ML20129E410

Jackson Pump,Auxiliary Feed Pump P 14-2

ML20129E410
Person / Time
Site:	Davis Besse
Issue date:	09/04/1984
From:	TERRY CORP.
To:
References
PROC-840904, NUDOCS 8507300306
Download: ML20129E410 (61)

Text

{{#Wiki_filter:_ ib i TERRY CORPORATION pg INFORMATION ONLY THIS MANUAL HAS BSEN ASSEMBLED FOR THE EQUIPMENT USTED BELOW: BYRON JACKSON FOMP OIVISION V-147411 (R-1091N) 9-4-84 JOB NO: ^ CLEVELAND ELECTRIC /72/cuc cinEn LOCAil0N: DAVIS BESSE SERVICE: gJ pUHp ,ja, 7cca 2.mjpf r / W 2. NM ITEM N0'S: WORKS FILE N0: WF-37686AB Inlet Temp. 590*F Exhaust Press. 3 PSIG Max. Steam 1170 PSIG_ inlet Press. 885 PSIG Exhaust Temp. 243*F Low Steam 50 PSIG TYPE SERIAL NO: SERIAL NO: fi dM NO-BHP KW RPM Turbine i Gear TURBINE GEAR GS-2N T-37686-A 800 3600 GS-2N lT-37686-B 800 3600 l l l l l NOTICE This instructen manual or any reproducten of it shall nct t)e used for manufacture, producten or procure-ment ethout the express wntten permissen of the Terry Corporaton or one of its subscanes. Use in a normal manner associated eth goods cr sennce furnished of tendered by the Te'ry Corporaton or one of its subscanes, is approved. Where references to " SAFETY" acpear in this instructen manual permission is given for its reproducten proveng, that only that part of the text of cCntext is used in the interests of SJfety for the purchaser's use. 8507300306 040904 PDR ADOCK 05000346 P ppg olTP. Rev. 2,82 g, p u n T-,y c g g g g e

r. BYRON JACKSON / TERRY T11RBENE 12501-M-36AQ-8-1 E c.nc.a Y.e M. 1. tugent th4V pe0Casp. S. WW AND tenuestf. tygg MAY #80Caen suaseCT TO Tm OF CMAfeOS a O mves ANo anuawe. WOER MAY NOf PROM, 4 0 arvow er neouseo. Woes MAy peocggg, MilllON TO PeOCIIO 000 MfMt 000% NOT Rtti tite peou #ULL COMPilA P O iCONta ACT SPtCW 8 tsIY bf S ISSUE / REVISION 1 Issued for FCR 83-136 " Change-out of PG-PL gov. to PCG gov." Revision 2 u. J

CALnON NOTICE This turbine has been designed to provide safe and reliable service within the designed specifications. It is a pressure containing piece of rotating machinery; therefore, good judgement and proper safety practices to avoid damage to the equipment and surroundings and serious or painful

injuries, must be exercised by responsible and qualified personnel.

The responsibility for correct operation, maintenance and training of personnel is that of the owner but. the following "Do NOT" and "Do" items are given. DO NOT.. Use unauthorized parts or repairs. Use of

parts, other than as manufactured or authorized for use by Terry or repairs performed by others not authorized by Terry to be so performed, will void any outstanding warranty on Terry equipment and will further relieve Terry of any liability for injury or damages resulting therefrom.

DO NOT.. Attempt to operate if installation is not correct' and/or pre-operation (static) safety and control features have not been checked anS verified. DO NOT., Attempt to operate until you have a thorough knowledge of the steam supply and exhaust system, its associated valves and drain system and the correct procedure for warming through and draining the system before starting the turbine. DO NOT.. Attempt to operate until you have a thorough knowledge of the function and operation of the turbine control

system, lubrication system, turbine drain and gland seal systems, safety devices and emergency operational procedures, mechanical and/or electrical.

DO NOT.. Attempt to operate, adjust, disassemble the turbine or its associated equipment until you have a thorough knowledge of the manufacturers instructions. DO NOT.. Wear neckties or loose clothing when standing near couplings or any rotating parts. DO NOT.. Remove any inspection covern or guards when the unit is it operation. DO NOT.. Open up bearings, oil reservoirs or lube system until is sufficiently cooled. TERRY CORPORAT!0N REV 3-78

8 i 5 i i CAUTIQW NOTICES CONTINUED.... i I 2 DO NOT.. Use the turbine casing eye bolt for litting the i turbine. Rig suitable slings for lifting. t j DO NOT.. Attempt repairs of a questionable nature. l l i j D0...... Consult the manuf acturer should any problems arise or j are foreseeable. D0...... After starting. test and verify the correct function j of the overspeed device (mechanical / electrical) before putting the unit into service. Refer to the l manufacturers instructions for the correct procedure. l t D0...... After starting and verification of overspeed device. I test and verify the correct function of the governor ) or control system through its range before putting l i unit into service. i L l D0...... Af ter starting, check and verify that the lubrication system has sufficient oil and is operating i satisfactorily. l g; D0...... Avoid personal contact with the turbine casing. valve I

bodies, drains and steam lines.

Serious burns may l j result. Near protective clothing and develop safety ( awareness. j l D0...... Ensure that the lifting devices used have been i l regularly tested and have a sufficient safety factor i j for the weight to be lifted. Also ensure that lifting j devices are properly secured before any lifting is l done. 6 l l D0...... Ensure all steam and exhaust lines are completely i drained and isolated and all turbine drains open before attempting to work on the turbine. j i l D0...... Fit spades. blinds or blank flanges of aufficient l 1 design to withstand full line steam pressure in the I inlet and eshaust lines if the turbine is to be t i dissantled. i i D0...... protect against possible head and hearing injury by i wearing the application protective equipment. I e 1 t 4 r Tsaay compotATIoN I ' l } REv 3-7e 4 i, l , - - -... - _ - - -, -, -, - ~ _.. _. - -,. - _

SECTION 1 - INTRODUCTION This instruction manual has been prepared for the equipment described on the title page and is intended as an aid to supplement the experience and ability of qualified personnel in the installation, operation and maintenance of rotating equipment and its associated auxiliaries and controls. The instructions contained in this manual do not purport to cover all details nor provide for every possible contingency to be met in connection with installation, operation or maintenance. The supplying of instructions does not imply in any manner or to be construed that, the Terry Corporation accepts liability for work carried out by a customer or contractors personnel. Liability is limited to and as stated in our warranty. Should further information be desired or should particular problems arise which are not covered sufficiently for the purchaser's

purposes, the matter should be referred to The Terry Steam Turbine Company.

Please address any inquiries to the attention of the Service Manager. The Terry Corporation, P.O. Box 555.

Windsor, Connecticut 06095.

Consultation: Our Engineering Department welcomes inquiries regarding any phase of steam turbine practice, installation, operation or design changes to meet special conditions. Inspection: Your TERRY equipment can be expected to operate successfully for years without much special attention: however, periodic inspection of vital parts can greatly help in avoiding unscheduled shutdowns. If you will write us fully about any trouble or unusual wear, we will be pleased to offer our help in their solution. Gervice: We maintain a force of trained engineers and service representatives, skilled in turbine work, who are available for installation, inspection or overhaul of TERRY equipment. They can be secured on reasonable notice. A charge at a daily or hourly rate while away f rom our Plants, plus expenses, with an extra charge for overtime, is made for their services. We will be glad to supply you with our current rates for these servicos, TERRY CORPORATION 1-1

SECTION 1 INTRODUCTION CONT'D.... 1 The proper ezection and starting of any turbine or gear is highly important. The success of a unit frequently hinges on l how it is installed. We strongly urge that such work be supervised by skilled personnel thoroughly familiar with steam turbine work. Unless you have men available with propet experience and ability, it would be advisable to employ our service representatives. These men can instruct the operators in the care and handling of the units. Many companies, especially those operating several TERRY units have our service representatives make periodic inspection to forestall trouble and to insure that best possible results. Our personnel can explain how to operate TERRY equipment to secure the greatest usefulness and economy, and the longest life. When requesting for the services of a service representative or an engineer, be sure to give us the equipment serial number with full particulars as to what new parts are, or may be, needed. This will enable us to instruct our personnel for the work required. If possible have these parts on hand. If the trouble involves apparatus other than that of Terry a manufacture, such as generators,

pumps, blowers, governors.

[ etc., we recommend that any such work be done by the manufacturer of this equipment. Our personnel are instructed that they must secure authorization from our factory before under-taking work on any apparatus not manufactured by us. Shipment: After final completion of test and inspection the oil is drained from the unit and the reservoir and sumps are cleaned. All exterior machined and exposed surfaces are coated with a rust preventative. The interior of the turbine is sprayed through all available openings with a suitable rust preventative. All tapped pipe connections are plugged and flanged pipe connections are covered with wood or metal enclosures and all exterior parts of the unit coated with shop paints or such paints and procedures specified by the buyer. Turbines and gears are shipped mounted on skids and enclosed in open frame work crating as required by the transporation company for domestic shipments. When boxed for export, the l unit is packed in a totally enclosed box. Receiving Shipment: Immediately upon receipt of

shipment, check the items received against those shown on the packing list.

l TERRY CORPORATION l 1-2 l

1 SECTION 1 INTRODUCTION CONT'D.... Care should be used when opening up a crate for inspection and checking for damage and shortage. Check the bottom of the crate because some

parts, such as loose

piping, trip and throttle valve, coupling halves, coupling guards, are attached to the bottom of the crate.

Any claims for shortages or damages suffered in transit shall be submitted by the receiver directly to the carrier and a copy of the report forwarded to The Terry Steam Turbine Company within ten (10) days after receipt. Storage: On completion of receiving inspection, action must be taken to protect the equipment if it is not to be installed immediately. The unit should be kept in its crate and attached to the skid until ready to install on its foundation. The equipment should at all times be stored in a

clean, non-corrosive atmosphere and protected against loss, weather, damage and foreign materials such as dust, sand, etc.

Indoor storage where constant temperature is maintained at a level which will prevent condensation is preferred. Should preparation for additional protection be required for adverse conditions or for an extended period of time it is recommended that The Terry Steam Turbine Company be consulted. For outdoor storage or in areas with a corrosive atmosphere, additional protection is usually necessary. The standard preservation procedure applied by Terry is for 18 (eighteen) months under indoor storage conditions. NOTE: The purchaser shall be responsible for all expenses related to returning the unit to original factory condition including the services of a Terry + engineer or service representative. TERRY CORPORATION 1-3

INTRODUCTION CONT'D.... SECTION 1 WARRANTY Our Standard Warranty Clause is as follows: "The company warrants that the equipment manufactured by it and delivered hereunder will be free of defects in material and workmanship for a period of twelve months from the date of placing the equipment in operation or eighteen months from the date of

shipment, whichever shall first occur.

Should any failure to conform to this Warranty be reported in writing to the Company within said

period, the Company shall, as its option, correct such nonconformity, by suitable repair to such equipment or, furnish a

repicement part F.O.B. point of

shipment, provided the Purchaser has

stored, installed, maintained and operated such equipment in accordance with good industry practices and has complied with specific recommendations of the Company.

Accessories or equipment furnished by the Company, but manufactured by others, shall carry whatever warranty the manufacturers have conveyed to the Company and which can be passed on to the Purchaser. Ths Company shall not be liable for any repairs, replacements, or adjustments to the equipment or any costs of labor performed by the Purchaser or others without the Company's prior written approval. l The effects of corrosion, erosion an normal wear and tear are specifically excluded from the Company's Warranty. Performance warranties are limited to those specifically stated within the Company's proposal. Unless responsibility for meeting such Performance warranties are limited to specified shop or field

tests, the Company's obiligation shall be to correct in the manner and for the period of time provided above.

THE COMPANY MAKES NOT OTHER WARRANTLY OR REPRESENTATION OF ANY KIND WHATSOEVER, EXPRESSED OR IMPLIED, EXCEPT THAT OI' TITLE, AND ALL IMPLIZD WARRANTIES, INCLUDING ANY WARRANTY OF MERCHANTABILITY-AND FITNESS FOR A PARTICULAR

PURPOSE, ARE HEREBY DISCLAIMED.

Correction by the Company of nonconformities whether patent or

latent, in the manner and for the period of time provided above, shall constitute fullfillment of all liabilities of the Company for such nonformities, whether based on

contract, warranty, negligence, indemnity, strict liability or otherwise with respect to or arising out of such equipment."

l The rights and obiligations of Purchaser and Company shall be governed by the laws of the State of Connecticut. TERRY CORPORATION 1-4

GiTDEiv 2 34 TERRY TURBlNE DATA SHEET sttAM RATE sitAM RATE CPERATING SPEED OPERATING CONDITIONS wP aw RPM 18/NP/H4 (84 W/N4 AANGE R P M nArto 800 3600 41.0 1100-3710 %CRMAL PART LOAD OvtRt0A3 L0w STEAM !st CRITICAL sPEIO RPM 2nd cRITICAt sPtt0 RPM TRIP SPEED 4500 RPM STEAM /EAS CONDITIONS mtEr sitAu/c11 NcRu 885 esm 590'm. uAx mit 1170 , sis 600Wun air 50 PsiG 281 'in 3 , sis /M243 *str Exhaust sttAM NCRM sitau RArt GUARANTEE rant, *P/M 800 sitAu 885 Ps,G. ExH 14_3_*rrite inP.E nR U FUtt LOAD Exhaust TEMP 243'FTT. uAx casing press 165 , sis. stNTINEL REUEF VALVI stTTING PsiG 30 TURBINE CONNECTIONS s:Zr RAtNG FLANGE FAtt PCslTION mtti 4" 900# ASA RF RH FACING COUPLIIIG Exxaust 5" 3Cf w ASA JF LH FACING COUPLING Phr. CONSTRUCTION FEATURES Co}OO FaAMICeslGNAnCN TYPE GS-2N HORIZONTAL D Riicat Y cAsiss spur HORIZONTAL

Ers/saxxixsP, cit =(PosliiaNs 1 Thrnoch 10 sitA u n o w HFITCAL-SQLID No atissautas 10 NO OF V,HEtts I

OlAMETERs 480 stAsts N/A No NcZZtt GROUPS N/A stA:ts N/A 40 m EAcH GRour N/A RatcR ccmst. RifflT tip Hamo vAtyts _N/A sTtAM CHEST N/A Ny_posificNs N/A sitau amG YES RoiAnam FAclNG cCUPllNG COUNTERCLOCKWISE atTs YES CAsWG SUPPORT - FOOT Nozztt stocx N/A sEARmGs (RatoR) Raa:At nPE SLEEVE BALL rwRust REV. CH AMBERS YES LueRicAnom RING Enou TURBINE RArtiu N/A cVERsPitD TRIP MECH. DISC rRiP vatvt T&T mitRsTAGE stats N/A T&TvAtyt HYD. MANUAL TRIP MECH. MANUAL MANu, GIMPEL END GtAND seats CARROM etAND stAL sYsitM PRESS. LEAKOFF t ,,,,,,,,,,,,,,,,,.,cuac,.,,,,,,,,,,,,,,,,,,,,not,,,,,,,,,,1.,,,,,,,,,,,,c,s aceton' 2 car at tw, n,*r nano sio, nn,e sacas tw sitam *nc ce s'tav cntst room r*, n psm, errn reissens too n GCvfRNCR TYPE MECH. HYD. ccVPUNG sUPPut0 BY OTHERS SINGLE EM covtRNcR vatvEs couPuNG rYPt DIRECT OTHERS .ruancN sAst nPE TURBINE NO WOODWARD OTHER T-37686 AB GOVERNCR MANUF sAst tocAncN l ucca PGG 787480 auruht NuustR D Mc:A ctAss @ 1984 TERRY CORPORAT10:1

{ TERRY STEAM TURBINE CO. - e.. s.c.;. s:sc. =ss,= cm.. Allowable Forces and Moments-Nema Standards Vertical Right angle to if turbine shaf t Lbs ( 1.m...~ Fy My (b y/ F // Fx Parallel to ff g turbine shaf t y g \\.s Mz Mx I .W.... INLET p, Lbs l ,,Q3,3,, Z+ F Lbs / Lb Ft . 1M6... M EXHAUST .. 7,000, p M / Lb Ft 3913 COMBINED AT EXHAUST Max. Combined Fx = 782 Fy = 1956 p, 1564 when M = o Forces & Moments at Exhaust Mx = 3913 uy=1956 y2, 1956 When F = 0 Allowed Forces (F) & Moments (M) Ref: NEMA Std. Pubn. No. SM 23-1979. Sect. 8 06 GS-2N SerialNo:T 37686AB intet: 4" In. Exhaust: 8" In. Turbine Type: i wo224 Prepared by: Richard S. Golas Date: 9-4-84 RM80 g ggg4 7gg;;y C3 ?CRATi0n j

SIZE-IN INLET EXHAUST COMBINED AT 90F EXHAUST INLET EXHAUST Fmax Mmax Fmax Mmax Fman Mmax Fx F Fg Mx M Mg y y 2 4 333 1000 666 2000 559 1118 224 559 447 1118 559 559 6 333 1000 1000 3000 791 1581 316 791 632 1581 791 791 8 333 1000 1333 4000 1031 2062 412 1031 825 2062 1031 1031 10 333 1000 1444 4333 1175 2350 470 1175 940 2350 1175 1175 12 333 1000 1555 4667 1257 2514 503 1257 1006 2514 1257 1257 14 333 1000 1666 5000 1339 2679 536 1339 1071 2679 1339 1339 18 333 1000 1889 5667 1504 3009 602 1505 1204 3009 1505 1505 20 333 1000 2000 6000 1587 3175 635 1587 1270 3175 1587 1587 24 333 1000 2222 6667 1753 3507 701 1753 1403 3507 1753 1753 30 333 1000 2555 7667 2003 4006 801 2003 1602 4006 2003 2003 36 333 1000 2889 8667 2252 4505 901 2252 1802 4505 2252 2252 3 4 500 1500 666 2000 625 1250 250 625 500 1250 625 625 6 500 1500 1000 3000 838 1677 335 839 671 1677 839 839 8 500 1500 1333 4000 1068 2136 427 1068 854 2136 1068 1068 to 500 1500 1444 4333 1185 2370 474 1185 948 2370 1185 1185 12 500 1500 1555 4667 1265 2531 506 1265 1012 2531 1265 1265 14 500 1500 1666 5000 1346 2693 539 1347 1077 2693 1347 1347 18 500 1500 1889 5667 1510 3021 604 1510 1208 3021 1510 1510 20 500 1500 2000 6000 1592 3185 637 1593 1274 3185 1593 1593 24 500 1500 2222 6667 1758 3516 703 1758 1406 3516 1758 1758 30 500 1500 2555 7667 2006 4012 802 2006 1605 '4012 2006 2006 36 500 1500 2889 8667 2225 4510 902 2255 1804 4510 2255 2255 i 4 6 666 2000 1000 3000 901 1803 361 901 721 1803 901 901 8 666 2000 1333 4000 1118 2236 447 1118 894 2236 1118 1118 10 666 2000 1444 4333 1199 2398 480 1199 959 2398 1199 1199 12 666 2000 1555 4667 1277 2554 511 1277 1022 2554 1277 1277 14 666 2000 1666 5000 1356 2713 543 1357 1085 2713 1357 1357 18 666 2000 1889 5667 1518 3037 607 1518

• 215 3037 1518 1518 20 666 2000 2000 6000 1600 3200 640 1600 1280 3200 1600 1600 24 666 2000 2222 6667 1764 3528 706 1764 1411 3528 1764 1764 30 6E6 2000 2555 7667 2011 4022 804 2011 1609 4022 2011 2011 36 666 2000 2889 8667 2259 4518 904 2259 1807 4518 2259 2259 6

8 1000 3000 1333 4000 1166 2333 467 1167 933 2333 1167 1167 10 1000 3000 1444 4333 1236 2472 494 1236 989 2472 1236 1236 12 1000 3000 1555 4667 1309 2618 524 1309 1047 2618 1309 1309 14 1000 3000 1666 5000 1384 2769 554 1385 1108 2769 1385 1385 18 1000 3000 1889 5667 1540 3081 616 1541 1232 3081 1541 1541 20 1000 3000 2000 6000 1620 3240 648 1620 1296 3240 1620 1620 24 1000 3000 2222 6667 1781 3562 712 1781 1425 3562 1781 1781 30 1000 3000 2555 7667 2025 4050 810 2025 1620 4050 2025 2025 36 100 3000 2889 8667 2270 4541 908 2271 1817 4541 2271 2271 8 10 10 1 4000 1444 4333 1288 2576 513 1284 1027 2567 1284 1284 12 1: 3 4000 1555 4667 1351 2702 540 1351 1081 2702 1351 1351 14 ! 1: 3 4000 1666 5000 1422 2844 569 1422 1138 2844 1422 1422 1:{3 3 4000 1889 5667 1571 3142 628 1571 1257 3142 1571 1571 18 1:3 4000 2000 6000 1647 3295 659 1648 1318 3295 1648 1648 20 24 1$3 4000 2222 6667 1804 3608 722 1804 1443 3608 1804 1804 30 1 #33 4000 2555 7667 2043 4087 818 2044 1635 4087 2044 2044 36 1533 4000 2889 8667 2286 4573 915 2287 1829 4573 2287 2287 10 12 1444 4333 1555 4667 1401 2802 560 1401 1121 2802 1401 1401 14 1444 4333 1666 5000 1467 2934 587 1467 1174 2934 1467 1467 18 1444 -4333 1889 5667 1608 3216 643 1608 1286 3216 1608 1608 20 1445 4333 2000 6000 1682 3364 673 1682 1345 3364 1682 1682 24 1444 4333 2333 7000 1910 3821 764 1911 1529 3821 1911 1911 30 1444 4333 2555 7667 2067 4135 827 2068 1654 4135 2068 2068 36 1444 4333 2889 8667 2307 4614 923 2307 1845 4614 2307 2307 NOTE: ALL FORCES ARE GIVEN IN LBS. ALL MOMENTS ARE GIVEN IN FT LB.

GOVERNOR SETTING WITH WOODWARD eOVERNOR - CAM OPERATED TURBINE NO. Rio'll N TYPE G S-Z u" FILE 37686AB H.P. 800 R. P. M. 3600 VALVE SIZE 3" venrugi DRIVE GEAR RATl03 - l EMERG. TRIP SPEED 4-Soo i

TERMINAL SHAFT. TOTAL ~AVAILABLE HIGH SPEED STOP SET AT3710 TURB. RPM &l2%.7 GOV. RPM

' ANGULAR TRAVEL 3o* EFFECTIVE l ANGUL AR TRAVEL 21 *- 3 6' hPPROX VALVE TRAVEL. 6/s CALCULATED TURB. AIR WOODWARD i VALVE GOV. F66 WOODWAR_D. OPENING R. P. M. y GOVERNOR MAX. ,c; 3Wo 1236.l PER. l! TERRY ' PART No, 728.7 Z7AO / E'-g L 2. " $7' 3600 lloo ni f' //oo 366.7 ~I N0R AL R t i O'Slr \\ fs'k) o CAM 4r _ __

1. WITH VALVE A6 OPEN, SET LEVER Li HORIZON-i j:

ROLLER TAL. CAM PLATE SHOULD BE IN MID-POSITION. 6 M VALVE,

2. WITH VALVE CLOSED, ADJUST CAM ROLLER ON

'i STEM SO THAT IT IS JUST 1/16 OFF OF i p j i: BOTTOM STOP. i' Ri

3. ADJUST CONNECTING RODASO THAT TERMINAL NbTES:

SHAFT LEVER Lt IS IN MID-STROKE POSITION gov. 1.EVEA Layout L.-- Z 3 8 2 AND"lS PARALLECTol.~60Vi~ VALVE LEVE8 L3 I FIGURED BY 'P# LEVER DIAGRAM -u-r+ g gggjg-CHECKED BY +A F-THE TERRY STEAM TURBINE CO. i gg j .R - /o ? /N i j I

l l SECTION 2 - TECHNICAL DATA i Recommended Turbine Steam Joint Compounds i 1. The following sealing materials aie recommended for use within the temperature limits and turbine areas specified: 2. Applicable Turbine Joint Areas ] e Case horizontal joint e Case vertical joints .e Steam ring or steam chest joint to case horizontal or vertical joint, as applicable i e Gland case to turbine case joint (s) i e Steam chest cover to steam chest joint e Nozzle block to steam chest joint (s) 3. Sealina Materials and Limits All turbine bolted joints which require use of a sealant material to ensure a leakproof joint shall employ the following sealants for flanges exposed to the temperatures listed. Temperatures to be based on inlet steam conditions for the entire flange. The following sealing materials shall be utilized for " RIGID FLANGE DESIGNS": 0 0 e RTV 732 Black: Below 500 F (260 c) 0 0 0 0 e Turbo "R": 500 F (260 c) to 750 F (399 c).. inclusive 0 0 e Alinco: Above 750 F (399 c) FLEXIBLE FLANGE DESIGNS shall use the following: I e RTV 732 Black: Below 500 F (260 c) 0 0 0 0 e TEMP-TITE String Kit: 500 F (260 c)-and above SPECIAL CUSTOMER MANDATE: Shall_ include applications where customer requirements dictate the use of ALINCO (triple boiled linseed oil). l NOTE: THIS SEALANT MUST BE HEAT CURED AFTER ASSEMBLY. j TYPE GS-NUCLEAR TURBINES: On case horizontal joint and on gland case joints to turbine case shall utilize the following: { e TEMP-TITE STRING KIT ONLY TERRY CORPORATION Section 2 REV. 3-81 2-1 - -.- -..,- - -,-,.. -.., - -,.. _ ~ -. -, - -,.. - - -

l RECOMMENDED TURBINE STEAM JOINT COMPOUNDS CONTINUED.... FIELD CHANGES: Should repair and/or maintenance become necessary, the following sealing materials shall be substituted for all field units where string-type casing staan joints were previously used: o TEMP-TITE STRING KIT: String Gasket in Turbo Seal 50 4. Turbine Component Joints (Other Than Case) COPALITITE: Shall be used, unless otherwise specified, for components which shall include but may not be limited to the following: j e Steam ring or steam chest plug (s) 4 e e Jet bodies and/or dummy jet bodies e L - Gland stem packing bonnet e Hand valve bonnet (s), body (bodies) i e Nozzle block (s) using asbestos gasket e Valve cage (after lapping to valve body) HO_J1: Copaltite shall not be.used for main case joints j covered in " Applicable Turbine Joint Areas". 5. Lube Oil Joints l i j Horizontal split and vertical flange of bearing housing, i if applicable, shall utilize the following sealing material: 4 o PERMATEX #2 6. Procedure and Materials 6.1 RTV 732 Black (Manufactured by Dow Corning Corp., i Midland, MI 48640) (Shelf life: 1 year) e Apply a continuous bead (s) to. sealing surface. Assemble joint. No special precautions for cure are required - assembled unit is suitable for steam service in four (4) hours. Assembly with this sealant must proceed as quickly as possible before the sealant cures ) and forms a rubber gasket. 6.2 ' Turbo "R" -(Manufactured by Industrial Gasket and Shim .Co., Inc., P.O. Box 368, Meadow Lands, PA 15347) l (Shelf life of 1 year UNUSED MATERIAL MUST BE KEPT l TIGHTLY COVEREDl). TERRY CORPORATION i Section 2 REV. 3-81 2-2 t 3 -..._.- -, _ - ~....-. .~. ,...~.,,-....._,,,,,.,,-.,-,,,~..%, ,-_w- .,-,_.--m._

RECOMMENDED TURBINE STEAM JOINT COMPOUNDS CONTINUED.... o Apply uniformly on sealing surface to cover with a minimum layer of sealant. Spray Turbo "R" film with chemical catalyst (2 percent solution) furnished. A

fine, uniform spray which completely wets exposed sealant is required.

Assemble joint. o Curing time used is 24 hours at room temperature. If necessary turbine may be subjected to steam cervice after 4 hours provided elevated temperature is present at low steam pressures. e If " catalyst" is not available, cure may be promoted by application of heat. Flange (s) must be held at a 0 0 temperature of 300 F. (149 c),

minimum, for a

period of one hour. During cure, internal pressure must be as practicable. (NOTE: Saturation pressure for 0 0 300 F. (149 c.) is 65 PSIG). 6.3 Temp-Tite Strina Kit String Ga s',e t in Turbo Seal 50 (Manufactured by Industrial Gasket and Shim Co., 200 Country Club Road, P.O. Box 368, Meadow Lands, PA 15347) (Shelf life of 6 months - UNUSED MATERIAL MUST BE KEPT TIGHTLY COVERED 1). e Place a continuous run of Temp-Tite string on sealing surface using Turbo "R" as an adhesive. Assemble joint. No special precautions for cure are required assembled unit is suitable for immediate steam service. 6.4 Wheeler's Alinco Compound - (Triple boiled linseed oil Manufactured by Wheeler's Paint Inc., 502 East Ohio

Street, Pittsburg, PA 15212

- may be available from " industrial suppliers"). e This sealant must be heat cured after assembly! e Apply uniformly on sealing surface to cover with minimum layer of sealant. Assemble joint. e Cure must be accomplished by heating flange (s) to 0 0 approximately 400 F. (204 c.) and held at this temperature for 2 hours. During cure, internal pressure must be as low as practical. Some insulation is advisable to minimize heat loss during curing. Flange temperature should be monitored by thermocouple py'rometer, or other suitable method. TERRY CORPORATION Section 2 REV. 3-81 2-3

. =. _ _ _ _ -.-. - ~_ 1 RECOMMENDED TURBINE STEAM JOINT COMPOUNDS CONTINUED.... l 6.5 Copaltite (Manufactured by National Engineering l

Products, Inc.,

15th and New York

Avenues, N.W.,

i Washington, D.C. 20005). e Apply a thin, uniform layer to cover sealing surfaces. Assemble joint. No special precautions for cure are 4 required - assembled unit is suitable for steam service in 4 hours. t 6.6 Pernatex #2 (Manufactured by Permater Co., Inc., 2300 N. Florida Mango

Road, P.O.

Box

1350, W.

Palm Beach, Florida 33401 - may be available only from " industrial suppliers"). i j e Apply with fingers. Do not exceed a thickness of 0.015" 'j (0.4 mm) when applying. I l i i TERRY CORPORATION Section 2 REV. 3-81 t 2-4 =

IMPORTANT NOTICE FOR UNITS WITH BASEPLATES READ CAREFULLY BEFORE GROUTING This unit has been carefully aligned and doweled at the factory prior to shipment. All baseplates deflect to some extent; therefore, original alignment must be reestablished BEFORE unit is grouted in. Before grouting and with steam lines disconnected, proceed as follows: 1. Mount unit on foundation and support base on several metal wedges or blocks well distributed around edge of baseplate. Allow 0.5 to 1 inch between base and foundation for grouting. 2. Check-alignment. If incorrect, reestablish original alignment by shimming the blocks or adjusting the wedges until correct alignment is obtained. No redoweling is necessary. Since a baseplate will spring unless rigidly supported, I grouting must be done carefully and base completely filled with grout to maintain permanent alignment. TERRY CORPORATION Section 3 I .m

.Z INSTALLATION 1. FOUNDATION 1.1 The foundation is one of the most influential factors where overall reliability of a unit is concerned. A foundation must maintain alignment under all normal and abnormal conditions. The includes the way the foundation is supported on the soil and/or superstructure, equal deflections of all columns under load, soil settling and soil resonances, thermal distortion, piping forces vacuum pull or pressure forces in expansion joints. 1.2 The foundation must minimize vibration by being as heavy as possible and non-reasonant. It is important that the turbine be isolated from external vibration by providing an air gap filled with mastic sealer all around the slab and mat. 1.3 Provision in design must be adequate when a turbine unit is carried on steel work or other structure, as applied to foundations in soil. Structure must be stiff enough to prevent yielding or springing. The addition of a substantial concrete mat will minimize vibration. It is essential that no part of the foundation or structure is resonant within the operating speed range of the machine. 1.4 Vibration transmissions may be from the unit to the surroundings or vice-versa, and it may be aggravated by resonance at transmission frequencies, piping, stairwan, and ducts may also transmit vibration, which should .e prevented by proper isolation. 1.5 Certified general outline drawings are furnished with each order. Those drawings include dimensions for locating anchor

bolts, weight of each assembly and general information needed for determining foundation size and thickness.

1.6 A generous factor of safety should be used when determining foundation thickness. The foundation length and width should extend at least six inches (6") beyond the anchor bolts. TERRY CORPORATION l Section 3 REV. 2-82 l 3-1 { =_.

L, INSTALLATION CONTINUED.... 1.7 Anchor bolts must be positioned accurately and provided with sleeves (see figures 1 and 3). The sleeve bore diameter should be approximately twice the bolt diameter, but should provide not less than one half inch (1/2") clearance all around the bolt. 1.8 Carefully constructed templates are required to hold bolts and sleeves in position while foundation is cast. Templates are usually made of wood and secured to the foundation forms. Skilled craftsmen should be able to set anchor bolts to a tolerance of one-eight inch (1/8") by locating and drilling the holes in the templates after they have been secured to the braced forms. 1.9 The anchor bolts should be threaded at both ends and of sufficient length to extend one and one-half (1 1/2) to twice (2) the bolt diameter above the top of the securing holes in the base of the sole plate. The lower end of each bolt passes through an anchor plate and is secured by a nur and welded (see figure 1). 4 1.10 Anchor plates can be either standard cast iron washers or flat steel plates. They should have a diameter of approximately twice to two and a half times (2 to 2 1/2) l the outside diameter of the sleeves. l l NOTES: A. The templates must be rigid enough to prevent bolts from shifting while the concrete is being poured. B. After concrete has been poured and before it has

hardened, recheck the position of the i

anchor bolts. C. Allow one half (1/2") to one inch (l") gap above the top of the foundation surface for I grouting under the edge of base or sole plates. TERRY CORPORATION 1 Section 3 REV. 2-82 3-2

J -INSTALLATION CONTINUED.... 2. LEVELING 2.1 Sufficient. parallel machined bearing plates or chock blocks should be placed beneath soleplates or base and along the sides and ends to distribute the load evenly. 2.2 It is essential that they' are leveled before the 'soleplates or base are placed in position. For levelinq use an optical method or a level of a very high quality with a ground calibrated dial. Obtain an accurate condition of level lengthwise and crosswise. 2.3 Shins should be used to adjust height of sole plates or base to align turbine and driven equipment (see figures 1 & 2). Allowances must be made for the turbine horizontal centerline rise due to thermal expansion relative to that of the driven equipment (See Section 4 - ALIGNMENT). M i Shins supplied under turbine feet or i flexplate supports are not for initial installation alignment, but for final alignment after a " HOT RUN" check. 4 2.4 In an installation involving a gear drive between the driver-and driven unit, installation procedure should be i j to align the driver and driven unit to the gear to achieve minimum error. 2.5 When units are attached to a common base wedges or jacking bolts can be used to initially adjust alignment (See figure 2). 4 3. GROUTING I 3.1 The anchor bolts are used for hold down only. The grouting resists side thrust, end thrust, and compensates for the irregularities between f oundation and base, thus preventing turbine and driven unit or units from shifting. i TERRY CORPORATION I Section 3 REV. 2-82 3-3 l l

O, INSTALLATION CONTINUED,... 3.2 Terry recommends that all machinery bases be grouted. 4 This should provide structural damping along with uniform and continuous support, from machinery feet through base t grout to concrete foundation, of sufficient stiffness to l kept support resonances above operating speed range. To i achieve desired structural integration, non-shrink grout must be used exclusively, with an epoxy grout layer at grout-to-base-deck interface, for a high-strength bond. i The base itself must be regarded as a shell or form in i which grout hardens to a structural block which alone ) transmits machinery forces to underlying foundation. Internal base reinforcement furnished by Terry is limited i to that required to minimize base distortion during j shipment and setup. 2 3.3 Bases shall be provided with 6 inch (152mm) minimum diameter grout fill holes fitted with steel pipe sections which extend at least 0.5 inches (13mm) above deck surface. These fill boles are to be spaced so that every compartment within base structure may be immediately-accessible for placement of grout, but not less than one 2 (1) fill hole for every 16 square feet (1.5m ) of deck section. i 3.4 For every fill hole, two 2 inch (51mm) di.ameter vent holes shall also be provided, fitted with similar pipe sections. 0.5 inch (13mm) above deck surface. Vent holes are to be placed in corners where air is likely to be trapped. 1 3.5 Acceptable grouting materials are non-shrink, non-expanding, portland cement base

grout, and epoxy grout.

Both grouts may be extended up to fifty percent -(50%), with clean aggregate consistent with manufacturer's recommendations. A. Portland cement grout may be extended with coarse aggregate. 1 B. Epoxy grout may be extended with sand only. i l l TERRY CORPORATION l Section 3 REV. 2-82 l 3-4 i l c

f INSTALLATION CONTINUED.... 3.6 Grout must be mixed and placed according to the following procedure. The concrete foundation top surface must. be roughened,

cleaned, and moistened, but with no free i

i standing water. Steel surfaces in contact with grout I must be free of

rust, scale,

paint, and

grease, preferably by sandblasting.

Cement grout must be mixed j as " stiff" (minimum slump) as possible and rodded or vibrated into place to eliminate voids. Manufacturer's j maximum thickness per pour, cure time, and cure procedure are to be observed. Epoxy grout must be used in a liquid condition and poured in such quantity as to fill base to i top of protruding pipe sections above deck sheface. This i l provides-a liquid pressure head assuring a grout structure reasonably free of voids and air pockets which 2 maximizes structural integration and eliminates deck " drum head" offacts, i e 3.7 The najority of base cavity is to be filled with cement grout. Cement grout must be poured to a level no higher 2 than one inch (25mm) below deck surface. The top of base 1 cavity must be epoxy grouted. I NOTES: 4 i A. Allow grouting to set before tightening i 1 anchor bolts. After tightening, check l alignment to make sure it has not changed. i j B. Do not connect piping to turbine until I alignment and grouting are completed. I l 4. LIFTING i r 4.1 Before lifting heavy equipment, be certain that weights I 4 listed on certified outline drawings are within the capacity of the crane or hoist. Lift smoothly and avoid 2 j twisting and shock damage. Adjust cable or chain lengths l to lift squarely. Use wooden block

pads, etc.,

to prevent-cables or chains from damaging pipe work or turbine parts. l 4 i TERRY CORPORATION Section 3 REV. 2-82 3-5 I i n,,., - ,e-, -e ,,,-,ww-n,n-4,4.- ,-----7--v a, -w ,.-+-,-m-nw w--.,, y,,, sw-r,---e nn,,,,-,en .-,,w-,,,, y.,, m,ge,,,-

INSTALLATION CONTINUED.... I 4.2 When turbines are mounted on a base and are equipped with a sliding expansion foot on the bearing pedestal at the governor or high pressure end of the lower half casing, the sliding foot is secured to the base by two bolts, one on each cide within the guide blocks. THESE BOLTS ARE NOT DESIGNED TO TAKE THE WEIGHT OF LIFTING THE ASSEMBLY. Chock washers are fitted under bolt heads to secure pedestal foot from movement during shipment. DO NOT REMOVE UNTIL UNIT IS INSTALLED. 5. PIPING 5.1 The piping system should be designed with sufficient inherent flexibility to take care of thermal expansion without creating excessive forces at the flanges. 5.2 On both the inlet and exhaust pipes a suitable support (adjustable spring loaded) should be installed directly under vertical risers near the turbine and above horizontal pipe runs, and then adjusted for best possible alignment of flange when hot. This will insure that most l i of the forces resulting from expansion and stresses due to dead weight will not be placed on the turbine flanges. i IMPORTANT NOTE i The piping must be so arranged and so supported t.ha t no excessive stress can be transmitted to the turbine, either due to the weight of the pipe or to its expansion and contraction. All piping must be within the limits of the allowable forces and momenta in accordance with the applicable NEMA standards publication. The only exception being when allowable forces and moments are included on a certified outline drawing for a particular project. i TERRY CORPORATION Section 3 REV. 2-82 3-6

[.. t ) INSTALLATION CONTINUED.... j l 5.3 PIPING STRAIN i 5.3.1 The not effect of piping strain on a machine reduces i reliability by: 5.3.1.1 Causing misalignment and consequent vibration. i 5.3.1.2 Causing case distortion and consequent vibration, rubs, case leakage and possible cracking. i 5.3.1.3 Causing foundation or base deflection, which may } result in misalignment, case distortions and i consequent vibrations or rubs. i 5.3.2 Excessive piping strain may be the result of: 1 5.3.2.1. Thermal expansion and contraction of the pipe, boiler. and machine. This indicates faulty piping design. t Expansion joints or loops may have to be installed to correct the problem. l l 5.3.2.2. Improper pipe support. Frequent problems arise from { indiscriminate use of rod hangers (instead of spring i. hangers),

anchors, and other non-elastic restraints and supports.

To correct this, disconnect piping at i .I both ends and support on spring hangers except where } anchors or restraints are required by the pipe design. 5.4 Inlet pipe sizes should be large enough to maintain rated steam pressure at the turbine inlet flange under maximum load conditions. In determining pipe size, l proper allowance should be made for pressure drop due l to long sections of

pipe, elbows, valves or other

[ fittings between the boiler and the turbine. j 5.5 If wet or saturated steam is

used, it is very i

important that the piping be arranged so thet condensate cannot be carried over into the turbine. A j steam separator of the proper size with a trap of j ample capacity, should be installed before the turbine t l inlet. If the turbine is fed from a main header under { no circumstances should the pipe be taken from the = side or bottom of the header. IT SHOULD. IN ALL j CASES. BE FED FROM THE TOP. All horizontal runs must i j be sloped in direction of steam flow, with drains at j the low points. l TERRY CORPORATION i Section 3 REV. 2-82 l 3-7 l

INSTALLATION CONTINUED.... 5.6 The importance of protecting the turbine against slugs of water cannot be over-emphasized. We are not concerned with the wetness of the steam, but with the condensate which is separated out as water. 5.7. The harmful effects of water are: 5.7.1. Rapid erosion of blading and valves. 5.7.2. In the case of wheels with inserted blades, the danger is present of the hammet blow effect of the water tearing out the blades and damaging the rotor. 5.7.3. Governing is adversely affected. 5.7.4. Rotor may be permanently distorted and/or turbine 4 damaged. 5.7.5. Danger of thrust bearing failure and consequent damage to turbine. i 5.8 Exhaust piping. On each installation the length of

run, elbows, valves and other fittings in the pipe l

must be considered and all factors which may cause excessive back pressure on non-condensing turbine or reduced vacuum on condensini; turbines, and the final decision on piping size made accordingly. On non-condensing

turbines, back prennure higher than that for which the turbine was designed will cause a reduction of power and an increase of steam consumption.

It may also cause gland leakage and, in extreme cases, can rupture the turbine casing. On condensing turbines decrease of vacuum will ha'. e an even greater effect on capacity and economy. 5.9 The exhaust pipe must be installed and anchored so that no excessive stress can be put on the turbine from either the weight of the pipe or its expansion and contraction. Where such arrangement cannot be made with certainty the provision of an expansion joint near the turbine can be useful in low pressure lines and is usually required on large pipe sizes. TERRY CORPORATION Section 3 REV. 2-82 3-8

t INSTALLATION CONTINUED.... 5.9 The use of an expansion joint does not of itself avoid undue' stress. It is not as flexible as many people assume and when installed it must be properly aligned and not indiscriminately exposed to shear or torsion. In a majority of applications the axial thrust created on the cross sectional area of the largest bellows by internal pressure, must be restricted by the use of the rods. They are most effective when the expansion joint is used in

shear, instead of tension or compression.

When used in either a vacuum or a pressure

line, the tie rods have to be arranged i

j accordingly. They are useless whore a joint moves under tension and compression as they by-pass. the joint and transmit pipe forces direct to tha turbine. Provision must be made to anchor the piping,in such a t manner that excessive forces will not be (ransmitted to the turbine during shutdown and operational running. (SEE NEMA STANDARDS IN THIS SECTION). As on inlet lines, connection to a header must be made at i the top-never from the side or botton, and great care l must be taken to avoid draining water back into the r i turbine. All horizontal runs must be sloped. i 4 i 6. FULL-FLOW RELIEF VALVE I i ~ 6.1 An atmospheric full-flow relief valve is part of the = exhaust piping which is external to the turbine and it 1 must be installed in the exhaust piping between the turbine exhaust connection and the first shutoff valve in the exhaust system. This is to protect the turbine casing and internal parts against excessive steam pressure. 6.2 The valve must be sized to pass the maximum steam a

flow, to the atmosphere, that will pass through the

{ turbine nozzles under rated initial steam conditions. 4 i THIS VALVE IS NOT TO BE CONFUSED WITH 4 THE SENTINAL RELIEF VALVE INSTALLED ON i THE TURBINE CASING TO GIVE AUDIBLE AND VISUAL WARNING OF EXCESSIVE EXHAUST PRESSURE. TERRY CORPORATION l Section 3 REV. 2-82 l 3-9 i a

-~._. INSTALLATION CONTINUED.... 6.3 The full-flow relief valve should start to open at the sentinal relief valve setting and be fully open with the additional rise in pressure not to exceed ten (10) percent (NEMA STANDARDS CODS). The sentinal relief valve will then give a visual and audible indication when the full-flow relief valve starts to open. CAUTION NOTICE 3 THE EXHAUST CASE IN NOT DESIGNED FOR FULL LINE PRESSURE AND MUST BE PROTECTED WITH A SUITABLE SAFETLY DEVICE SUCH AS A l FULL-FLOW RELIEF VALVE TO PREVENT OVER PRESSURIZATION OF THE EXHAUST CASE. 7. CHECK VALVE 7.1 When a turbine exhausts or bleeds steam into another system and a check valve is installed to provide containment of reverse flow to the turbine, adequate . bracing must be installed to absorb any forces created by water hammer occurring in the exhaust line l downstream and acting on the check valve. 8. AUXILIARY PIPING r 8.1 When water cooling is indicated on certified outline drawings the inlet pipes must be provided with valves i for regulating. NEVER INSTALL VALVES IN OUTT.ET PIPESt Output pipes must be so arranged that they cannot become obstructed. Only

clean, cool water should be used.

Cooling water. piping should be sized to suit the connections on the cooler. .The amount of l cooling water will vary, depending on the temperature of the water, steam temperatures, etc. With forced feed lubrication, the flow of water should be adjusted to maintain an oil temperature leaving the bearings 0 0 not to exceed 165 F (74 C)., and an inlet O 0 temperature not under LOO F-(38 C). 4 i TERRY CORPORATION Section 3 REV. 2-82 3-10 t i d ,.-3 y --e. -,,,w w4 .-y .-,e- .-,.-..,-we ,,,,,.,--,,.,.-,-,.,,,-,..,,,,,y

INSTALLATION CONTI?UED.... 8.2 Every turbine is provided with one or more drain outlets. These should be piped with suitable OPEN atmospheric drain lines and shutoff valves must be provided. These drain lines must be left open when the turbine is idle to prevent accumulation of condensate in the turbine which will result in corrosion and rapid deterioration of internal parts. INSURE THAT NO CONDENSATE CAN BE PULLED INTO THE TURBINE THROUGH THE DRAIN LINES. 8.3 If turbine is subjected to freezing temperatures water must not be allowed to stand in cooling coils or pockets in the case, steam chest or valvcs. 9. OIL PIPING AND GLAND PIPING 9.1 Instructions are provided in the Lubrication and Steam Seal-Drain System sections in this manual. t i-10. CLEANING OF STEAM PIPING s 10.1 Terry Corporation has found from experience over many

years, with different customers, that it is very important to clean steam piping and

headers, especially with new installations, before a

steam turbine is put into operation. There have been cases where steam lines have not been cleaned at all, with the idea that strict inspection for cleanliness during installation would be sufficient. This has proven unsatisfactory since very small particles of steel, welding slag and large quantities of oxide scale have been blown into the turbine through the small strainer holes of the turbine governor or stop valve. 10.2 From experience it has been found most satisfactory to e blowdown steam lines with steam using a cycle of

heating, blowing and cooling.

This method is recommended by Terry Corporation. i l TERRY CORPORATION Section 3 REV. 2-82 3-11

.l j INSTALLATION CONTINUED.... i NOTE i The following procedure suggested by Terry Corporation is not mandatory. The purchaser is at liberty to employ i other accepted methods. IN EITHER i

CASE, IT MUST BE CLEARLY UNDERSTOOD THAT IT IS THE PURCHASER'S 1

RESPONSIBILITY TO SUPPLY STEAM FREE OF i FOREIGN MATERIAL TO THE TURBINE INLET CONNECTIONS. 10.3 SUGGESTED BLOWDONN PROCEDURE. Due to the variations in different installations of the length. configuration, number of stop valves and sixes of [ steam piping it is not intended or possible to give a t i detailed procedure. [ E9IE 4 l NHEN CLEANING STEAM PIPING IT MUST BE DISCONNECTED FROM THE INLET -TO THE l TURBINE OR THE TURBINE STOP VALVE. l 4 i i 10.3.1 The purchaser must plan and make proper arrangements to achieve maximum cleaning of piping. The blowdown cycle consists of warming the steam lines initially. l l Then, design pressure for the piping in built up in t the boiler and released through the valve to blow i through the steam line. Blowing should be stopped l before boiler pressure drops to 100 PSIG or the } minimum pressure recommended by the boiler manufacturer. t l 10.3.2 Boiler pressure is then built up again, during which time the steam line should be cooled enough and the l cycle can be repeated. 10.3.3 The cycle should be repeated f rom four (4) to six (6) 2 times. The use of targets installed in the steam path f are - recommended as they give a good indication as to the cleanliness of the line. Targets should have a i highly polished finish and be repolished after each I blowdown check. I i i TERRY CORPORATION l j Section 3 REV. 2-82 3-12 l z 4 i ., -,----,- -, - - -, - - - - - - ~ - ~ - -, - _ _,, .c

INSTALLATION CONTINUED.... 10.3.4 To achieve maximum cleaning during the blowing cycle, the blow piping should be sized large enough to obtain the maximum mass velocity head that can be developed during full load operation of the turbine. 10.3.5 The blow pipe should be piped outside of the building where the blowdown steam and particles will not injure personnel oc damage equipment. It should also be of the same design rating of the steam line being blown down. 10.3.6 The purchaser must decide as to whether the steam line should be blown down by sections, stop valve to stop valve or direct from boiler to stop valve, according to the system layout and keeping in mind that the maximum velocity must be maintained to achieve maximum cleaning. NOTE i THE FINE MESH SCREEN MUST NEVER BE CONSIDERED AS A SUBSTITUTE FOR A THOROUGH PIPE CLEANING JOB. 1 10.4 EXHAUST PIPING ROT _g WHEN CLEANING STEAM EXHAUST PIPING IT MUST BE DISCONNECTED FROM THE TURBINE EXHAUST. 10.4.1 Put blind between exhaust flange and exhaust pipe to prevent foreign materials from entering the case during the blowdown process. 10.4.2 Open exhaust valve slowly. This allows condensate and steam to wash out exhaust piping. 10.4.3 Repeat step 10.4.2 until system is clean. TERRY CORPORATION Section 3 REV. 2-82 3-13

INSTALLATION CONTINUED.... 11. EXPANSION JOINTS i I WARNING DO NOT PERMIT CINDERS OR OTHER FOREIGN MATERIAL TO BECOME LODGED BETWEEN THE EQUALIZING RINGS AND THE CORRUGATIONS. 11.1 Expansion joints 5" and smaller in size are shipped with two (2) spacing blocks between the equalizing rings. These must be removed before pipe spacers between the equalizing rings. These should not be removed until joint is set in place in the line, but must be removed before the joint is permitted to function. 11.2 Flanged expanttion joints having internal sleeves require a soft gasket between the face of the joint-dnd the back of the sleeve face as well as gasket I between the sleeve and the companion flange. Those joints should be installed so that the flow is in the l inner sleeve. 11.3 The universal type of expansion joint has two (2) or four (4) heavy limit rods which divide the movement equally between both expansion joints. Each of these rods have four (4) split spacing collars under the nut. These maintain the proper overall Inngth and should only be removed after the joint is bolted in place. WARNING GASKETS CONTAINING CARBON OR GRAPHITE SHOULD NOT BE USED IN CONTACT WITH STAINLESS STEEL. SEVERE CORROSION MAY RESULT. ANY DARK COLORED GASKET MAY CONTAIN GRAPHITE: CONSULT GASKET MANUFACTURER. TERRY CORPORATION Section 3 REV. 2-82 3-14

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O, 'oe T.J 1 I Figure 2 ) i I NOTE: When using Jack bolts or wedses to establish alisnment before grouting they should be backed off or removed after the grout has set and the anchor bolts should be tightened. TERRY CORPORATION Section 3 REV. 2-82 3-15 ,,, _ _..__. _ _ _ _ _.. ~,. _ _., ~, _

i COVER OPENSNG TO PREVENT GROUT FROM ENTERlNG P9PE SLEEVE SHIM LAMINATED STAINLESS STEEL SHlM FLEXPLATE FINISH GROUT TO DE POURED FLEXPLATE AFTER FINAL UNIT ALIGNMENT pooy N s TOP OF FINISH GROUT ,A SOLE WM 'h 1.5 \\ CEMENT m At%7/////fA s:.?:'. M W//XS 8 mWfnu:-;:.? E5; 3 % ;/'i. $* g 755.'!.:'f.:-(11M9EE En.. i 'd.i$[> MIN. ~ 5 .h D

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INSTALLATION i This page is included as a location reference for the following extract as taken from the National Electrical Manufacturers Association (NEMA) Standards Publication No. SM23-1979, for a which due credit is acknowledged. It is included in this Instruction Manual as a guide for the minimum requirements of installation, except

that, where allowable forces and moments are shown on certified outline drawings, pipe loads are to be kept within those limits shown.

h i l i i 'I i a J y -

Pub. No. SM 23 Pag) 28 i Part 8 STEAM PIPING SYSTEMS SM 23 8.01 INTRODUCTION turbine and to very large forces at the turbine supports. Reactions of piping systems connected to steam turbines, if of sufficent magnitude, will The forces in a piping system under opera-4 result in misalignment of the turbine sufficient ting conditions can be grouped into three class-es: those due to steam pressure, temperature, to cause rough operation and sonous mechani-and dead weight. l cal damage. Steam turbines have been very carefully designed to provide for thermal ex-Autnonaes Engineenne informauon o.at.is79. pension and, at the same time, maintain close i alignment between the turbine rotating and J stationary parts, and also the turbine and driven SM 23 4.03 FORCES DUE TO STEAM PRESSURE equipment. The provisions for turbine ther* These are most commonly associated with mal expansioins by necessity limit the allow-gow. pressure and vacuum lines where expansion 1 able values of forces and moments applied to joints are often used to provide flexibility. If ] the turbine structure by the piping connected ] to it. an expansion joint is improperly used, it may cause a pipe reaction greater than the one it is the purpose here to briefly discuss piping which it is supposed to eliminate. An unre-l j arrangements and recommend flange loading j limitations iml*osed on mechanical-drive steam strained expansion joint will cause an axial thrust equal to the effective area of the bellows i turbines by piping. This information is pre-1 sented as an aid to the purchaser and is not times the internal pressure. The force neces-intended as a self contained thesis on piping. sary to compress or elongate an expansion The recommendations to be discussed should [oint can be quite large, and either of these i provide allowable values of forces and moments forces may be greater than the limits for the at the turbine connections for steam inlet, exhaust flange. In order to have the lowest extracting, and exhaust piping. reaction, it is best to avoid absorbing pipeline it is not considered necessary to supply expansion by axial compression or elongation. j values for auxiliary piping such as steam leak-if it is found that expansion joints are required, off, lubricating oil, and cooling water, but even consult the Expansion Joint Manufacturers t Association.' so, this acxiliary piping should also be designed i such that turoine expansion is not restrained. The following figures and paragraphs re-present typical installations and are offered j Avinonaes Eneiaeenne informenon e.211e79. only as guides. 1 SM 2M M MM PROM M Fig. 81 shows an expansion joint in a pres-APPUED TO TURSONES sure line. The axial thrust from the expansion joint tends to separate the turbine and the One of the first considerations in designing elbow. To prevent this, the elbow should have any piping system is to keep the stresses in an anchor to keep it from moving. The turbine j the pipe within the limits of the established should also absorb this thrust and, in doing i j rules of national codes such as the ASME so, becomes an anchor. This force on the Soller and Pressure Vessel Code, American turbine case may be greater than can be al-l National Standard 831.3, Chemical Plant and lowed. In general, this method should be dis-l Petrodsum Astinery Piping, and any local codes couraged. i that may be applicable. In general, the jurisdic. Fig. 8 2 shows the same piping arrangement tion of such authonties stops at the turbine inlet as Fig. 81, except for the addition of tie rods } and exhaust connections or other openings on on the expansion joint. The tie rods prevent { the machine to which external piping systems the elongation of the joint and take the axial connect. thrust created by the internal pressure of the i in order to keep the strains due to forces expansion joint so it is not transmitted to the 1 and bending moments on the turbine connec-turbine flange. The tie rods eliminate any axial l tions, including the weight of the pipe, within flexibility, but the joint is still flexible in shear; recommended limits, the piping system design that is, the flanges may move in parallel pianos. should be such that restraints and freedom of The location of this type of joint in the piping movement match the requirements of the tur-should be such that movement of the pipe l bine. Pipe forces which seem small may lead puts the expansion joint in sheer instead of 1 to large moments at the connections to the tension or compression. E.a. =o e a.o

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Pub. No. SM 23 Page 29 i i a i I .I [/ A / ANCHon TunslNE / V EXPANSION JOINT l 1 e_' E I m E I i P j j rua.Ne v-4 5- ///////// Fig.5 2 EXPANSION JOINT WITH TIE RODS 1

~ _ - Pub. No. SM 23 Page 30 Fig. 83 la an arrangement frequently used, place during installation as illustrated in Fig. 8 g. having tie rods as Indicated for noncondensing Forces and moments in the hot condition are operation. This arrangement should prevent thus reduced below the values they would have any thrust due to internal pressure of the ex-if the system were not cold sprung. Points i pension joint from being transmitted to the A and C of Fig. 8-g are the points to be con-exhaust flange and retains the axial flexibility nected by a piping system and X and Y are of the joint. It may be used for either vacuum the respective expansions. or pressure service (by suitable arrangement In the case of welded connections, it is of tie rods). necessary to bend the pipe by putting a mo-i Fig. 8 4 shows a suggested arrangement for ment on it when connecting it to point C to a condensing turbine with an "up" exhaust. make the weld preparations parallel, as well a j Due to the large exhaust pipe size normally as just pulling B up to C. If this is not done, a i encountered on condensing turbines, the ex-moment may exist in the hot condition, and haust piping may be relatively stiff, and an desired reduction in forces and moments may expansion joint should be used at some point not be obtained. Wherever possible, it is wise .3 to take care of thermal expansion. An unre-to facilitate assembly by locating field welds l stricted expansion joint placed at the exhaust at points of minimum moment. Points D and flange of the turbine may exert an upward or E are such points. lifting force on the turbine flange which in Authortaed Engineering Information 6 2119M. many cases is excessive. Fig. 84 provides the necessary flexibility to take care of thermal expansion without imposing any unnecessary SM 23 4.05 FORCES DUE TO DEAD WElGHT lifting force on the turbine. The expansion joint is in shear which is thq preferred use. The dead weight of the piping should be entirely supported by pipe hangers or supports. The relatively small vertical expans:on may There are basically two types of supports-rigid compress one joint and elongate the other which causes a small reaction only and may and spring. Rigid supports are necessary when 1 be well within the turbine flange limits. an unrestricted expansion joint is used. Rigid Autheruse Eno6neenno informat6en s 21. ism. supports may be used to limit the movement of a line to prevent excessive deflection at SM 23 4.04 FORCES DUE TO TEMPERATURE am n A sw rt is nm sadstadM 4 where thermal expansion may cause the pipe if a pipe is connected to some point as A in to move away from the support. Fig. 8-5, and has the configuration shown by On the two types of rigid supports shown in j the solid line, it may assume the approximate Fig. 810, the rise of the turbine case due to position shown by the dash line when heated temperature may lift the base elbow from the 4 to a higher temperature, providing no restraint support so the turbine would have to support is offered by point B. the weight of the pipe. The expansion of the if both points A and B are rigid points which vertical run of pipe would rolleve the pipe hanger may not move, the pipe may assume a shape of its load so the turbine would again have to similar to that shown by the dash line in Fig. 86 support the weight of the pipe, when heated. If an expansion joint with restraining tie The stresses may be reduced by using ex-rods is utsed, either a rigid pipe hanger or a pansion loops such 'as shown in Figs. 8 7 and base elbow with a sliding or rolling contact 8 8. When the piping does not have to be con-surface can be used as shown in Fig. 811. ~ fined to one plane, torsional flexibility may be When the thrust due to an expansion joint is effectively used to reduce stresses. Prestres-less than the exhaust flange limits and no re-sing the pipe in the cold condition or " cold straining tie rods are used, the pipe should have springing" may also be used to reduce the an anchor as shown in Fig. 812. Since this con-stresses in operation. These principles may dition rarely exists, it la better to use one of be used in combination to produce a design the preferred arrangements such as shown with flexibility sufficient to keep the stresses, in Fig. 811 and eliminate as much pipe reaction 4 i forces, and moments within the permissible as possible rather than just stay within the limits in both the hot and cold conditions. limits. The piping system should be designed with Spring hangers or supports are best suited sufficient inherent flexibility to take care of to carry the dead weight when there la ther. thermal expansion. Prestressing (cold spring-mal expansion to be considered. The move-i ing) to reduce the maximum values of both ment of the pipe may change the spring tension I connection reactions and piping stress is ac-or compression a sniall amount and the hanger complished by cutting the pipe short by a pro- . loading a small amount but may not remove determined amount and then forcing it into the load from the hanger. Pubilshed manuals ~

Pub. No. SM 23 Page 31 i I l l i ="5

c.

m v V- //////// i Fig. 5 3 EXPANSION JOINT WITH TIE RODS FOR NONCONDENSING OPERATION i i a l ) Ij 2 l q .I ') r- ,O. ~ ~ 4 CONDENSER f TURSINE Fig. 8 4 EXPANSION JOINT WITH TIE RODS FOR CONDENSING OPERATION WITH "UP" EXHAUST 1

Pub. N2. SM 23 eaa. 32 i M///M////// /////////// A A / . I ' l. l II I ( s A a ( % #,,w_. s [ 's s' FI. M Fig. H S 4 .i //////////// A //////////// ~ A f 3 a r Y A a L J FI.87 Fig. 4 4 G

s Pub. No. SM 23 Page 33 //////// /////////// A s, 's's 'so s ,\\ '.N, i -ax. 's 1 i d, N e Y___ I 'b'p // c, N 9 p / \\s, N /////// ^ Fig. 69 Fig. 810 ///////// l r / /M~u /~7_n-llllllll lllll/ll Fig. 611 Fig. 412

Pub. N3. SM 23 Page 34 on pipe design provide information on hanger

a. These resultants shall not exceed:

spacing to give proper support. In addition to this, it may be found necessary to add addi-p* ~_ 250 De - Me tional supports or move existing supports if 2 resonant vibration appears in the piping. where: A spring support should not be used to op-pose the thrust of an expansion loint, when Fe = Combined resultant of inlet, ex. the pressure is removed from the line, the traction, and exhaust forces' i spring support may exert a force the same as pounds. the expansion joint only in the opposite direction. Aumorized Engineonng informenon s 211979. Mca Combined resultant of inlet, ex. traction, and exhaust moments, SAS 234.00 ALLOWASLE FORCES AND MOMENTS ON MECHANICAL DRIVE ,r as pound-e t STEAM TUR84NES De = Diameter (In inches) of a circular The forces and moments acting on mechani-opening equal to the total areas cal drive steam turbines due to the steam inlet, of the inlet, extraction, and ex-extraction, and exhaust connections may be haust openings up to a value of limited by the following rules: 9 inches in diameter. For values j

1. The total resultant force and total resultant beyond this, use a value of De moment imposed on the turbine at any equal to:

connectiort must not exceed the following per Fig. S 13: (18 + Equivalent diameter) = inches. 3 Fn + Mn = 167 De

b. The components of these resultants shall not exceed:

where: F = 125 De My = 125 De q y Fn = Resultant force (pounds) including pressure forces where unrestrained F, = 100 De M, = 125 De expansion joints are used at the connection except on vertical ex- %= 50 De M = 250 De hausts. Full vacuum load is allowed on vertical down exhaust flanges. The components are as follows: 4 It is not included as part of the Fy = Vertical component of Fws, piping load. Fz = Horizontal component of Fngt right angles to turbine shaf t Fn = F,2 + F 2 + F 2 Fm = Hortzontal component of F>r to y turbine shaf t. ) Mn = Resultant moment in foot pounds = Component d W in a vocal plane at right angles to turbine shaft. MR= M,2 + M 2 + Mg2 y My a Component of Mgin a horizontal pian.. D = Nominal pipe size of the connection Mr = Component of M#cin a vertical in inches up to 8 inches in diameter, plane parallel to the turbine shaft. For sizes greater than this, use a value of

3. For installation of turbines with a vertical (16 + Dnom) Inches exhaust and an unrestrained expansion De =

joint at the exhaust, an additional amount 3 of force caused by pressure loading is

2. The combined resultants of the forces and allowed. (This additional force is perpen.

moments of the inlet, extraction and ex-dicular to the face of the exhaust flange haust connections, resolved at the center. and central.) For this type of application, lines of the exhaust connection must not calculate the vertical force component on exceed the following two conditions: the exhaust connection excluding pressure

s Pub. N2. SM 23 Page 35 loading. Compare this with one sixth of ciuding pressure loading) of 151/2 times the pressure loading on the exhaust. Use the exhaust area (square inches). the larger of these two numbers for vertical

4. These values of allowable force and mo-force component on the exhaust connec-ment pertain to the turbine structure only.

tion in making calculations outlined in They do not pertain to the forces and items 1 and 2. moments in the connecting piping, flange, The force caused by the pressure load-and flange bolting which should not ex. Ing on the exhaust is allowed in addition coed the allowable stress as defined by to the values established by the foregoing applicable codes and regulatory bodies, up to a maximum value of vertical force (pounds) on the exhaust connection (In. Authorued Enginowing Information 4 21 1979. VERTICAL U RIGHT ANGLE To TURetNE SHAFT 3y, / / / F, ,/ / ,o'/ F' ,/ r PARALLEL U X+ TO Me l M. TUR8tNE SHAFT I l I a Z+ l l l Fig. 813 i l

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4 b PROCEDURE FOR ALIGNMENT OF TURBINES TO DRIVEN EQUIPMENT BY REVERSE INDICATOR METHOD GENERAL: This section establishes procedures for cold and hot alignment checks of turbine-driven equipment. Procedures are based upon use of a bracket-mounted dial indicator, alternately mounted on each

shaft, which eliminates the necessity of obtaining coupling hub face readings.

1. SCOPE These proceduren are applicable to alignment of driver and driven equips. tnt where both shafts can turn as one, and where parallel offset and/or angular misalignment are present. There are three conditions of 2. TYPES OF MISALIGUMENT misalignment which may exist. 2.1 Parallel Offset. Shaft centerlines are parallel but slightly displaced with respect to each other as shown in Figure 1 (b). 2.2 Anquiar Misalionment. Faces of shaft ends are at an angle with respect to each

other, with shaft centerlines intersecting at one

point, as shown in Figure 1 (c).

~ 2.3 Combination offset and Ancular Misalionment. Shaft centerlines are

offset, and are not parallel with respect to each other as shown in Figure 1 (d).

3. FACTORS AFFECTING ALIGNMENT The following factors must be considered during cold and/or hot alignment checks. 3.1 Thermal Expansion

Turbine, gear and/or driven equipment may rise vertically at their horizontal centerlines, and may also move horizontally, due to thermal expansion.

3.1.1 Initial cold alignment is based upon calculated thermal movement using theoretical linear thermal expansion coefficients. TERRY CORPORATION 4-1 ~ -.

.. _ ~ _ _ _ _ _ / i i ~ PROCEDURES FOR ALIGNMENT OF TURBINES TO DRIVEN EOUIPMENT BY REVERSE INDICATOR METHOD CONTINUED.... t (a) If shaft "A" is calculated to move 4 vertically more than shaft "B" at normal i j operating and ambient temperatures, shaft "A" should be set lower than shaft "B" by ) the amount of calculated centerline rise, so that shaft centerlines will be line-to-line during normal steady-state operation. (b) Linear thermal expansion may be found by the formula: j AT = tcK(AT/2) where Atsexpected average rise or movement, 1 (in.) to s initial distance or height between support feet and shaft

center, unit cold, (in.)

K acoefficient of thermal expansion, 1 (in./in. 0F) AT u temperature difference between ambient and operating conditions, (OF) (c) In general, L.P. end of turbine will not rise as high as its H.P.

end, due to higher temperature of steam at inlet.

Rise at both ends of turbine shaft should i therefore be calculated, and any resulting angular misalignment accounted for during 4 initial cold alignment. An exception to this occurs when turbine casing is j centerline supported at its H.P. - end. In i this case. - L.P. end could rise more than i H.P. - end. i 3.1.2 Horizontal movement of gears should also be taken into account. t 3.2 Shaft End Clearance. Axial clearance between shaft i ends shall be per. coupling manufacturer's recommendations, and should be measured with shafts against their active thrust faces. Allowances for any axial expansion of shafts, as.well as combined axial l movement of gear and pinion thrust clearance and backlash, must be included in gap. i I TERRY CORPORATION j 4-2 I 1 I

4 d 6 i PROCEDURES FOR ALIGNMENT OF TURBINES TO DRIVEN EQUIPMENT BY REVERSE INDICATOR METHOD CONTINUED.... I 3.2.1 Use temporary spacer or shin stock to ensure proper gap is maintained during alignment. i 3.3 Bearina Oil Film. Depending upon type of journal r i bearings installed, shafts will rise during operation due to lubricating oil film thickness. For sleeve-type bearings, shaft rise is generally taken to j be equal to bearing radial clearance, whereas for i tilting-pad type journal bearings. the rise is about 0.001-in, regardless of clearance. i 3.4 Cleanliness of Feet and Pads. Since dirt and burrs j act as shin stock when between feet and pads, it is essential that all dirt or burrs be removed from feet i and pads prior to alignment. 1 l 3.5 External Forces. Stresses caused by

piping, rigid i

conduit -connections, etc. must be eliminated or i reduced to acceptable levels prior to final alignment. 3.5.1 Initial cold alignment should be performed with piping disconnected. After initial alignment has been completed, piping can be connected j ~ while distortion is checked and measured with l dial indicators on the. coupling. This will i allow' observation of any movement of the shafts caused by stresses imposed by piping. i 3.6 " Soft-Foot" Condition. All turbine support feet must i be on same plane. Condition created when one foot is e f slightly higher or lower in elevation. This difference in elevation can be caused by a machininq error in the turbine feet, support pads upon which the j feet rest, or by spongy (soft) shins. 3.6.1 Can be corrected by adding or removing shims, or j by using heavier shims beneath affected foot. J l i .i 2 l TERRY CORPORATION l 4-3 i

l s EROCEDURES \\ FOR ALIGNMENT Mt3E INDICATOR 3GittiOD CONTINUED _.... OF TURBINES TO DRIVEN 1 EOUIPMENT 1 BY 4. &LIGNMENT PROCEDURES. 4 4.1 Hub Runout i O.D. check. Prior to and face alignment runout of roundness and concentricity with r

check, coupling hubs to record ensure i

espect to shaft axis. 4.1.1 Set-up dial indicator t coupling hub at a point o read on face of circumference. turbine nearest its maximum Rotate turbine shaft and minimum indicator and outer runout is given b and minimum values.y diffference readings. record Face between maximum 4.1.2 Reposition dial turbine coupling inlicator to read on O.D. of hub. i record Roundnessmaximum and Rotate turbine shaf t minimum indicator or O.D. and the difference between the

runout, is given by oreadings.

i 4.1.3 Repeat se two readings.ne half steps [ equipment coupling hub.4.1.1 and i 4.1.2 above for driven 1 4.1.4 Position of I maximum runout ~ both hubs prior to should be Readings continuing marked obtained during alignme. alignment i on corrected for O.D. runout, check. i nt check must be 4.1.5 Face or O.D. j be corrected runout by reinstalling hub andin excess of 0.00lS-in hub replacement as applicable keys 4.1.6 Record or by 1 runout Figure 2 values on Alignment 4 Record Sheet, i 4.2 Turbine-to-Driven coupling hub and set-up dial indinon-sagging in Eouinment Alionment. 1 Secure of half c et io turbine half a 1 location coupling hub of hubs that 0.D. drivencator to read on O.D. so that runout equipment. was at same indicator relative obtained. can be position Mark both dynamically balanced maintained of bracket maintain in position during'aligncouplings, when reversed. and i align match marks With ment check. and l = TERRY CORPORATION 4-4 j

PROCEDURES FOR ALIGNMENT OF TURBINES TO DRIVEN EQUIPMENT BY REVERSE INDICATOR METHOD CONTINUED.... 4.2.1 Set dial indicator zero at aid travel of stem. Most indicators read plus (+) when stem tip is pushed in towards dial, and minus (-) when tip moves away from dial. 4.2.2 Ensure dial indicator supports do not deflect. If sag occurs, record amount on Alignment record Sheet and correct readings accordingly. Ref. Figure 1 (e). 4.2.3 Rotate both hubs together and record indicator readings on Alignment Record Sheet at 12 o' clock vertical positions, and 3 o' clock and 9 o' clock horizontal positions. (a) When rotating

shafts, always use same direction of rotation using hands or a strap wrench.

Do not use pipe wrenches. (b) Algebraic sum of indicator readings taken at 12 o' clock and 6 o' clock must equal algebraic sum of 3 o' clock and 9 o' clock readings, within limits of hub runout. Use 12 o' clock position as "zero" starting point for all readings. When rotating shafts dial indicator should always return to its zero setting when at its starting point. (c) Use a good mirror and adequate lighting to follow indicator during rotation. (d) Take two or three sets of dial indicator readings to verify accuracy. 4.2.4 Make a graphical plot of indicator readings to show relative shaft positions, as shown in Figure 3. Parallel offset is one half the difference (T.I.R.) between two readings taken at 1800 from each other. 2 d 4.3 Driven Equiement-to-Turbine Allonnent. Remount indicator bracket on driven equipment half coupling

hub, and set-up dial indicator to read on O.D.

of turbine half coupling hub at same location that O.D. runout was obtained. Repeat requirements of paragraph 4.2 and subparagraphs 4.2.1 through 4.2.4 above. TERRY CORPORATION 4-5 l

J ) PRCCEDURES FOR ALIGNMENT OF TURBINES TO DRIVEN EQUIPMENT BY REVERSE INDICATOR METHOD CONTINUED.... i 4.4 Use of Double Brackets. If available, two opposing bracket may be mounted at same time with respective dial indicators set-up to read on coupling hub O.D.'s as described above. This will allow quicker alignasnt checks to be made, as well as eliminate any possible setup errors during reversal of a single bracket. i i 4.4.1 When conditions are such that it is impossible to obtain satisfactory readings on coupling l hubs, accurate readings may be obtained by use j of two

brackets, modified to include an indicator reading post on each bracket.

Dial J indicators are set to read on opposite indicator posts vice coupling hub. In this

method, coupling hub sleeves can be secured together, and hence would be useful for hot-alignment checks as it would eliminate time delay in i

uncoupling the hubs. l 4.5 BRACKET MANUFACTURE. Brackets must be accurately l manufactured. It is important that support for dial indicator is parallel to longitudinal horizontal centerline axis of shaft, in order to obtain accurate readings. Example: From thermal expansion considerations, etc., assume that it has been determined that for initial cold alignment, turbine must be set 15 mils below and 8 mils to the north of driven equipment. Initial reverse indicator readings are taken and results shown on Figure 3. i I i a ) i TERRY CORPORATION j 4-6 t l ~ --

l i ggg BINES TO DRIVEN EQUIPMENT R REVERSE INDICATOR.. METHOD CONTINUED.... l 5 A. PILOT DISPLACEMENT Since TIR for OD represents twice the displacement of shaft centerline, only half the value i j of the readings should be plotted. Graphically locating i 1 displacement versus linear dimensions of unit will reveal I amount of shims or lateral displacement required to achieve desired alignment. Construct graph similiar to Figure 3. and establish plane of reference, such as centerline of driven unit, since turbine is being aligned 1 to driven unit. At a position conveniently selected. l ) construct centerline of driven unit as well as point along 1 I it which the turbine to driven unit readings were taken, i (i.e. Plane A). For reference an extension of this t centerline can be made throughout the length of the graph i by using a dashed line. Determination of the value of i each grid horisontally should be made at this point. Consulting the assumed dimensions of the turbine from i Plane A to outboard foot as shown in Figure 3 sum is t found to be 114 inches. The MINIMUM VALUE for each grid will result in maximum display of length of turbine, and l j also maximum accuracy. A value of 1 in./ division has j been selected and Planes A.B. I.B.F & O.B.F. located on the i i basis of the turbines dimensions. This is the scaled down representation of the driver's length. A similar technique is used to determine the value of the vertical grids which will represent the displacement at the various points along the length. A value of 0.5 mils / division is selected for accuracy. Plotting Plane A

first, will prevent confusion in plotting Plane B.

Displacement a Plane A is -12, or the turbine is low to the driven unit j j in this plane. Locate a point 12 mils below the j centerline of the driven unit. Displacement at Plane B, p l driven unit to driver is +e or the driven unit is high to i the turbine by a mile. Since the brackets were reversed, or different relationships were measured, the sign in } reality changed. Connecting points

1. 1 and
2. 2 with a

j straight line that extends beyond Plane B will show the existing elevation of the turbine in relation to the ey$ sting elevation of the driven unit. Next, determine i e in relation to driven unit centerline, should the g-get 4 be located. In this example expected rise is [ souped to be 15 mils, hence turbine must be set low to he, driven unit by 15 mLis. An additional line is i aptructed parallel to the extended driven unit etterline, but offset low 15 mile, using same vertical ) egle as before. l We u i } TERRY CORPORATION 4-1 I i l i _. _. _ ~ _ _. _ _

i PROCEDURES FOR ALIGNMENT OF TURBINES TO DRIVEN EQUIPMENT BY REVERSE INDICATOR METHOD CONTINUED.... 1 This in the desired elevation. Where the turbine is a versus where is it desired to be is determined by I comparing points #3 and #4 to where the desired centerline l intersects with Planes IBF and OBF respectively. Point #3 I is 9.5 mils high and point #4 is 23.5 mils high. These are the amounts of shims to be removed from under the inboard and outboard turbine feet respectively. Determining offset displacement is done in a similar i fashion. Direction for this example is established based l upon North in relation to the driven unit. Place the i direction on the graph. Considering turbine to driven i unit readings, the turbine is displaced to the North by 4 ) mils at Plane A. This value is plotted above the driven l unit reference centerline, point #5, using same scale of I 0.5 mils / division. Driven unit to turbine readings at Plane B reveal that the turbine is displaced to the North i by 2 mils, point #6. Again connect points #5 and #6 to determine points #7 and

1. 8.

A coll of 8 mils of the turbine to the South is anticipated. The desired offset centerline is established and once again the displacement at the feet is established. The inboard feet. Plane IBF, l should be moved to the North by 7.5 mils, the outboard l

feet, Plane OBF, to the North by 9.5 mils.

The total correction required for the shim,chan and lateral move -9.5 and P 7.5,)ge i would be: Inboard Feet Outboard Feet -13.5 l and N 9.5. V ~- One Foot at a time, using dia1\\ E. MAKE SHIM CHANGES } indicators placed at Planes IFB and OFB, from base to j turbine, in order to monitor lateral movement of turbine. i C. CONFIRM RESULTS OF SHIM AND LATERAL MOVE CHANGES Always recheck alignment after making changes to ensure proper results. O E E m E t TERRY CORPORATION 4-8

'la$lhalts in perfect alignnung (b) Parallel' Offeet b seed how@ . %,ed here @ Ot-s s}q ( 01 % -f7 qi ea e(,s J '*y..,3 e a p ;y, p{ H T y; - m*e 3d we 6.. 6.. -,.6. -.. 6.... (c) Angular Misalignment I I h) Parallel offset and angular misalignment JeBar with us @ r 6,,,' I' 8"d b' b ]g,,,, Y14 ant =% deem ~ l et emner t--l. is ;- _.y, e M.

LL_

, 'l~. ,,. Ce=**=. ,_1 8 m --- g,, z ~ 1 s e I1Y.D~L -e4 -gg fee +4s "Il -13 +8 C +8 .g +ge - 14 +16 T 6me e eday A se no esseene ase amed Figure 1. Illustration of Perfect Alignment. T*/ pes of Misalignment, and Support Bar Saq. (No horizonal offset assumed) N CNPWATICH 4-9

i i CUS'!ONER USER IDCATION TURRINE TYPE 3ER. NO. GEAR TYPE SER. NO. OTHER UNIT TYPE SER. NO. MANUFACTURE N.S. CalPLING TYPE COUPLING GAP DYN BAL L.S. COUPLING TYPE COUPLING GAP DYN BAL l THEORETICAL THERMAL GROWTH TURBINR NORISONTAL CENTERLINE RISE CASING SUPPORT GEARJBORISOMTAL CENTERLINE RISE NORISONTAL OFFSET GEAR PINION w*rr "H SULL GEAR END FLOAT OTHER (EfIT NORISONTAL CE8FFERLINE RISE CASING SUPPORT SMIM PACE TOTAL THICKNESS 4 l UICER TUR5INE FACING COUP END: L.M. FOOf R.H. FOOT UNDER TURSINE FACING STEAM RING L.M. FOOT R.M. FOOT UNDER GEAR: BULL GEAR SIDE TURBINE De SLANE END PINION SIDE i UNDER OINER UNIT FACING DRIVEN END L.R. FOOf R.M. FOOf UICER OTHER UNIT FACING FREE E3E3 L.H. FOOT R.M. FOOf REVERSE IICICATOR READINGS (CORRECTED FOR SAG) AMBIEfff TEMP O DIRECTION OF RCrrATION OUTLINE OWG. NO. l TURRINE AND PINION GEAR TURRINE AND PINION GEAR COUPLING RUNQUT 3 FACING TURRINE N.S. COUP FARING PINION GEAR K.S. COUP. Turbine Hub Face Pinion Hub Face _ 12V 12V l Gear Hub Face Driven Unit Hub Face 38 9E

H Indicator Support r

Sracket Sag (pl) i Bracket Sag (02) 6V 6V GEAR A85 DRIVEN UNIT GEAR AAC DRIVEN UNIT FACING GEAR LS COUP. FACING DRIVEN UNIT LS COUP. l 12V 12V 9:: 3H 9H 3H l CHECKED BY 6V 6V 0 ATE l i h TERRY CORPORATION 4-10 1 _-__r._-~,,_, ,,---%, - - -. ~,, -, _ - - _. -,. -,, -, _ _ .-----,,_-.-w

e 1 l DRIVEN TURBINE UNIT ,l w m & 43" 26" 45" y A B INBOARD OUTBOARD FOOT FOOT N y Initial Reverso Indicator -8 A -16 +6 B +10 r-Readings Corrected for Support Bracket Sag. s -14 +16 DESIRED HORIZONTAL Ol:FSET TL RBINE g FYISTINc in DRIVEN ,77 OFF9pT gggt3 ~6 q p 8 ~ - - ~ ~ ~ ~~~ UNIT 15 MILS 'l DESIRED ELI VATION V ~ 0F TURB; NE 1"/DIV. % A 11 IBF OBF Figurc 3. Sample Plot of Relative Shaft l'osi t ions TERIOf CORPORATIOi ~4-11 l

PARTS LIST Tv et. os-2N 128860E FILE: R1001N/F37696AB SECTION DR AWING NO. O TERRY NO. YOY NAME OF PART N SER S EC TYPE GRADE U IT 001 LEVER, TERMINAL SHAFT 88024803 STEEL 1 5 002 LOCKWASHER SHAKEPR00F 75287A STEEL 1 003 PIN, GOV. LEVER EXTENSION 59370 EM-31 ASTM:A276 S41000 1 STEEL / 004 END, HEIM R00 HFR-8 75208A15 UNIFLON 1 LOCKNUT, FLEXLOC .c- 00c g; 3/8-16 75233A06 STEEL 4 8' NUT, HEX. JAM R.H. ml 006 1/2-20 75324A07 STEEL 2 007 R00, CONNECTING 1/2 0 65131 EM-124 ASTM:A108 G11170 1 NUT HEX. JAM L.H. . 008 1/2120 75325A07 STEEL 1 57 EEL / $ 009 END, HEIM ROD HFLR-8 75208A16 UNIFLON 1 010 WASHER PLAIN 1/2 0 75344A09 STEEL 2 011 L0cv30T. et Fxt Oc 1/2-11 75233A07 STEEL 1 012 PIN 112829801 EM-31 ASTM:A276 S41000 1 013 SPRING, EXTENSION 32128 EM-122 ASTM:B221 6061-TG 1 014 BRACKET SPRING HOLDER 128726C01 EM-102 LC STEEL COMM. 1 015 LEVER, GOVERNOR 128725C01 EM-102 LC STEEL COMM. 1 016 STUD, SPRING 112830B EM-124 ASTM:A108 G11170 1 017 NUT, HEX JAM 1/2-13 75266A05 EM-88 ASTM:A194 2H 2 018 GOVERNOR, WOODWARD PGG 128727A01 1 019 HUB CITY GEAR BOX 68216A01 1 020 SHAFT, VALVE LEVER 95760A STN STL 410 1 021 1/4 x 1 1/2 LG. KEY 49337 EM-90 ASTM:A108 1018 2 WASHER GARLOCK DU BRG. 022 40020 75201A63 MATERIAL 2 023 PIN, LEVER PIVOT 92759B EM-31 ASTM:A276 S41000 1 REv REv ECM ECN oRAWN .JS.5/16/84 TE7WEY Ta^cso MF.1 .,g.. $novEo @ h s M o' *cm*** W ' oWG No 128861A sNT 1 or 3

PARTS LIST rvpo es-2N mm: R1091N/F37686AB SECTION DRAWING NO. 128860E o TERRY NO O NAME OF PART NUM8ER S EC TYPE GRADE U 1* 024 NUT, HEX JAM 1/2-13 75266A05 EM-88 ASTM:A194 2H 4 5 SCREW, S0C. HD. CAP ALLEN 0Y 025 1/4-20 x 1.00 94582A03 EM-87 CCMM. 4037/4140 1 026 CRANK, CAM 949410 EM-102 LC STEEL COMM. 1 hT 027 WASHER, GARLOCK 00-10 75201A56 1 0U BRG. 5 0 28 BUSHING, GARLOCK 12-DU-12 75201A26 MATERIAL 2 029 PIN, CRANK PIVOT 927608 EM-31 ASTM:A276 S41000 1 l 030 SUPPORT, CAM CRANK 93271E EM-102 LC STEEL CCMM. 1 hriZE 031 END, FEIM ROD HF-8 75207A15 1 hhhE 032 END, HEIM R00 EM-8 75209AIS 1 BUSHING, GARLOCK OU BRG, 033 20-00-12 75201A39 MATERIAL 3 034 LEVER, GOVERNOR 932968 EM-102 LC STEEL Cor+t. 1 035 PIN 63113 Of-31 ASTM A276 SJ1000 1 036 STEM, VALVE 95923B EM-59 43 jp7g g41ggg 1 ~ 037 GUIDE, UPPER VALVE STEM 95757A EM-31 ASTM:A276 541000 1 ~ 038 BUSHING, VALVE STEM CONN. 95759A EM-31 ASTM:A276 S41000 1 039 CONNECTOR, 5 ALVE STEM 95758A EM-31 ASTM:A276 541000 1 HEIM,8 SPHERICAL BRG. 040

• LSS-75439A07 STEEL 1

041 GUIDE, LOWER VALVE STEM 95756A EM-31 ASTM:A276 S41000 1 SCREW, S0C. HD. CAP 042 1/2-13 x 1.50 94584A05 EM-87 COMM. 4037/4140 4 043 BONNET, COV. VALVE 902580 EM-01 ASTM:A216 WC: 1 044 NUT, HEX. 1 1/8-7 75139A13 EM-88 ASTM:A194 2H 24 04 5 STUD BOLT 1 1/8-7 x 8.00 63120 EM-13 ASTM:A193 B7 10 046 STUD BOLT 1 1/8-7 x 8.50 66606 EM-13 ASTM:A193 B7 2 "'Y "EV ECN ECN ORAWN dS.5/16/84 gg TEIRY ta^cto IppnCvt ENS 128861A 2 3 owGNo ,gy o,

GS-2N PARTS LIST Tvee 128860E nom R1091N/F37686AB sECTioN OMAWING NO. O TERRY NO. NO NAME OF PART NUMBER SPEC TYPE GRADE U 17 n f 60 047 912000 EM-01 ASTM:A216 WCB 1 g 048 WASHER, GARLOCK 0U12 75201A58 STEEL 1 049 WASHER, GARLOCK 0010 75201A56 STEEL 1 050 WASHDI 106969A08 STEEL 2 PIN, TAPER #6 051 x 3.00 LG. 75108A34 STFFI 2 h 052 STUDBOLTf[8G y 13472 EM-13 ASTM:A193 B7 8 8' ALLEN 0Y d 0 53 NUT, ALLEN 1*-8 75176A11 EM-87 COMM. 4037/4140 8 0 54 GASKET, R-1 ISP FLEX 75286A02 STN STL 1 055 GASKET R-1 15L FLEX 75286A01 STN STL 1 f M00. 056 VALVE SEAT 79181C r.M-59 ASTM:A276 S41000 1 057 VALVE 3" VENTURI 90076D EM-125 ASTM:A276 S44004 1 h" "$h 0 58 VALVE SLEEVE 79180C01 EM-50 1 059 NUT, HEX 3/8-24 105564A STEEL 1 060 BUFF.ING, GUIDE 79344A01 EM-125 ASTM:A276 S44004 2 P-55 061 SPACER, BONNET 64843 PURE 30N 22 M00. 062 WASHER, FLAT 54846 EM-59 ASTM A276 54100n ?n RING. TRUARC SNAP 063

n. 000 112 7 5144A21 STEEL 2

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CONTROL SYSTEM GOVERNOR (Woodward Type PGG) The governor controls turbine speed by controlling the amount of steam supplied to the turbine. Speed control is isochronous, i.e., the governor will maintain constant turbine steady state speed, within the capacity of the unit. regardless of load. GENERAL The governor is of the mechanical hydraulic type, driven by the turbine rotor through spiral reduction gears. The governor contains a gear type oil pump and reservior for supplying oil under pressure to the remote servo. Internal spring loaded accumulators maintain oil pressure and act as relief valves. A spring loaded, mechanical flyweight head assembly, is driven via a rotating power cylinder assembly. Oil under constant pressure is maintained on the smallest surface area of the servo piston. Oil, acting on the largest surface area of the

piston, is either under supply pressure, to drain or locked according to the position of the pilot valve.

The action of the servo is a " push-pull" motion. In this application, movement of the servo rod in an upwards direction causes a decrease in turbine

speed, whereas, a

downward movement will cause an increase in speed. For more specific details of the governor operation and maintenance, refer to the Woodward Governor bulletins in this section. The function of the governor is to sense and control turbine speed over a varying range, maintaining speed constant with varying load for any setting. The governor is designed to meet the operating requirements of the installation as long as the load does not exceed design capacity. The operating speed can be varied either by local manual setting or by varying a pneumatic signal to the governor from a remote control position. TERRY CORPORATION S.I.C.S. Section 6 REV. 1-82 6-1

I CONTROL SYSTEM CONTINUED.... T l l lun: Manual operation is not to be used in conjunction with pneumatic or vice versa. i SPECIAL GOVERNOR NECHANISM FEATURES 4 GENERAL } The speed at which the governor will control is determined by the force exerted on the toes of the flyweights by the speeder spring in the basic governor section. Speeder spring force is determined by the position of the piston in the speed setting cylinder. The position of the piston, in turn, is determined 4 by the volume of oil trapped in the area above the piston. The direction and rate of oil flow into or out of this area is I controlled by the speed setting pilot valve plunger with is i mechanically linked to the bellows. If the plunger is moved i downward, uncovering the upper edge of a metering port in the-bushing, pressure oil is allowed to flow into the speed setting cylinder. This displaces the piston

downward, further increasing speeder spring tension and thus increasing the speed l

setting. If the plunger is moved upward uncovering the lower l edge of the metering port, oil is permitted to drain from the l cylinder. This allows the piston spring to raise the piston. l decreasing speeder spring force and thus lowering the spring setting. l I ACCELERATION CONTR04 l The rate of movement of the speed setting piston over its full downward strike (idle to maximum speed) is usually retarded to i l occur over some specific time interval. This is done by l admitting governor pressure oil into the rotating bushing i j through an orifice which registers with the main supply' port i ) once in every revolution of the bushing. This reduces the rate i at which oil is supplied to the control port in the bushing and l l thus, the rate of oil flow to the speed setting cylinder. The { diameter of the orifice determines the specific time interval I which may be anywhere within a nominal range of 1 to 50 seconds. Thus the rate at which the speed setting may be increased is restricted under all conditions of operation. The i longer rates are generally used with. turbo-supercharge units to permit the supercharger to accelerate with the engine. } I TERRY CORPORATION 8.I.C.S. Section 4 REV. 1-82 l 6-2 1 4'

{ CONTROL SYSTEM CONTINUED.... The rate of movement of the power piston over its full upward stroke (maximum to idle speed) is also restricted on turbo-supercharged units to prevent compressor surge during decelerations. This timing may be anywhere within a nominal range of 1 to 15 seconds. In these cases. the speed setting pilot valve plunger has an additional land (not illustrated) which covers the drain port in the bushing. A vertical slot in the drain land registers with a second orifice in the rotating bushing once each revolution. This restricts the cate at which the oil is allowed to drain from the speed setting cylinder. The width of the slot in the drain land determines the length of tine the drain port (orifice) is open during each revolution and thus the specific deceleration time interval. This particular unit is supplied with a 30 second acceleration bushing. f l TERRY CORPORATION S.I.C.S. Section 6 REV. 1-82 j 6-2

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