed upon by the Purchaser and the VENDOR during the Pre-inspection Meeting.

PETROBRAS: Not acceptable. Any discussions to be held before the purchase order, PIM contents to fully comply with what has been specified and agreed for that particular job. VENDOR: Noted. PETROBRAS: Noted.

Closed 800

- VENDOR: Exception: In lieu of Annex 2D, please refer to VENDOR's preliminary inspection and test plan provided in our quotation.

PETROBRAS: This is a vague statement. Deviations shall be clearly stated case by case, item by item, and submitted for PETROBRAS review and approval during bid stage. VENDOR: Please find our standard ITP. [Annex 800-02, for PETROBRAS eyes only.] PETROBRAS: PETROBRAS considered so far the provided ITP not complete. Please provide further details for next edition of this document.

Closed 800

Item NI-2626 data sheet

-

Individual stage drains required. VENDOR: Common stage drain for complete dranage is provided for barrel type compressor.


Closed 500

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Baseplates furnished by contractor. Compressor, driver, gear. VENDOR: Baseplate arrangement will be decided on a project-by-project basis.


Closed 500

-

Extent of process piping by vendor shop fit up of vendor process piping. VENDOR: Process piping should be provided by the purchaser.


Closed 500

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-

Field evaluation test. VENDOR: VENDOR dispatches a supervisor for this field evaluation test.

PETROBRAS: Noted. VENDOR #500: Noted, as option per diem rate. VENDOR #300: Agreed with VENDOR. PETROBRAS: Noted.

Closed 500

Page 28, line 55

Boroscopic inspection ports. VENDOR: Additional ports on compressor casing which are only determined for boroscopic inspection could not be supplied due to space limitations. VENDORs philosophy is to use given main and auxiliary compressor openings such as process, balance line, seal gas extraction etc. potential ports for boroscopic inspection.


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Page 30, line 13

Shaft end seal inspection. VENDOR: The inspection of the shaft end seal after the compressor test run shall not be done. Besides a significant influence on the delivery time and the necessary efforts of this test, VENDOR do not recommend to change the already tested and approved compressor set-up after the testing. The seal integrity and inspection test will be done at the workshop of the OEM after the testing on OEMs test stand.

PETROBRAS: Shaft end seal shall be inspected as required. VENDOR #400: See comment on para. 7.3.1.2.b. VENDOR #300: Appearance of DGS cartridge can be inspected. (DGS cartridge will not be disassembled.) PETROBRAS: VENDOR #300’s comment noted. Regarding VENDOR #400’s comment: (a) Refer to PETROBRAS comment on paragraph 7.3.1.2.b (NI-

2626). (b) In case leakage rates during GLT remain within OEM

specified parameters, no further action will be required. (c) In case of excessive leakage seals shall be returned to OEM

for repair. Subject closed.

Closed 400

Page 30, line 14

Gas leak test at discharge press VENDOR: A gas leak test at discharge pressure will not be done because of the design pressure of affected sub-systems such as the dry gas seal and systems piping. The assembled compressor gas leak test will be done at settle out pressure.

PETROBRAS: GLT shall be performed as required. VENDOR #400: See comment on para. 7.3.1.2.b. VENDOR #300: In this case design pressure of DGS cartridge need to be changed to compressor discharge pressure. PETROBRAS: VENDOR #300’s comment disregarded. VENDOR #400’s comment disregarded. PETROBRAS re-states comment above. According to API Std 617, MAWP, settle-out pressure, and maximum sealing pressure, whichever is greater, shall apply. Subject closed.

Closed 400

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Page 30, line 17

After gas leakage test. VENDOR: A post test internal inspection of the compressor after the test run will not be done. For reason see point comment to page 9 Line 14 - Inspection of shaft end seal after compressor test.

PETROBRAS: Shaft end seal shall be inspected as required. VENDOR #400: The merits of post-test inspection of compressor internals are in no comparison to the benefits of shipping a unit with proven mechanical assembly and casing joint integrity. Therefore a post-test inspection of the compressor internals will not be done. VENDOR #300: Appearance of DGS cartridge can be inspected. (DGS cartridge will not be disassembled.) PETROBRAS: VENDOR #300’s comment noted. Regarding VENDOR #400’s comment: (a) Refer to PETROBRAS comment on paragraph 7.3.1.2.b (NI-

2626). (b) In case leakage rates during GLT remain within OEM

specified parameters, no further action will be required. (c) In case of excessive leakage seals shall be returned to OEM

for repair. Subject closed.

Closed 400

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GENERAL INFORMATIONS

1. PURPOSE

This technical specification provides PETROBRAS’ unified replies and interpretation to vendors’ comments and alternate technical solutions regarding API Standard 617 and PETROBRAS NI-2626 for centrifugal compressors manufactured according to API Standard 617.

2. UPDATING

This specification shall be revised at least every two years. There shall be updating newsletters every six months, if required.

3. DEFINITIONS

• Deviation: alternate technical solution proposed by a vendor for a given standard or specification requirement.

• Exception: noncompliance with a given standard or specification requirement.

• Gas transportation service: refers to family number 98,008,584 as defined by I-ET-0000.00-0000-321-PPM-001.

• PETROBRAS’ comment: clarification or interpretation from PETROBRAS concerning a given standard or specification requirement.

4. SCOPE

This technical specification is based on API Std 617, 7th edition, and PETROBRAS NI-2626, revision B. It is written only in English.

This technical specification applies only to centrifugal compressor packages manufactured according to API Std 617, 7th edition, July 2002 – chapters 1 and 2.

5. WORKING GROUP

• Working Group constituted by memorandum MATERIAIS/OGBS/PDR 10/2012; and modified by memoranda MATERIAIS/OGBS/PDR 13/2012, MATERIAIS/OGBS/PDR 4/2014, and MATERIAIS/OGBS/PDR 5/2014.

• Responsible engineer: Alexandre Domingues Müller de Campos, Downstream Basic Design.

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6. REFERENCE DOCUMENTS

• API Std 617, 7th edition – Axial and centrifugal compressors and expander-compressors for petroleum, chemical and gas industry services.

• PETROBRAS NI-2626, revision B – Axial and centrifugal compressors and expander-compressors.

7. REMARKS

• The information contained in this document is PETROBRAS property and may not be used for any purpose other than those specifically indicated herein.

8. REVISIONS

• 0 – Original issue.

Revision 0 A B C D E F G

Date 26/09/2014

Project OGBS/PDR

Execution T. MELLO

Check R. TREMPER

Approval A. MÜLLER

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