gas plant land fill

7/28/2019 Gas Plant Land Fill

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All content, including technical writing,SOPs, graphic design, photography, layout,

and Process and InstrumentDiagrams created by Bob J. Kaplan

Norflux

Landfill Gas Plant

Authors Note - L7-I Bob Kaplan can produce 3D, Isometric, Plan View, or Exploded Drawings of Equipment and Buildings

Practices and Procedures Manual
mailto:[email protected]:[email protected]


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NorfluxNote Norflux is a fictitious company created only for use in this document.

L7-i.com Landfill Gas Plant

Standard Operating Procedures

SOP-LFGP-01


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NorfluxPower Generation

NORFLUX LANDFILL GAS PLANT


NUMBER: BJ K-Trial3.2

REV: May 21, 2003 PREAMBLE Page i

Important Document Information

The contents of this document do not represent any existing facility.

This material may NOT be used without the written permission of the author Bob J . Kaplan

These pages have two main purposes, first, to present an example that can beused as a template for up-and-coming Training Manual Writers and second, togive prospective clients of Bob Kaplan an example of his work on a mid-rangedocumentation project (see project scale level notes on web page).

This manual is an example of a mid-complexity project that stopped short ofincluding section quizzes and a certification exam. For that reason it might moreproperly be considered as an advanced SOP manual rather than a full-blowntraining manual.

The process and instrument diagrams included in the appendix are an advancedoption and were created as a separate project.


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REV: May 21, 2003 PREAMBLE Page ii

These procedures are reviewed annually each November.


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REV: May 21, 2003 PREAMBLE Page iii

SOP Change Submission Sheet

Page # Change Request

123456789

SOP Change Control Sheet

Date Description Page Approval


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REV: May 21, 2003 PREAMBLE Page iv

SOP Locations

Three hard copies of this SOP manual are officially maintained. They are located as follows:

L7-i.com Landfill Gas Plant Office / Control Room L7-i.com Landfill Gas Plant File Area Generating Station Services Managers Office

Approval must be obtained before removing a copy from its assigned location. The documentmust be returned within seven days. The copy located in the Landfill Gas Plant Office & ControlRoom area must NEVER be removed.


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REV: May 21, 2003 PREAMBLE Page v

Initial Sign off and Validations

Reviewed By Bob Kaplan Date: May 08, 2008

Approved By Bob Kaplan Date: May 24, 2008

Operations Approval No Date: N/A

Title: Landfill Gas Plant Standard Operating Procedures


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L7-i LANDFILL GAS PLANT


NUMBER: RJ K-025

REV: May 21, 2003 LFGP SOP Page 1

1.0 IntroductionThe following procedures are a guide for startup, shutdown, and routine operation of the L7-i.comLandfill Gas Plant. They are intended to help insure the safe and efficient execution of theseactivities. Changing conditions may dictate the alteration of certain steps; however, theprocedures as described in this document have stood the test of time in that they maximize safetyand minimize downtime.

Stylized Process and Instrument Diagram


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Creators Note to Potential Customers and/or Employers

Note This page is not part of the Training Manual SOP.

The previous sketch, labeled Stylized Process and Instrument Diagram, is a synthesis of fiveseparate Process and Instrument Diagrams (P&ID).

This note has been included here to bring up important points regarding the utility of such asketch as well as the skills required to produce it.

The diagram, as well as the P&IDs it is based on, was produced from scratch by following andidentifying lines and equipment out in the field. The original image file is a vector graphic ratherthan a bitmapped graphic, which means that it can be enlarged to any size and printed withoutpixilation or any other loss of clarity. Such a sketch is perfect for mounting on a control room wallfor quick reference.

The drawing is the perfect backbone for use in a computer based training application. It can beanimated to show key process flows during different procedures. It was created using Corel Drawand can be saved in most other vector based graphics programs file format (AutoCAD, forexample).

This diagram has been singled out as it demonstrates the advantage of having someone like BobKaplan producing your training material. Bob is a Power Engineer with varied experience as aProcess Operator, Graphics Artist, Technical Writer, Internet Technician, and more. Skills fromeach of these fields were necessary to produce the desired outcome a functional and easy tofollow graphical summary of the entire process. The following is a rough breakdown of the skillsets.

Power Engineering skills were used to draw the P&IDs properly

Process Operator experience provides the experience to choose the appropriate content,ensuring that only the most important components were included to reduce clutter. Thismakes the sketch not only an excellent training aid, but also an invaluable reference toolfor use during process upsets and emergencies.

Technical Writer experience determined that the value of the sketch in helping to explainthe process was high enough to justify the additional time and expense used to create it.

Graphics Artist experience was needed to determine the most effective color scheme andplacement of components in the sketch - it also made sure that the proper drawingprogram was selected and that it was used in a quick and efficient manner.

Internet Technician experience was needed to determine the most effective way todeploy the sketch on a website or web based training program.

It is rare to find one person with all of the skill sets necessary to complete a USEABLE training

manual for industries such as Pulp and Paper, Oil and Gas, Petrochemical, and otherManufacturing sectors. It is rarer yet to find someone who also has significant experience increating software help files; user manuals; emergency procedures; computer based trainingmodules; business process analysis and documentation; QC manuals; FAQs; plant-site energydistribution analysis and documentation; web pages; and web applications. It is rare, but notimpossible; Bob Kaplan has all of this experience and more. Having all of these skills applied toyour training project ensures that you receive the best value and a quality outcome.

Bob Kaplan also has significant experience creating documentation in a team environment asboth team leader and as a valuable participant. Contact Bob at [email protected]
mailto:[email protected]:[email protected]


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NUMBER: RJ K-025


1.1 Process Overview

1.1.0 Main Process

Summary

Blowers, located in the Landfill Gas Plant (LFGP), apply suction to a network of methane richwells located throughout the L7-i.com Landfill. The blowers discharge into the initial gaspurification section that provides cool, dry and H2S free feed at low pressure to the main gascompressor(s). The compressor discharges into a 12-tray bubble cap contactor tower thatproduces high pressure dehydrated gas into the main sales line. The current end-use of the gasis to supplement natural gas usage at Norfluxs L7-i.com Generating Station.

Simplified Process Flow Diagram


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Details of Main ProcessThe anaerobic decomposition of the organic waste component of the garbage buried in the landfillproduces Landfill gas - abbreviated as LFG. The gas is primarily composed of methane andcarbon dioxide; however, a small yet significant percentage of highly toxic compounds such ashydrogen sulphide and BTEX are also present. In the absence of a collection system, LFG canhave a significant negative impact on the environment by creating toxic conditions, offensiveodors, and causing stress to local vegetation. The gas also poses a significant explosive hazard.Not only does it make sense to properly dispose of the gas through incineration, but it alsobecomes a significant asset when its disposal generates electricity. It should be noted thatMethane gas is 21 times more potent than Carbon Dioxide as a greenhouse gas so it is importantto eliminate this contributer to global warming through the process of combustion.

LFG is collected in the L7-i.com landfill by a network of perforated wells and piping connected toa 14 main plant inlet line. A vacuum pressure of negative 1-2 psig (7-18 kPag) is applied to theinlet line, which in turn creates a constant suction on the entire collection system. Centrifugalblowers, located inside the plant, create the vacuum.

The LFG, saturated with water, discharges from the wells at temperatures typically around 60-90F (16-32C). As the water saturated gas flows towards the plant, it cools below its dew point,causing the water to condense throughout the collection system. Several strategically placedcondensate drains on the field flow-lines discharge most of the water back into the landfill refuse.

The remaining free water, as well as particulates composed of clay, soil, and fine refuse, areentrained with the LFG as it flows into the main plant inlet. In addition, other chemicals, in bothliquid and gaseous form enter the plant with the LFG. Portions of these additional chemicals arepotentially toxic, including hydrogen sulfide (H2S), and a combination of benzene, toluene, ethylbenzene, and xylene (BTEX).

CAUTION:

Every effort should be made to ensure that personnel do not come into direct contact with thesechemicals without adequate personal protective equipment. Potential pathways of exposureinclude inhalation, ingestion, and skin contact. Take appropriate safety precautions when thepossibility of contact exists.

Various plant safety related issues, practices, and procedures are beyond the scope of thisdocument. Refer to appropriate safety literature and always use safe trade practices.


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From the inlet line, LFG flows into the vertical hydro cyclone recirculating Inlet Separator (V-100).By design, V-100 removes almost all entrained water at inlet conditions and 80% of particulatesgreater than 10 micron in size. The vessel is equipped with a sight glass that indicates the liquid

level. When a level is detected, it is pumped out to the flare header by the manually operatedcentrifugal base pump (P-877).

Inlet Separator Piping Sketch


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Gas leaving V-100 enters the main Blower Suction Header (H-804), which is a cylindricalhorizontal vessel equipped with a sight-glass and tie-in to the inlet separator pump. In the unlikely

event that a liquid slug passes overhead from V-100, it will collect in H-804; thus offering adegree of protection for the blowers.

Plant Inlet Piping

Three 75 hp Blowers (K-100, K-101, & K-102) draw a vacuum directly on the suction header, and

thus indirectly on the inlet separator, inlet header, and the entire landfill gas well network.Normally there are two blowers running, feeding one reciprocating compressor, but the plant PLChas flexibility to run one, two, or three blowers and one or two compressors depending on gasflow-rates into the plant. Each blower has a rated capacity of 1280 CFM. Three suction linebutterfly valves set the blower flow rates.

LFG discharges from the blowers at 1-7 psig (10-50 kPa). The compressing effect of theblowers imparts substantial heat to the gas, with temperatures of 160-175F (74-80C) beingtypical. The heated LFG is passed through the Pre-clean Gas / Glycol Heat Exchanger (HE-100)to increase efficiency through the compressor(s) and to aid in removing water. HE-100 is a twopass shell and tube heat exchanger equipped with stainless steel tubes. Gas flows through thetubes and cooled ethylene glycol circulates through the shell. HE-100's gas inlet PSV protectsboth it and other associated equipment from excess pressure.

Plant Inlet Header

Inlet Block Valve

Blower Suction hdr

Blower Suctions (3)

V-100 Outlet


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Process Flow from Blower Suction Header to HE-100 - Sketch

NOTE:

All plant effluent sources liquids and gases are connected to the main flare header. Refer tothe Flare Effluent heading in this section for more detailed information.


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Cooled gas and condensed free liquids exit HE-100 and enter the Pre-clean Contactor Tower (V-110), the primary function of which is to remove hydrogen sulfide (H2S). It also functions as waterwash tower. V-110 is a packed vertical tower with H2S scavenger chemical injected into its upper

section. The H2S scavenging agent flows down the tower counter current to the uprising gasstream, absorbing H2S along the way. The scavenger is spent over time and must be replenishedon a daily basis. Enough fresh chemical is added to keep the sales gas concentration of H2Sbelow 15 ppm. Fresh water is also added daily. The water captures particulates from the gasstream and helps to keep the H2S scavenger chemical from forming hard deposits in the towerpacking. To prevent high viscosity liquids and particulates from building up in the base, the towerbottoms are periodically pumped off to the flare line.

After exiting the top of V-110, the gas stream enters the Pre-clean Knockout Separator (V-200), alarge knockout vessel that removes liquid mist particles from the gas stream before it enters thecompressors. The liquids that collect in the bottom of this vessel are also periodically pumped tothe flare header. In winter months, this may be necessary every two weeks.

V-110 Pre-clean Contactor / H2S Removerand V-200 Pre-clean Knockout


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The sweet, dry, and cool gasleaving V-200 enters the inlet lines

of the J oy ReciprocatingCompressors (K-200 & K-210). Thetwo compressors are identical. Eachis a two-stage design withintercoolers between stages. Theyare driven by 300 HP electric motorsrotating at 585 RPM. Maximumdischarge operating pressure is 125psig (862 kPag); however, the plantpressure controllers PCV-100 andPCV-101 keep the dischargepressure at 90-97 psi (620-670kPa). The intercoolers tubes are

composed of stainless steel. Seeattachment section and the followingpage for more images of LFGCompressors.

The compressors are protected bythe following shutdown initiators:

High gas pressure High gas temperature Murphy high vibration High lube oil temperature Low lube oil level Low lube oil pressure

In addition, each compressor is equipped with a pressure relief valve on its discharge.

A recycle line equipped with a pneumatic control valve (FCV-831) allows thegas to be recycled from the compressor discharge back to HE-100 inlet. FCV-831 allows the compressor(s) to run without surging when the total plantthroughput is lower than the surge point. The controller takes its flow signalfrom the same differential pressure (DP) element that supplies the sales gaschart. The valve fails open. On manual control, 15 psi is closed, zero psi is wideopen, with 10 psi being the most common operational setting. When onautomatic, the controller is set to a desired DP; the valve opens when the DPdrops below the setpoint, increasing the flow through the compressor. Seeattachment section for more images of this system.

Gas Compressor

FC-831


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Both LFG Compressors

East Side of East LFG Compressor

Panel Gauges

North High Pressure Cylinder

Low Pressure Cylinders

Gearbox / Drive

HP Outlet (North End)

South High Pressure Cylinder

Inlet Header

Inlet Header

Intercooler

Electric Motor Driver

North High Pres. Cyl

North Low Pres. Cyl


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Upon discharging from the compressors, the gas enters the Gas/DEG Heat Exchanger (HE-300);a single pass shell and tube exchanger which acts to recover waste heat. Heat generated fromLFG compression passes from the shell side to the tube side where it is used to preheat the main

gas-dehydrating chemical, Diethylene Glycol (DEG), as part of the DEG regeneration cycle. Thisexchangers tubes have also been upgraded from carbon steel to stainless steel.

After giving off some of the heat of compression in HE-300, the gas is further cooled in HE-310.This heat exchanger is a two-pass shell and tube design with upgraded stainless steel tubes.Cooled ethylene glycol is circulated shell side and the LFG flow is tube side.

High Pressure Landfill Gas Coolers


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From HE-310, the gas enters the base ofthe main contactor tower (V-300). This

tower has a bottom free water knockoutsection that collects water that hascondensed out of the gas stream due to theupstream cooling by the two heatexchangers. The water is dumped dailythrough a manual one-inch ball valve to theflare header.

The main section of the tower is equippedwith 12 bubble cap trays with stainless steelcaps on the bottom half trays. There is astainless steel mist pad at the top of thetower. Diethylene glycol (DEG) is circulated

through the tower starting at the top tray.The DEG absorbs water as it cascadesdown through each tray until it reaches thebottom chimney tray, at which point it issaturated with water. This Rich DEG isdischarged from the tower to continue itspath to the DEG regeneration system. Asthe LFG travels up through the tower itbecomes increasingly dry until it is almostcompletely dehydrated as it discharges offthe top.

The dry gas stream next enters a liquidknockout drum (V-330) that helps removedroplets of DEG carried overhead with theLFG. It also serves to catch liquid slugsduring system upsets. V-330 is alsoequipped with a demister, sight glass, and

drain.

To further remove fine liquid mist out of the gas, a coalescer filter pot (V-340) is installeddownstream of V-330. It holds six coalescer filter elements that must be changed periodically. It isalso equipped with two liquid drain off points - an upper and lower - that must be operatedperiodically. At a differential of 12 psi (84 kPa), the filter elements must be changed out or liquidswill re-entrain into the gas stream.

V-300 Main Dehydration Contactor


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From V-340, the LFG is metered through an orifice plate differential flow meter where it iscontinuously charted on 7-day circular paper chart (FR-01). The static and differential pressures

(PR-01) as well as the gas temperature (TR-01) are recorded on this chart. From this data, anaccurate pressure and temperature compensated flow rate can be calculated using amathematical formula.

V-330 Overhead Knockout Pot, V-340 Coalescer Filter, and Pressure Controllers

Two Kimray backpressure controllers act in complimentary fashion to maintain plant and salesgas line pressure. PCV-100, which outlets to the sales gas line, is set at 75 psig. PCV-101, which

outlets to the flare line, is set at 90 psig. An example of how these PCVs work is as follows. If thesales gas line is blocked in, the plant pressure will rise and PCV-100 will open in an attempt tolower it by sending the gas to the sales gas line. Since it is blocked in, this will have no effect andthe pressure will continue to rise. When the pressure reaches 90 psig, the setpoint of PCV-101,PCV-101 will open up to the flare line; thus putting all of the plant gas flow to flare, whilecontrolling the plant pressure at 90 psig. When the sales gas line is unblocked, PCV-100 willbleed off plant pressure to it until it reaches its setpoint of 75 psig at which point it will begin tocontrol the pressure at the lower setpoint. Meanwhile, PCV-101 will close completely as the plantpressure will be well below its setpoint of 90 psig. Flaring will cease.

After metering the LFG, it exits the plant into an underground HDPE line and flows into the L7-i.com Generating Station Custody Transfer Station. A liquid knockout vessel that requiresoccasional emptying into a plastic storage tank is situated immediately inside the generating

station. The gas is metered through a turbine meter at the generating station. Water and H2Sconcentration, as well as the heating value, are also continuously monitored. From here, the gasflows into one or both of two boilers where it is burnt to generate steam.


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1.1.1 Diethylene Glycol (DEG) System

After absorbing water in Main Contactor Tower (V-300), the rich DEG, i.e. DEG saturated withwater, flows from the towers chimney tray through the Rich DEG filter (V-120) and the chimneytray level control valve (LCV-1) to the LFG/DEG heat exchanger (HE-300). In HE-300, the DEGabsorbs heat from the hot gas leaving the compressors. From HE-300, the DEG flows to the DEGRecovery Still (V-312) and its direct-fired reboiler (HE-311).

Diethylene Glycol (DEG) System

The DEG Recovery Still (V-312) or DEG Stripper is a relatively small distillation column withstainless steel pall packing rings. The packing functions as both separation media and amechanical defoamer. The upper portion of the column contains an integral reflux condensersection. A direct-fired reboiler (HE-311) provides the tower base-heat that drives the water, gas,

and light ends components up the column from the Rich DEG feed-tray at the base of the column.These lighter components flow overhead to the flare knockout tank; the heavier DEG componentfalls down to the reboiler.


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DEG Recovery Still (V-312) and Gas Fired Reboiler

Tower Packing: Pall Ring Gas Fired Reboiler West Side

The Reboiler section consists of two horizontal cylindrical vessels connected by a downcommerpipe. The lower vessel (V-311) contains dehydrated DEG (Lean DEG) and functions as anAccumulator, from which the DEG pump(s) take suction. The upper vessel contains the gasfired reboiler firetube element that heats the incoming Rich DEG (saturated) for distillation. Theliquid outlet side of the upper vessel is equipped with a weir that maintains the optimum levelrequired to ensure that the reboiler firetubes are always submerged - thus preventing overheatingof the firetubes. The mostly dry DEG in the top reboiler vessel overflows the weir and fallsthrough the downcommer to the lower vessel (accumulator). A small amount of dry LFG issparged into the accumulator to absorb any remaining moisture. The sparge gas travels upthrough the Reboiler/Still and overhead to the flare K/O tank with the rest of the tower overheads.

Burner Exhaust Stack

Internal Reflux Condenser Section

DEG Recover Still Main Section

Reboiler Firebox / Firetube Area

Pilot and Burner Access Port

Exhaust Stack

Lite-off Port

Burner Gas Piping


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Gas Fired Reboiler (V-312) and Accumulator (V-311)

The reflux condenser, a double looped stainless steel tube, is located in the top section of thetower. It can be activated to condense a portion of the vapor so that it refluxes down the column;ultimately helping to purify the rising vapor before it exits the top of the tower. A sidestream ofcooled lean DEG is fed into the U-shaped condenser tube-side to provide the cooling. It has beenshown that this system is of limited benefit and is therefore seldom put in service.

Diethylene Glycol (DEG) Pumps and Piping

The lean DEG in the Accumulator flows to the suction of the Lean DEG pump(s) (P-100 & P-310)and is pumped through the DEG Cooling Tower (HE-330). The primary element in the cooling

Reboiler HE-312

Reboiler Si ht lass

Downcommer

Accumulator V-311

Lean DEG Outlet

To Cooling Tower

Coolin Tower B ass

From Cooling Tower

DEG Pumps

Cooled DEG to V-300

DEG from Accumulator

Pum Dischar e Line(s)

To Reflux Condenser


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tower is a closed loop heat exchanger section, where the DEG passes through a bank of tubesthat transfer heat to the evaporating spray water falling counter to the air flow from the forceddraft fan at the tower base. The unevapourated spray water is collected at the base of the tower

and recirculated back to the spray nozzle headers by the spray water pump. Any water losses aremade up for by a flow of fresh water, controlled by an internal level float, from the external waterstorage tank. In the winter months, the cooling tower is operated dry with the spray watersystem deactivated and drained.

DEG Cooling Tower Spray Pump DEG Cooling Tower Forced DraftFan

External Water Storage Tank EG & DEG Cooling Towers

From the cooling tower the cooled lean DEG flows through a globe valve, which is used tomanually set the flow to V-300. The flow-rate is indicated locally by a turbine flow meter (FQ-05).Prior to starting the cycle again by flowing into the upper portion of the Main Contactor Tower (V-300), particulate matter is removed in the Lean DEG Filter (V-121).

LevelFloat

Access

SprayWaterPump

EG CT DEG CT


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DEG Addition To V-300 Piping

A small carbon filter (V-350), used to remove liquid hydrocarbons, takes a slipstream flow of leanDEG from the filtered DEG entering the contactor tower. After passing through the filter, thisslipstream joins with the rich DEG as it enters the heat recovery exchanger (HE-300).

V-350 DEG Slipstream Carbon Filter

V-300 Main Contactor

DEG Globe Valve

DEG Flow Meter

Hat Tray Level Control

Lean DEG Pum s


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1.1.2 Ethylene Glycol (EG) Cooling System

Plant cooling is supplied by a closed Ethylene Glycol (EG) circulation system, which cools thefollowing:

Compressor Intercoolers Compressor J acket Coolers Compressor Oil Coolers HE-100 Pre-clean Gas / Glycol Cooler HE-310 Contactor Precooler / Compressor Aftercooler

Cooled EG is pumped from the EG Receiver to a main header where it flows to the various heatexchangers to provide cooling, the heated EG outlet from these exchangers joins in a commonheader that flows to the EG Cooling Tower. The EG Cooling Tower is almost identical to the DEG

Cooling Tower as described previously. After being cooled in the tower, the EG flows back to theEG Receiver where it starts its cycle again.

During normal operation, the EG Receiver level is constant; any change in level indicates aproblem. An atmospheric vent at the top of the EG Receiver has been fitted with extension pipingthat outlets near the east side of HE-100. Any flow from this outlet indicates a cooler is leakinginto the EG system. A loss of level in the EG Receiver indicates either an EG piping leak or atube leak in HE-100, which operates at a process side pressure that is less than the EG system.

EG Circulation Pumps

H2S ScavengerStorage

West EG CircPump

East EG CircPump

HE-100 Pre-clean GasCooler

EG Inlet to HE-100 throttlevalve


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1.1.3 Flare Effluent System

The majority of plant equipmentcapable of producing gas or liquideffluent has connections to themain flare header. This headerdischarges into the under-groundFlare Knockout Tank (V-420),located a few feet upstream of theflare-stack inlet. Liquidsaccumulate in V-420 while gasespass through to the 38 ft (12meter) flare stack (S-400) wherethey are incinerated.

V-420 is a double walled fiber-glass vessel with a retractableprobe installed between the innerand outer walls. This probe iswithdrawn regularly and checkedto ensure that it is completely dry.

The presence of liquid indicatesthat the inner hull is leaking, atwhich point the vessel would haveto be taken out of service forrepair. In this case, the vesselshould be shutdown and emptied

as soon as possible as a failure of the outer wall would release effluent to the environment.

The liquid level in V-420 is monitored daily. Its maximum capacity is 3,500 imp gallons (15,750liters). A liquid waste disposal company is called in to unload the tank when its level approachescapacity. The vessel is equipped with a 160 l/min Effluent Unloading Pump (P-120) that takessuction from the bottom of the tank and discharges to the unloading standpipe. The standpipe islocated near the southwest gate of the plant site. The liquid effluent is transported by tanker truckto a hazardous waste disposal facility.

The flarestack is equipped with a flame arrestor that prevents a backflash ignition in an area otherthan the top of the stack. An electric igniter on a one-minute timer ensures that the flame isreestablished quickly should it go out. A thermocouple installed near the windguard senses aflameout and triggers an alarm in the control room.

Refer to PID LFGP-05 from more information.

Flare Knockout Tank and Stack


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Flare Stack Burning Full Flow of Plant Gas


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2.0 Purpose

The primary purpose of this Standard Operating Procedure (SOP), and it component procedures,

is to assist plant personnel by providing systematic process operating instructions. It functions as

a reference for experienced personal and as a training aid for new operations staff.


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3.0 Definitions

BTEX Benzene, Toluene, Ethyl benzene, and Xylene volatile monoaromatichydrocarbons which are commonly found together in crude petroleum;they are also a component of crude landfill gas. Generally consideredharmful to health.

Bubble Cap Tray A bubble cap tray has riser or chimney fitted over each hole, and a capthat covers the riser. The cap is mounted so that there is a spacebetween riser and cap to allow the passage of vapor. Vapor rising throughthe chimney is directed downward by the cap, through slots on its side,and bubbles through the liquid on the tray.

Chimney Tray Dehydration Contactor - A circular metal plate, with a large chimney in thecenter used to collect liquid (rich DEG), without preventing upward flow ofvapor (wet LFG) from the feed zone below.

DEG Diethylene Glycol Absorption MaterialEG Ethylene Glycol - CoolantHDPE High Density Polyethylene Plastic piping materialLFGP Landfill Gas PlantLFG Landfill Gas in any stage from raw well gas to sales gasSOP Standard Operating Procedure


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4.0 Responsibilities

Unless otherwise stated in a procedure step, the execution of all tasks described in this document

are the responsibility of the attending Gas Plant Operator; the designation of whom is at the

discretion of the LFGP Superintendent.

These procedures, and any future changes made to them, must be signed off by Landfill Gas

Plant Superintendent to be considered official.


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5.0 Routine Checks and Act ivi ties5.01 Daily

Step Key Points

1. Complete daily checks and logsheet round. Record readings on the daily run log whenappropriate.

2. Check for leaks throughout the plant. A LFG leak into the plant will first show up onthe PLC panel hydrocarbon sensor. Careshould be taken when first investigating ahigh hydrocarbon in ambient air alarm.

3. Check LFG analysis printout. Ensure that oxygen is well below 4 %. Look for signs of air leaks into system by

observing ratio of oxygen and nitrogen.

4. Check blower suction header pressure andtemperature

Pressure should be 8 to 20 kPa @ normalflow rate; pressure can fluctuate due to watermovement in the system.

5. Check Inlet Separator V-100 gage-glass level. Pump out if level at half glass. See Routineprocedures.

6. Check blower motor temperatures by briefly placinghand on housing.

It should be warm, not hot, to the touch.

7. Check blower discharge temperature ~75C

8. Blowers: Listen for abnormal sounds and check forexcessive vibration.

9. Check inboard blower bearing temperature by hand oruse gun thermometer.

Temperature should be ~150F (66C).Temperature greater than 175F (79C) isexcessive.

10. Add water and H2S scavenger chemical to V-110,pump level to flare header if required (every 3 weeks).

Water must be added immediately if no levelis shown on sight glass. In the winter, fill totop of sight glass. In summer, add scavenger

chemical and water to top of gauge glassplus 100 usg by meter. See SOP.

11. Check V-110 Inlet temperature and adjust HE-100 EGinlet valve as required to maintain 18-22 C

When V-110 inlet temperature drops below18C an undesirably large amount of waterwill condense in tower.

EG valve is sensitive, start by moving itabout one cm than make moves of 1/10 cmat a time.


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Step Key Points

12. Check blower discharge pressure and temperature

gages located near V-110.

Normal Temp: 65 - 85 C

Normal Pressure: 10 40 kPa

13. Check V-200 level and pump to flare when greater than glass.

See routine procedures.

14. Check glycol pump discharge temperature. Note on logsheet, investigate if high.

15. Check inside water tank level. When external water tank is out of service forwinter, the internal tank must be filled bycalling a water truck in. Truck should becalled in for next day when level is


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NUMBER: RJ K-025


Step Key Points

25. Check that lean DEG flow is set at 510 litters/minute.Adjust globe valve as required.

26. Check reboiler is full. Due to outlet weir, this level will be constant.

27. Check accumulator level, add DEG as required. Should show at bottom of sight glass.

28. Check Reboiler temperature

29. Check Stripping tower overhead temperature. Normal: 70 100 deg C

30. Check DEG filter differential pressure and changefilters as required (see routine procedure).

DP of 15 psi indicates time to change filters.

31. Check V-330 Contactor K/O pot level. Dump to pail as required, see routine

procedure.

32. Check Coalescer differential pressure and sightglasses.

DP: 10-12 psi - time to change, see SOP. Dump liquid as required. See SOP.

33. Check level in External Water Tank, fill from hydrant ifapproaching tank (summer only).

Open hydrant valve slowly. Normallyrequired daily. Daily usage: ~1/2 tank

34. Ensure that cooling tower belts are in good shape, andat proper tension and not squealing.

35. Check level in cooling tower basins. Ensure that floats are operating properly.

36. Ensure that flare ignitor is operating ~once per minute.

37. Dip Flare Tank level and arrange for unloading ifrequired.

Unload at 180 cm.


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5.02 Weekly

Step Key Points

1. Clean up piping with pressure washer (summer monthsonly)

2. Dump water from plant air compressor receiver tankevery two weeks.

3. Change sales gas circular chart.

4. Pump V-110 level to flare using bottom suction valveevery 3 weeks.

See SOP.

Sales Gas Seven Day Circular Chart Plant Air Compressor Receiver Tank

BlowdownValve


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5.03 Other Routine Checks

Step Key Points

1. Drain Reboiler secondary containment vessel asrequired especially after heavy rain.

Shovel out snow if excessive. Use tiger torch to thaw water ice in winter if

required.

2. Grease various equipment bearings every 2000operating hours as follows:

Blower motor bearing - 30 shots Inboard blower bearing 30 shots Non- rubber blower couplings located under shroud

- 15 shots

Blower outboard bearing 15 shots Glycol pumps 15 shots Cooling Tower 15 shots DEG pumps 15 shots

The following can be greased while running:

Blower motor bearings Blower inboard bearing

The following bearings require that the unit beshutdown prior to being greased:

Blower outboard Blower coupling

Use Chevron SRI-2 grease Mark hour meters with next service due

number.

3. Wash floor as required or at least once per month(except in winter).

4. Inspect V-100 Inlet Separator on a yearly basis. Remove six inch access hand hole and cleanout sludge by hand.

5. Stroke both cooling tower louvers when preparing forwinter.

6. Check Flare Knockout Tank for leaks once / month.Use standby man.

Carefully remove leak detection dip stick andcheck for liquid. Use extreme caution andfollow safe practices when entering flare pit.

7. Clean reboiler burner annually and adjust air ratiocontrol disk / regulator.

8. Check reboiler cycling time on a regular basis. Thepreferred cycle is 15 minutes off and 45 minutes on.

If the reboiler is cycling more frequently, theburner flame can be adjusted down bylowering the burner pressure. Burner

pressure is governed by a regulator andshould be kept between 8 and 15 PSI.

9. Add DEG to system when required. 1/3 of a barrel every one or two weeks orwhen Accumulator sight glass shows lessthan inch.

10. Add a litre of antifoam to system every three to fourweeks or as required.


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Step Key Points

11. Calibrate GC when required See SOP

12. Bake out GC when there is not longer space betweencurve bottoms.

Caution, incorrect Bake Out canpermanently damage GC. See SOP.


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5.1 Routine Procedures5.1.1 Purging Liquid from Inlet Separator

Step Key Points

1. Open pump suction valve to Separator Base.

2. Open pump discharge to flare header

3. Start pump. Pump should gain suction within minute. System under vacuum

4. Run pump for hour or until separator is empty ofliquid

If pump has difficulty gaining suction, cleanY strainer on suction line. Due to systembeing under vacuum, the strainer will haveto be isolated, disassembled, and cleanedby hand.

Note: Vessel should be pumped out when level reaches glass on sight glass

V-100 Inlet Separator Base Pump and Piping

V-100 Base Suction Valve

Recirculation Valve

V-100 Base Pump

V-100 Discharge Piping to Flare

Suction Line Strainer


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5.1.2 Daily H2S Scavenger and H2O Addition to V-110

Step Key Points

1. Stop circulating pump.

2. Line up pump suction valves to draw from H2SScavenger chemical tank.

Switch from normal V-110 circulating suctionline 2nd from bottom.

3. Line up pump discharge valves to allow flow throughmeter to V-110.

4. Start Pump and add H2S scavenger. Run pump until 4 gallons scavengerchemical has been added according tometer.

5. Stop pump.

6. Line up pump suction to draw from indoor water tank.

7. Start pump and add H2O. Add water to a maximum of 150 USG asdetermined by V-110 level sight glass andambient temperature. Max amount is basedon ambient temperature of approx. 30 deg C;during extremely cold periods, no wateraddition is required.

8. Stop pump.

9. Line up pump for normal circulation. Suction from second level outlet on V-110,discharge unchanged.

Meter not required. Pressure gage in service

10. Start pump. Discharge pressure should increase.

NOTE: Loss of circulation on V-110 for greater than 1 hour will result in high H2S in sales gas.High H2S levels could force generating station to stop LFG gas usage.


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V-110 Base Piping

V-110 Sight Glass / H2S Scavenger Tank H2S Scav. Tank / V-110 Suction Lines

Normal Suction

Pump-out Suction

Flow Meter

Discharge Pressure

Base/Circulation Pump

Backup Pump

V-110


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5.1.3 Purging Liquid from V-200

Step Key Points

1. Shutdown H2S scavenger circulation pump and closeV-110 suction and discharge valves.

2. Line up the pump suction to draw from V-200 and thepump discharge to flow to flare header

3. Start pump and run pump for 20 minutes

4. Stop pump and put system back into service as V-110circulation pump.

Entire procedure should take less than 1hour to prevent H2S levels in sales gasbecoming excessive.

NOTE: Vessel should be pumped out when sight glass indicates glass. On average, this willtake about one month to build up; however, liquid accumulation rate is inversely related toambient temperature i.e. Liquid will accumulate faster during cold weather.


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5.1.4 Changing Lean/Rich DEG Filters

Step Key Points

1. Open filter bypass valve.

2. Close filter inlet and outlet valves.

3. Open bleed valve and depressurise filter.

4. Remove filter top.

5. Remove dirty filter elements to rack and allow to drainover barrel.

Used filters should be allowed to drain intobarrel for two weeks.

They should then be disposed of in a

Hazardous Material bin (45 gallon drum withoverpack).6. Exercise internal bypass mechanism to ensure proper

functionality. Liquid in barrel should be disposed of by

adding back to DEG.

7. Insert new filter elements.

8. Install filter cover.

9. Slowly open filter inlet valve and fill vessel with DEG.

10. When filter is full, close bleed valve.

11. Open filter outlet valve.

12. Close filter bypass valve.

NOTES: Filters should be changed when differential pressure reaches 15 psi.

Filters contain an internal spring loaded disk that automatically bypasses the filtermaterial when a high differential pressure develops.

Used drained filters must be disposed of in accordance with the LFGP HazardousWaste Disposal Document.


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5.1.5 Purging liquid from V-330 K/O Pot and V-340 Coalescer Filter base.

Step Key Points

1. Put bucket at K/O pot blowdown line outlet.

2. Slowly open blowdown valve.

3. Bleed liquid into bucket. Be aware that gas in solution breaks out likefoam, this can extend the time taken to executeprocedure by up to hour.

4. Close blowdown valve when liquid stops flowing.

5. Empty bucket using DEG addition system.

NOTE: Liquid should be drained from vessels as required, usually every three months for V-330and monthly for V-340.


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Changing Coalescer Filter Material

Step Key Points

1. Prepare vessel for filter change as follows:a. Block in inlet valveb. Block in outlet valvec. Open bleed valve

2. Loosen cover bolts slowly and remove cover.

3. Remove coalescer filter agent media.

4. Replace with fresh media.

5. Reassemble filter.

NOTE: The plant must be shutdown to replace filter material. This is required when differentialpressure gage reads 10 12 PSI (8 to 12 months.)


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Adding Fresh DEG to System

Step Key Points

1. Place unloading hose in DEG barrel.

2. Connect free end of hose to DEG pump suctionstrainer blowdown coupling.

3. Open strainer blowdown valve. Strainer blowdown valve: V958.

4. Slowly close suction valve from Accumulator (V-311). Accumulator suction valve: V948.

5. When required amount of fresh DEG has been added,

open suction valve from Accumulator (V-311) and closestrainer blowdown valve.

Observe liquid level in barrel to determine

when enough DEG has been added. Strainer blowdown valve: V958. Accumulator suction valve: V948.

6. Disconnect hose from strainer hose coupling. Drain DEG in hose back to barrel.

NOTE: Fresh DEG is added when Reboiler Accumulator level shows inch on bottom sightglass; 2-3 times per month depending on operating conditions.

Reboiler Accumulator Outlet to DEG Pumps

V-311 DEG Accumulator

Reboiler Burner Main Gas

Reboiler Burner Pilot Gas

Suction Valve to DEG Drums V958

Accumulator Suction Valve V948

DEG Pum (s) Suction Line


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Unloading Flare Knockout Tank

NOTE: The flare knockout tank is emptied when the dip gauge reads 180 cm or greater.

CAUTION: A high level in the flare K/O tank can result in liquid carryover and ignition at the top offlare stack spreading burning liquid around base of flare stack.

Step Key Points

1. Call liquid waste disposal company, currently Sellers Normally they are called the day before theyare required; however, they can arrive inapproximately one hour if requiredimmediately.

2. When truck arrives, open southwest gate and unlockcamlock plug on flare K/O tank unloading point (locatedimmediately south of SW gate).

The truck will unload K/O tank while parkedat the side of the road.

3. Connect truck unloading line to K/O tank unloadingpoint and connect grounding cable.

Responsibility: Truck Driver

4. Start unloading pump. The pump switch is located on light standardpost near flare stack.

5. Stop unloading pump when informed by truck driverthat unloading is complete.

The truck driver will monitor the unloadingprocess and inform LFGP operator to stoppump when truck tank volume stops

increasing or when truck tank is full. Unloading normally takes an hour and 15minutes +/- 5 minutes.

6. Disconnect truck unloading line from K/O tankunloading point.

Responsibility: Truck Driver.

7. Replace and lock Camlock plug / close gate.

8. Ensure that waste shipping manifest is properlycompleted.

Refer to previously completed manifests asan example.


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Preparing Cooling Towers for Winter

Step Key Points

1. Shutdown spray water pumps.

2. Drain tower sumps and piping by breaking unions asrequired.

3. Drain external water tank.

4. Disconnect and drain water addition line at hydrant.

5. Remove, drain, and store hydrant flow meter. The flow meter costs $3000 and will bedestroyed if allowed to freeze.

NOTE: During colder months, the Cooling Tower is run dry with the fans running but no spraywater. The towers must be prepared for winter operation as soon freezing temperatures areforecast usually mid October.


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Lighting Reboiler

Step Key Points

1. Shut gas to pilot and main burner.

2. Allow firebox to purge via natural draft for 3 minutes.

3. Light diesel soaked ignitor and insert it three feet intoburner port.

4. Open pilot valve and slowly open main burner gasvalve (15 seconds from closed to open).

Listen for flame ignition Check flame after removing igniter


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Plant GC Calibration

Step Key Points

1. Measure peaks for O2, N2, and methane using mousecursor and record values.

2. From the menu, choose Method Peak table.

3. Enter channel A RT values in the appropriate fieldsfor O2, N2, and methane.

4. Choose Save from the menu. Run Calibration gas through GC to verifyaccuracy.

Note:

After a power failure the remote button must be pressed on the GC prior to restarting EZChrom.Printer power must also be cycled.


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Plant GC Bakeout Procedure

Step Key Points1. Stop run Press Esc

2. Choose Method Open from menu. Selectbakeman from list and click okay.

Loads the column bakeout parameters

3. Choose Instrument, Send current method from themenu.

Sends the method to the GC.

4. Choose Instrument, Receive current method fromthe menu.

Sends the method back from the GC.

5. Choose Instrument, Status from the menu and

ensure that the following maximum temperatures arenot exceeded: A - 180 deg C B - 160 deg C

Exceeding these temperatures will destroy

the respective column.

Once temperatures have peaked safely, theyno longer need to be monitored continuously.

6. Allow columns to bake out for 1 hours minimum.

7. Stop run by pressing Esc

8. Choose Method Open from menu. Select cblfg1zfrom list and click okay.

Loads normal GC parameters.

9. Choose Instrument, Send current method from the

menu.

Sends the method to the GC.

10. Choose Instrument, Receive current method fromthe menu.

Sends the method back from the GC.

11. Choose Instrument, Status from the menu andobserve as temperatures cool to normal values:

A - 65 deg C B - 50 deg C

The columns must be at normaltemperatures before an accurate GC runcan take place.

12. Select start to begin normal operation. GC should start a run immediately.


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5.2.0 Plant Startup ProcedureNOTE: The following procedure assumes that no piping or vessels have been taken apart andthat the plant has been left in standby mode.

Step Key Points

1. Manually shut off various electrical switches located outin the plant as follows:

All three blowers Both compressors Both DEG circ pumps

Switches only work in manual mode not inauto mode.

It is important to position the switches to offon the blowers, compressors, and DEGcirculating pumps before pushing the plant

reset button or the plant will start up in anuncontrolled manner.

2. Ensure the main gas suction valves to the plant arewide open.

V800 and V802

3. Ensure all blower suction valves are open. V806, V807, & V808

4. Push plant reset button and place compressor runselection switch in appropriate position.

Compressor Run selector switch settings:

1 West compressor2 East compressor1&2 Both compressors

5. Place the attended/unattended selector switch in theattended mode.

6. Start the main ethylene glycol circulating pump West pump

7. Manually prelube the compressor(s). Rotate hand crank the required number oftimes. This ensures that the secondprelubing is quick after the blowers arestarted.

8. Start the blowers. Normally two are run, the other left as aspare.

9. Manually prelube the compressor(s)a second time.


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Step Key Points

10. Start the compressor(s) This must be done within 45 seconds ofturning on the blowers or a timer on the PLC

will shut down the blowers-This shutdownfeature is in the program logic because theblowers will sustain internal damage if theyare dead headed for any length of time.

If you exceed the above-mentioned 45seconds, you will have to start over again(manual switches turned off of blowers andcompressors and plant reset button pushedinside plant office).

11. Check the panel-mounted gauges for normal pressurebuildup on both left and right cylinders.

A closed downstream valve may causeexcess pressure on either gage.

12. Check the oil pressure gauge to ensure normal functionof lubrication system.

Normal oil pressure for cold unit is up to 80psig. Once unit has come up to operating

temperature, normal oil pressure is from 35to 50 psig.

13. Line up and start the DEG circulating pump. P-100 or P-310

14. Set the DEG flow rate using the manual globe valve to5 10 liters/minute as indicated by FQ-5.

V933 - located next to Halliburton liquid flowmeter (FQ-5).

15. Check the gas flow chart to ensure that gas pressure isbuilding up normally.

With the sales gas line blocked in at powerstation, the gas should be at ~90 psig andflaring.

16. Ensure that Kimray backpressure control valve isoperating correctly controlling pressure by divertingsales gas to flare.

Ensure that Kimray controller keeps gaspressure well below 100 psig.

Excess pressure (over 100 psig) will pop thesales gas line PSV - an undesirable situationbecause this PSV does not always reseatand therefore must be sent out forrecertification. This would cause substantialplant downtime.

17. After five minutes, call generating station and instruct

them to start taking gas.

Monitor the gas sales chart to ensure that the

generating station is in fact taking the fullflow of gas-It is normal for them take five orten minutes to accept full volumes of gas.

18. Start the cooling tower air fans and spray water pumps. Summertime only.


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Step Key Points

19. Walk through the plant again to ensure all equipment isheating up normally and that there are no problems

(normal gauge pressures and no abnormal vibrationsor noises).

20. Check chromatograph readings to ensure that oxygenconcentration is below 1.5 %.

Oxygen readings in excess of 1.5% are abnormaland should be corrected immediately.

DANGERIf oxygen exceeds 4%, the plant must be shut down immediately. In this case, press the manualESD button on PLC panel. The source of air ingression must be identified and corrected beforeattempting to bring the plant online. Failure to adhere to this procedure could result in a plant

explosion.


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NOTE:

Plant Startup With Purging - If any vessels or piping are taken apart when the plant is down thenthe plant must be properly purged of any oxygen that may have found its way into the gas stream.

This also includes valve changes on the compressors. To purge air out the plant piping open themanual flare valves on the compressors before starting them. Also, open the manual contactordrain valve; which is also tied in to the flare system. To ensure good displacement of the foreignair these valves should be open to flare for at least five minutes before they can be closed. Seeattachment section 6.6 for photo of east compressor purge outlet piping.


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5.3.0 Plant Shutdown Procedure

Note: In case of an emergency, the plant can quickly be shutdown by pressing the ESD buttonon the PLC panel.

Step Key Points

1. Contact Generating Station and inform them ofimpending shutdown.

412-3281 or 412-3360

2. Shutdown blowers by moving local switches to the offposition.

The compressor will automatically shutdown.

3. Shutdown DEG pump.

4. Shutdown spray water pumps and fans on bothCooling Towers.

5. During warm weather, shutdown EG circulation pumpafter a minimum of hour. During cold weather, leaveEG circulating for duration of shutdown.

It is important to leave EG circulating for aperiod after plant shutdown to preventthermal shock to the compressor(s).

EG is left circulating in winter to help preventfreeze-ups.

6. In winter, drain liquids from all major vessels. V-100, V-110, V200, & V-300`

7. Reset PLC and press acknowledge button.

Note: The main LFG inlet valve is left open to help prevent air ingress to process over time due tochanges in barometric pressure.


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6.0 Attachments6.1 Typical Bubble Cap

6.2 Typical Chimney Tray

6.3 Plant Air Compressor Photos

Air Compressor & Receiver Air Compressor Close-up

Oil LevelSight

Glass

PressureGageReceiver

Motor

Filter

Blowdown

Cylinders


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6.4 West Landfill Gas Compressor Photo

West LFG Compressor

6.5 V-100 Inlet Separator and Blowers Photo

V-100 and Blowers

LP Cyl Inlets

Mur h Vib Switch

Crankcase Oil Level

HP Cyl

HP Cyl

LP Cyl LP Cyl

Oil Hand Crank

Oil Cooler

Blower Outlet Header

LFG Blowers (3)

V-100 Inlet Separator

V-100 Base Pum


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NUMBER: RJ K-025


6.6 LFG Compressor Discharge and Purge Outlet Valves

East LFG Compressor Discharge Piping

6.7 LFG Compressor Recycle Line Block and Check Valves

Main LFG Outlet Line from Compressors

Compressor Disch Valve

Hi h Disch Pressure Tri

Pur e Outlet Valve

High Disch. Temp Trip

Com ressor Disch Line

Recycle Line

Rec cle Check Valve

Rec cle Block Valve


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NUMBER: RJ K-025


6.8 Supplemental Images

V-300 Main Contactor Hat Tray Draw-off V-330 OH K/O Pot & V-340 Coalescer


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Inside Water Tank Flare Stack KO Tank Pump Pit

Addition Line

Pum Unloadin Line

Di Check


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7.0 Forms7.01 Daily Logsheet Example


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7.02 Spill Report Checkl ist

Chemical & Oil Spill Report Checklist

Date: NORFLUX Report#

Alberta Environmental Protection File #

Operating Supervisor

Initial Information Part A

Reported by

Name Phone #

Location of spill area:Address

Cause of Spill

Time of report

Amount of Chemical or Oil Spilled (liters)

Additional Information Par t B

Alberta Environment Informed? Yes No

Time Inspectors Name

Alberta Environments Comments

How was cleanup done?

Soil analysis required? Yes No

Results ppm Senior Sustainable Development Engineer notified

Site clean up date Time

Faxed NORFLUX Environmental Affairs Time

Date Fax # Phone #

Report compiled by

File Closed? Approved by


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L7-i Landfill Gas Plant SOP PIDsNorflux

Environmental PracticesExample of Environmental Checklist

The following environmental related checks must be performed at the assigned frequency:

Inspected Item Type of Inspection Purpose of Check Frequency Inspection Results

Plantsite Walk around-Visual &

Audible

Prevention of gas or

liquid releases toair/ground

Daily Leaks- Yes/No

Flarestack IgnitionSystem

Manual Switch-Audible &Visual

Prevention of unburntgases to atmosphere

Weekly Working-Yes/No

Flarestack IgnitionSystem

Professional ElectricalInspection

Prevention of unburntgases to atmosphere

Yearly Defects Requiring Fiup Y/N

Flare Knockout TankInterwall

Visual Inspection ofDipstick

Prevention of liquidsrelease to soil

Weekly Dipstick Dry & CleanY/N

Flare Knockout Tank 24 Hour Visual Leak Test Prevention of liquidsrelease to soil

Yearly Gauge Stick ReadingChange Y/N

Flare line 8" 900Disch. Elbow

Visual Inspection ofinterior pipe wall

Prevention of gas orliquid releases toair/ground

Yearly Excessive corrosionY/N

CondensateWastewater

Independent LaboratoryAnalysis

Proper Handling, Storageand Shipping

Yearly Report Submitted toAlberta Environ.

Flarestack Influent Independent LaboratoryAnalysis

Prevention of excessiveemissions to air

Yearly Report Submitted toAlberta Environ.

Solid HazardousWaste

Independent LaboratoryAnalysis

Proper Handling, Storageand Shipping

Yearly Proper CharacterizatY/N

Proposed Future Checks

Inspected Item Type of Inspection Purpose of Check Frequency Inspection Results

Flare line MonitoringWell

Visual Prevention of liquidsrelease to soil

Monthly? Well Dry Y/N

Flare line CathodicProtection Electrical Tester Prevention of liquidsrelease to soil Monthly? Functioning Y/N

gas plant land fill

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