ENERGY RESOURCES CONSERVATION BOARD

Calgary Alberta

Informational Letter
IL 80-23

TO: ALL OPERATORS OF OIL, GAS, OIL SANDS AND PIPELINES

EXPERIMENTAL SCHEMES

• RELEASE OF APPLICATIONS AND BASIC WELL AND GEOLOGICAL RECORDS

• CONFIDENTIALITY PROVISION FOR UNIQUE DESIGN DATA AND PROGRESS REPORTS

ON OPERATING RESULTS

• REQUESTS FOR INFORMATION OF LOCAL INTEREST

This letter outlines revised procedures for control of information
respecting experimental schemes.

INTRODUCTION

The general policy for classifying experimental schemes for the recovery
of bitumen and crude oil is set out in Informational Letter IL~OG 78-12.
Experimental data submitted to the Board pursuant to the approval of an
experimental scheme is retained by the Board on a confidential basis
pursuant to the provisions of section 12.150(8) of the regulations.
The Board has determined that as the number and variety of field ex-
perimental operations has grown rather rapidly in recent years, that
it is proper that the basic intent and nature of such schemes should
be made available to the public and that certain basic information such
as geological data should be removed from the experimental information
category and placed in the Board *s normal records system. Occasionally,
the Board also receives requests from local residents regarding environ-
ment protection measures or other local concerns and the Board believes
that procedures must be available to readily reply to such requests while
at the same time avoiding disclosure of proprietary information. This
letter sets out the procedures that will be used to meet those purposes.

APPLICATIONS

In keeping with the procedure in use during the past year, applications
for experimental schemes will be made available to the public in a
manner similar to other applications received by the Board. The time
of release will be either upon approval of the scheme by the Board (the
most common situation), or upon publication of notice for objection or
hearing.

Requirements for experimental scheme applications include descriptions of
the general program of investigations, site development plans (including
well locations, equipment sites, mine pits, etc.), surface facilities

2

layout and design capacities, geological information, environmental
factors and protection measures and identification of any landowners
or leaseholders that may be affected.

Experimental schemes sometimes involve intricate new design considerations
or operating techniques which when implemented may lead to the development
of information of special proprietary value. This kind of information,
though relevant to the Board for examining technical merit of the
experimental test program, would not ordinarily be considered of general
public interest and need not be part of the application. It should,
however, be submitted as confidential information to be made part of the
progress report documentation. That information would then be given the
same confidential status as that of the progress reports as described on
a following page.

Where the size and duration of experimental operation is such as to be of
significant importance to the local region, information concerning
socio-economic matters may be required. For clarification of the need
for this and other information, it is suggested that a draft of the
application be discussed with the Board staff by contacting the Oil
Sands Department prior to formal submittal.

STANDARD LOG AND CORE DATA

During the course of the discussions over the past year, agreement was
reached on the benefits of converting the basic well files for oil sands
evaluation (OV) and experimental (EX) wells to the same filing and
release system applicable for conventional oil and gas wells in the
province. By converting to this procedure, routine well information
including basic well licensing data, drilling depth information and
conventional well logs and core data will be administered in the same
way as that which is in use for conventional wells. Amendments to
regulations 12 . 150(2) (c) , (4) and (6) will be made to reflect these
revised procedures.

SPECIAL LOG AND CORE DATA AND OTHER MEASUREMENTS

Recognizing that during the operation of an experimental scheme special
monitoring, including log and core measurements, are often used to
evaluate performance, the Board will receive and consider such infor-
mation and measurements as part of the confidential progress reports.
For example, log and cores taken to investigate an altered state
resulting from experimental activity would fall into that category and
should be submitted as part of the confidential progress report in order
to retain confidential status.

PROGRESS REPORTS

The basic data obtained during experimental operations is compiled and
submitted to the Board in the form of progress reports. These reports
are retained by the Board on a confidential basis pursuant to section

3

12.150(8) of the regulations. During the course of discussions a range
of opinions has been expressed concerning the control of this kind of
information. The variations in viewpoint appear to stem from different
perceptions of what kind of information might be considered of particular
competitive value.

The Board agrees that proprietary design data made available to the Board
staff at the time of filing of the application should be confidential.
Also, the Board concurs with the general view that information developed
during experimental operations which is of special proprietary value
warrants confidential treatment. On the other hand, relatively free
exchange within the industry of information respecting improvements in
state-of-the-art developments and operating techniques will usually
accelerate the pace of such improvements and would be broadly beneficial
to the industry.

To better meet the objectives and needs of research groups, industry and
the public interest, the Board has adopted the suggestion that experimental
scheme progress reports be scheduled for release five years after
completion of an experimental operation this ordinarily being the expiry
date of the approval, provided that release would not result in serious
loss of proprietary information. In cases where an experimental operation
has been extended to perform an additional phase of investigation,
classification of the completion dates of the experimental operations
will be determined in consultation with the operator. Therefore,
commencing in 1981, progress reports for experimental schemes will
ordinarily be scheduled for release five years after completion of the
experimental operation. A backlog of older reports submitted during the
1960s and early 1970s may be eligible for disclosure under this revised
policy.

Exception to this rule may be obtained, however, if an operator requests
and obtains continued confidential status for the reports for an
additional period of five years by satisfying the Board that the information
is still of significant proprietary value. The reports would then be
re-scheduled for release at the end of the second five-year period unless
the operator demonstrated to the Board's satisfaction that it was in the
public interest to continue to classify the information as confidential
for such further period considered appropriate.

INFORMATION OF LOCAL INTEREST

Occasionally, the Board receives requests from local residents, other
leaseholders and the local news media respecting the operating aspects
of an approved experimental scheme. The Board has directed its staff
to ensure that any such requests that are reasonable and proper should

4

be fulfilled expeditiously. The Board expects operators of experimental
schemes to co-operate fully in responding to any such requests whether
those come directly to an operator or are received at a Board field
office or its Head Office. In line with suggestions submitted by
operators, the Board does not intend to establish any formal procedure
to meet this need.

DATED at Calgary, Alberta on 16 September 1980.
ENERGY RESOURCES CONSERVATION BOARD

Board Member

ENERGY RESOURCES CONSERVATION BOARD AND

ALBERTA ENVIRONMENT

The Province of Alberta

Informational Letter
IL 80-24

TO: All Oil and Gas Operators

and Gas Processing Consultants

SULPHUR RECOVERY GUIDELINES
GAS PROCESSING OPERATIONS

New requirements have been set for sulphur recovery at new or expanding
Alberta sour gas plants. The revised guidelines result from continuing
investigations and communications involving the federal and provincial
governments and the industry. They supersede the requirements previously
established in 1971 as they are set out in the Board's Informational
Letter IL 71-29 and in applicable parts of IL-OG 74-5.

While the new recovery efficiency requirements will be generally
applicable, some variance may be appropriate in particular circumstances.
For example, where there are overriding local environmental considerations,
sulphur recovery may be required at small plants having a sulphur inlet
rate of less than 10 tonnes per day (t/d). At plants with severe design
constraints or operating conditions, a modest reduction in the required
recovery level may be permitted if this appears to be environmentally
acceptable. A decision to deviate from the normal requirement would not
be made without opportunity for the input of persons who may be adversely
affected.

New Plants

For plants commencing construction after 1 December 1980 and with
approved inlet rates exceeding 10 t/d of sulphur, the expected minimum
sulphur recovery for normal plant operating conditions shall be
determined to the nearest 0.1 per cent from Figure 1. Figure 1 is
intended to be applicable to plants processing good quality acid gas
(i.e. acid gas containing more than 40 per cent hydrogen sulphide).
An operator may apply for some relaxation if poor quality acid gas is
to be processed. For small plants to be emitting less than 3 t/d of
sulphur and processing acid gas barely within the good quality range,
some relaxation may be permitted having regard for the cost and
complexity of the equipment which would be required to achieve the
recovery efficiency indicated in Figure 1. These and other exceptional
cases will be considered individually.

2

The gas processing scheme approvals issued by the Board will stipulate
a required quarterly average recovery of 0.3 per cent less than the
recovery determined from Figure 1. This difference allows for operating
periods during which the plant is experiencing start-ups and shut-downs
or abnormal operating conditions.

Plant Expansion, Modification, or Life Extension

Plants being expanded or significantly modified will be assigned a
sulphur recovery requirement on an individual basis having appropriate
regard for the new requirements and such factors as the nature and
extent of the expansion, environment protection, economics, and the
forecast sulphur inlet rates. Similarly, where substantial new reserves
of sour gas are to be processed in, and thus would extend the life of,
a plant whose recovery efficiency was established under previous guide-
lines, the plant's sulphur recovery requirement would also be reviewed
having regard for the same factors.

Existing Plants

Existing plants not included in the above categories remain subject to
the sulphur recovery requirements stipulated in the respective approvals.
As these stipulated requirements are expressed on a quarterly average
basis, they are not to be reduced by the 0.3 per cent allowance
mentioned above under the heading "New Plants".

An operator of an existing plant which is receiving gas from fields
undergoing a decline in deliverability may apply for a reduction in
the recovery efficiency requirement. The decision on an application
of this type would be based on such relevant considerations as
environmental impact, sustainable plant throughput, plant turndown
ratio, and sulphur recovery efficiency experience at the plant.

ISSUED at Calgary, Alberta on 4 November 1980.

Assistant Deputy Minister Vice Chairman

Artachmenf to Informational Letter IL 80-24

ENERGY RESOURCES CONSERVATION BOARD _1_

Calgary Alberta

Informational Letter
XL 80-25

TO: Oil and Gas Operators and Testing Companies
Canadian Petroleum Association
Independent Petroleum Association of Canada

NEW BOTTOMHOLE PRESSURE RECORDERS

The Board wishes to advise Oil and Gas Operators that it does not issue
certificates of approval for new measuring devices used in the Industry.
The Board does not have adequate facilities at its disposal to check
these devices at operating conditions over both the short and long term.
It endeavours, however, to maintain the accuracy of measurement devices
through regulations and policies that stipulate calibration, accuracy
and performance criteria.

Recently, the Board has received enquiries requesting approval of certain
new types of bottomhole pressure recorders. The devices are acceptable
to the Board provided that:

1 The Board is satisfied with the initial calibration and sensitivity
check data as indicated from a calibration against a Board-approved
Dead Weight tester.

2 Board staff have been advised of the date and time of the
calibration in the event they may perform or witness the calibration.

3 The recorder has an accuracy of at least 0.25 per cent of full
range.

4 The performance of the device has been demonstrated to be satisfactory
over a reasonable period of field testing.

5 Subsequent calibration checks are performed on each instrument in
accordance with section 11.110 of the Oil and Gas Conservation
Regulations.

For additional information please call Cheryl Adolf at 261-8550 or
Bill Erkamp at 427-0228 in Edmonton.

DATED at Calgary, Alberta on 20 October 1980.
ENERGY RESOURCES CONSERVATION BOARD

V. E. Bohme
Board Member

1

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ENERGY RESOURCES CONSERVATION BOARD

Calgary Alberta

Informational Letter
IL 80-26

TO: All Operators

(Oil and Gas, Pipeline, Rural Gas, Hydro & Electric)

Effective 03 November 1980 the Medicine Hat Office will be moving
to the following location:

Energy Resources Conservation Board
P. 0. Box 909
Medicine Hat, Alberta
TIA 7G8

Office Telephone: 527-3385 (24 Hour Service)

Office Location: 1609 Brier Park Road N. W.

Medicine Hat, Alberta
TIA 7G8

DATED at Calgary, Alberta on 21 October 1980.

R. W. Edgecombe
Assistant Manager
Field Operations
Development Department

ENERGY RESOURCES CONSERVATION BOARD

DEVELOPMENT DEPARTMENT

Telephone Number

CALGARY OFFICE 603 - 6th Avenue S. W. 261-8311

Calgary, Alberta, T2P 0T4 (After Hours &

Telex 03-82-17-17 Holidays Only)

261-9917

Manager, Development Department L. A. (Lloyd) Bellows 261-8169

Assistant Manager, Drilling & Production Wm. H. (Bill) Wolff 261-8172

Assistant Manager, Field Operations R. W. (Rod) Edgecombe 261-8174

Senior Drilling & Production Engineer L. E. (Lloyd) Hicklin 261-8176

Senior Drilling & Production Engineer J. R. (John) Nichol 261-2410

Senior Staff Supervisor, Field Operations B. E. (Brian) McFarlane 261-8167

Supervisor of Well Licensing D. L. (Don) Skappak 261-8159

Supervisor, Drilling Section W. (Bill) Wylie 261-8554

AREA OFFICES

Drayton Valley Box 390, 51st Avenue & 52nd Street, TOE OMO 542-5182

Area Supervisor - F. (Fred) Sorenson (24 Hour

Assistant Area Supervisor - R. (Bob) Keller Service)

Edmonton 145 Street and 123 Avenue 427-0200

MAILING ADDRESS - P. 0. Box 3560 (24 Hour

Postal Station "D" Service)
Edmonton, Alberta
T5L 4J6

Area Engineer - K. G. (Ken) Sharp
Staff Supervisor - V. (Vern) Jones

Supervisor, Pipeline Inspection - L. (Lloyd) Bowhay

Bonnyville Satellite Office: (operated through the Edmonton Office)

P. 0. Box 1969, Northlands Development Building 826-5352

49th Street & 50th Avenue, Bonnyville, Alberta (Normal

TOA OLO Working

Hours)

Medicine Hat Box 909, 1609 Brier Park Road N.W. , TIA 7G8 527-3385

Area Supervisor - R. (Ron) Elle (24 Hour

Assistant Area Supervisor - D. (Dwayne) Waisman Service)

Red Deer Box 5002, 4920 - 51 Street, T4N 5Y5 343-5454

Area Engineer - W. J. (Bill) Schnitzler (24 Hour

Staff Supervisor - E. F. (Ed) May Service)

Supervisor, Pipeline Inspection - D. (Don) Knopp

Turner Valley Box 447, 2 - 102 Sunset Boulevard, TOL 2A0 933-4326

Area Supervisor - J. S. (John) Eraser (Normal
Assistant Area Supervisor - H. E. (Harvey) Sondergard Working Hours)

266-5854 (After
Hours & Holidays)

Wainwright Box 1506, 1037 - 2 Avenue, TOB 4P0 842-4431

Area Supervisor - M. (Metro) Koziol (24 Hour

Assistant Area Supervisor & Supervisor, Pipeline Service)
Inspection - W. (Wayne) Green

Whitecourt Box 1530, 5020 - 52 Avenue, TOE 2L0 778-3812

Area Supervisor - R. B. (Barry) Doherty (24 Hour

Assistant Area Supervisor - D. (Darrold) Banta Service)

Effective

- October 1980

(energy resources conservation board
\j alberta, canada

AREA OFFICE
INSPECTION DISTRICTS

JUNE,1979

^ AREA OFFICE LOCATION

ENERGY RESOURCES CONSERVATION BOARD

Calgary Alberta

Informational Letter
IL 80-27

To: All Operators ^0^^^^^

A )

LICENCE AND PERMIT FEES

The Board after reviewing the costs of processing applications for
well licences, and pipeline permits and licences, has concluded
that an increase in fees is necessary to compensate for increased costs
and more complex administrative procedures.

The current schedules of fees have been in effect since 1 January 1979
and, since that time, salaries and overhead have increased considerably.
In addition the increased involvement of the Board and the industry with
respect to the impact of resource development on landowners, the
environment and the public has increased the complexity of the approval
process. This has resulted in an increase in the amount of staff time
necessary to process these applications.

Effective 1 January 1981 the fee for a well licence will increase from
$150 to $250 and for a pipeline permit or licence from $100 to $150.
Schedules of fees will be available when the amended schedules have been
registered.

Dated at Calgary, Alberta on 25 November 1980.
ENERGY RESOURCES CONSERVATION BOARD

ENERGY RESOURCES CONSERVATION BOARD

Calgary Alberta

Informational Letter
TO: All Oil and Gas Operators and Gas Purchasers '

MOV £^1980

GAS RESERVOIR REVIEW 81-1

In the first of a series of semi-annual reservoir reviews, the Board,
through Informational Letter IL 80-9 requested submissions from industry
on the reserves and deliverability of 29 pools for which production
performance or other indicators suggested a revision to the Board's
established values for reserves or deliverability may be appropriate.

The Board now requests the cooperation of industry in the submission
of similar information for some 32 pools under "Gas Reservoir Review
81-1". Attachment 1 lists the pools scheduled for this review. Seven
copies of submissions respecting these pools are requested to be filed
on or before 31 March 1981.

The Board would prefer a single submission from a major operator or
co-ordinating operator in each pool, but where this is not practical,
would accept separate submissions from different operators each dealing
with a portion of the pool. The Board asks that its Gas Department be
advised as soon as possible respecting any pool where a single pool-wide
study cannot be submitted.

The Board also welcomes submissions from gas purchasers who have a direct
interest in any of the pools.

Reserve submissions should preferably be summarized on form EG-31-79-12
"Reserve Submission Summary Sheet" (Attachment 2), and include, but
not necessarily be limited to, the information described on the reverse
of the form. Performance-based reserve estimates using methods such as
pressure decline, production decline, material balance and numerical
simulation should be appropriately documented.

Deliverability data may be summarized on the form "Natural Gas
Deliverability Data Sheet" (Attachment 3). The pool production forecast
should include the information described on the reverse of the form.

The submissions and a listing of them will be available for public
scrutiny shortly after 31 March 1980 in the Board's Record Centre by
reference to "Gas Reservoir Review 81-1".

The staff of the National Energy Board (NEB) will be involved in an
informal manner respecting the submissions.

2

Any questions respecting this matter may be directed to Mr . H. R. Keushnig
(261-8511) of the Board's Gas Department.

DATED at Calgary, Alberta on 14 November 1980.

H. J. Webber, P. Eng.
Manager, Gas Department

Attachments

ATTACHMENT 1

POOLS WHICH SUBMISSIONS ARE REQUESTED

FOR

31 MARCH 1981

Established Reserves as at
31 December 1979

Pool

Carson Creek Beaverhill Lake A

Carson Creek Beaverhill Lake B

Cranberry Slave Point A

Crossfield East Wabamun A

Enchant Basal Colorado A

Ferrier Cardium E
Associated and Solution

Figure Lake Upper Mann. B & D-2 B

Greencourt Pekisko A
Associated and Solution

Jumping Pound West Rundle A & B

Lone Pine Creek Wabamun A

Long Coulee Mannville N

Medicine River Pekisko P

Okotoks Crossfield

Olds Wabamun A
Associated and Solution

Oyen Viking A & Detrital C

Pembina Lobstick Glauconitic A

Pine North-west D-3 A

Richdale Viking A & C

Rosevear Beaverhill Lake A

Rowley Pekisko A
Associated and Solution

Simonette D-3
Solution

V/aterton Rundle -Wabamun A

Wimborne D-3 A
Associated and Solution

Initial

Remaining

4 790
2 250
8 800

14 100

1 150
10 687

2 390
1 835

30 300
10 400
845
1 490

5 920

6 264

1 880

3 500

2 820
1 550

10 400
1 608

3 280

48 900

7 047

3 046
1 747
8 797

8 671
846

5 666

1 524
900

22 182

6 123
432

1 152
3 235

2 950

1 436
1 918
1 465
1 204

9 540
641

1 753

23 612

2 828

GROSMONT TREND POOLS

Craigend Grosmont A 4 790 3 161

Duncan Grosmont B 1 370 1 126

House Grosmont A 2 120 2 120

Hylo Grosmont A 380 291

Liege Grosmont A 800 800

McMillan Grosmont A 271 157

Nixon Grosmont A 1 580 958

Portage McMurray-Grosmont A 1 750 1 187

Tweedie Grosmont A 519 93

ATTACHMENT 2

ENERGY RESOURCES CONSERVATION BOARD

RESERVE SUBMISSION SUMMARY SHEET

FIELD AND POOL
SUBMITTED BY

DATE

TY^E OF RESERVE

MEAN FORMATION DEPTH K.B.
TYPE WELL (LOCATION)

(ASSOCIATED OR NON - ASSOCIAT 'D)

s.s

.w.

M.

f«ASe OF PAY K B

s s
s s

AVERAGE POROSITY (FRACTION).
sou«cs

CUTOFFS POROSITY

PERMEABILITY.

GAS SATURATION I FRACTION).

SW SOURCE

INITIAL RESERVOIR PRESSURE (kPo )
souRcr

RESERVOIR TEMPERATURE

SOoRCt

COMPRESSIBILITY FACTOR 2

( Pr "fr

GAS ANALYSIS Pc .
RELATIVE DENS.TY

kPo Tc

3R0SS HEATING VALUE (Mj/mM

SOURCE

POOL RECOVERY FACTOR

RESERVE ESTIMATE

^

- INITIAL CONDITIONS

G/ W . metres SS

i

G/0, metres SS
1 0/V^, metres SS
1 AREA , hectores
1 h , m e t res

VOLUME, lO^m^

i riAC ^AT imr* ir\n
1 VjMj jM 1 . , T roc I Ion

! P, , kPo

f

PROVEN

■ PROBABLE

!

j ;

i i

^ i

j

, \ 1

, \ \,

I Z

i mVm'
GIP, 10^ m'

i

1 RESERVOIR LOSS

\ 1'

1 11

•

PRODUCIBLE, 10' m'

■ SURFACE LOSS

t

1 MARKETABLE

L — — I

,

' MARKETABLE GAS | i
i PRODUCED 1 ■

i REMAINING

1 ESTABLISHED MARKETABLE j j;
L EFFECTIVE DATE i Jj

SURFACE LOSS FACTOR

7o

7o CO,

7o C,

Vo PLANT AND LEASE FUEL

ADDITIONAL COMMENTS

The minimuTn reservoir information requirements are:

(a) basic reservoir parameters such as h, ^, Sw, So, k, initial
pressure, gas composition, and interface levels;

(b) a description of the reservoir by use of isopach maps, structure
maps, cross-sections, assigned area, or other depictions;

(c) basic production data such as pressure history, production
history, and deliverability tests;

(d) the volumetric reserve estimate;

(e) recovery factor calculations, including the effect of:

• water aquifers,

• water production»

• reservoir stratification and/or zonation,

• expected well density,

• completion and production techniques, and

• the impact of gas and co-product price on recovery (including
a discussion of the economics of producing pools which are
currently shut in) .

PLANTS £ CAPACITIES

SUBMITTOR:

DATE OF ESTIMATE:

ATTACHMENT 3
NATURAL GAS DELI VERABILITY DATA SHEET

FIELD:

POOL:

LOCATION:

PRODUCING ZONE:

GAS CAP Cn

RESERVE TYPE: - NON ASSOC CD

SOLN I [

CAPABILITY FORECAST

frcxn remaining marketable reserves at 80-01-01
of 10® m' @ 15°C and 101.325 kPa

Year 10* mVd

1979 (Actual)

80

81 __

82 __

83

Sk ___

1985

i 86 ___

87 __

88 __

89

1990 ___

91

92

93

9A __

1995 __

96

97

98

99

2000

GHV of marketable gas

# Wells

Added

Comp 'n (kW)

C. RESERVOIR DATA

Mean formation depth (KB)
Initial reservoir pressure
Reservoir temperature

Drive mechanism

MJ/m^

m

kP%
K

D. RAW GAS PROPERTIES
Relative Density

kPa, T

Composition (mol fraction) C

-2
iC,

CO,

'3 -

nC^

He"

iC,

nC,

'7 +

"2^

BASIC DEL I VERABILITY DATA
Number of producing wells
Number of capable wells

Estimated wells at full development

Delivery pressure

Installed compression kW

Buyer(s) > _______

Dedicated ,

10 m

Contract Rate(s) ; DCQ

Min. day
Max. day

(Rate of Take) ROT

.10' mVd

Estimated Producing Rate
at abandonment

10' mVwell/yr

ell Location

Tubing Datum
I.D. mm Depth

AOF Potential (Raw Gas)
Dite VO^I? "n" BHSIP

Wellhead Del i verab i 1 1 ty (Raw Gas)
Date 10^ m^ "^n" WHS IP WHFP

The pool production forecast should include;

• average well and total pool AOF and average slope "n"
of AOF plots,

• prospects and plans for r ecomp let ions , infill drilling, and
compression,

• contract rates,

• other restrictions such as gathering system, processing
plant, and laterals, and

• forecast of actual expected production, including all
important assumptions.

NATURAL GAS DELIVERABILITY DATA SHEET

Section A

Normally productive reservoirs can be completely identified by supplying
the information requested in Section A. In cases where reserves and
deliverability apply to only part of a pool, a plat clearly indicating
the part concerned should accompany the form.

Section B

All volumes submitted in Section B should be in respect of marketable
gas. The Board defines supply capability as the deliverability,
unconstrained by market demand, that could be achieved by a natural gas
reservoir when limited by reservoir performance, well capability, field
processing capacity, expected maximum wells and compression, the existing
or assumed contract rate, and provincial rate limitations. Submittors
are asked to identify restrictions where this is necessary to understand
the capability forecast.

The gross heating value should be reported on a dry basis.

Section E

The purpose of Section E is to present the raw data used to develop
the forecast shown in Section B. Where individual well AOF's are not
available, or were not used, submittors are asked to supply alternative
flow test data such as a pool average AOF, typical well AOF, or drill
stem tests.

ENERGY RESOURCES CONSERVATION BOARD

Calgary, Alberta

Informational Letter
IL 80-29

TO:

All Operators ^JQy £

In order to issue the Board's January 1981 MD Order on 19 December
1980, the Board requests that applications for the following be
submitted no later than 4:00 p.m. on 4 December 1980.

Production Spacing Units

Blocks

Projects

No applications for 1 January 1981 approval will be accepted after
the deadline.

DATED at Calgary, Alberta on 14 November 1980
ENERGY RESOURCES CONSERVATION BOARD

Staff Supervisor
Proration Services
Oil Department

VO/pm

CANADIANS

ENERGY RESOURCES CONSERVATION BOARD

Calgary, Alberta

Informational Letter
IL-80-30

TO:

All Oil, Gas and Pipeline Operators

APPLICATION FOR APPROVAL OF
NATURAL GAS COMPRESSORS

The purpose of this Informational Letter is to describe certain require-
ments respecting applications for approval of compression facilities.

Applications for approval of new or expanded gas compression facilities
are subject to the exhaust emission requirements as outlined in Appendices
3 and 4 effective immediately. Certain existing compression facilities
may require higher exhaust stacks and the criteria for these facilities
are described in Appendix 2.

Revised stack design criteria resulting from studies done by Alberta
Environment, are specified in the publication "Guidelines for Plume
Dispersion Calculations" which is available through the Standards and
Approvals Division of Alberta Environment.

Appendices 5 and 6 provide supplementary information on liquid waste
handling and noise abatement at compression facilities.

This Informational Letter supersedes Informational Letter IL-OG-PL-76-15
and will be reviewed when additional information on oxides of nitrogen
(NO^) emissions is available.

ISSUED at Calgary, Alberta, on 22 December 1980.
ENERGY RESOURCES CONSERVATION BOARD

V. E. Bohme
Board Member

APPENDIX 1

TYPES OF COMPRESSORS

For the purpose of this Informational Letter:

1. Gas Plant Compressor is part of a processing plant as defined under
section 2(1)35 of the Oil and Gas Conservation Act.

2. Battery Compressor is part of a single or multi-well gas or oil well
battery as defined under section 2(1)3 of the Oil and Gas Conservation
Act.

3. Field Compressor is an installation

(a) on a gas line or secondary line for gas to maintain operating
pressures within the pipeline system; or

(b) for subsurface gas injection where the facility is not part
of a gas plant or battery.

4. Existing Compressor shall be grouped into the following two categories:

(a) Category I includes compressor (s) at existing facilities where:

(i) no increase in compression is to take place; or

(ii) an increase in compression is proposed and the maximum
total NO^^ emission from the expanded (existing plus
proposed additions) facility will be less than twice
the maximum NO^ emission of the existing facility as
of 1 January 1981.

(b) Category II includes compressor (s) at existing facilities where

additional compression is proposed and the maximum total
NOx emission from the expanded (existing plus proposed
additions) facility will be greater than twice the maximum
NOx emission of the existing facility as of 1 January 1981.

5. New Compressor is any compressor unit which is to be located at a site
where no compression existed on 1 January 1981.

APPENDIX 2

APPLICATION PROCEDURE

1 . Gas Plant Compressors

The addition of a compressor (s) at a gas plant will require an
amendment to the existing gas plant approval under section 38 of
the Oil and Gas Conservation Act, together with a new Clean Air
Act permit before construction may commence.

Applications for approval of these facilities shall be submitted
to the Gas Department of the Board. The application shall include
the requirements of section 15.050 of the Oil and Gas Conservation
Regulations and shall include the applications for a Clean Air Act
permit and licence, which will be referred to Alberta Environment.

2. Battery Compressors

Battery compressors are those described in the battery approval
pursuant to Sections 7.001 and 7.002 of the Oil and Gas Conservation
Regulations.

Applications for approval of these facilities shall be submitted
to the Development Department of the Board. The applications shall
include:

(a) the distance from the unit or units to the nearest occupied
dwelling;

(b) a description of the present land use and the designated
land use by any zoning authority within a 1.5 km radius of
the station;

(c) the extent of advice given to residents in the vicinity of

the proposed station, regarding the details of the construction
and operation of the station;

(d) the method of noise suppression for the compressor installation;

(e) a statement as to whether the battery location is within 100 m
of a water body, water course or valley break, or is closer
than 600 m from the boundary of any city, town, village, hamlet,
densely populated area or established recreational area;

(f) for battery compressors having prime movers with a total power
rating equal to or greater than 750 kW.

(i) an application for a Clean Air Act permit and licence, and

(ii) evidence as outlined in Appendix 4 to verify that the
engine exhaust stack has been designed to maintain the
total maximum calculated concentration of nitrogen
dioxide (NO2) for all compressors within the maximum
allowable of 0.21 ppm or any other standard the Board or
Alberta Environment may specify.

3.

Field Compression Facilities

All field compressor stations require an application for a permit
as prescribed in Part 4 of The Pipeline Act, 1975. Applications
for these facilities shall be submitted to the Pipeline Department
of the Board. The application shall include the information required
in Part 2, Section 6 of the Pipeline Regulations, and

(a) a statement as to whether the station location is within 100 m
of a water body, water course or valley break, or is closer
than 600 m from the boundary of any city, town, village,
hamlet, densely populated area or established recreational area;

(b) for field compressors having prime movers with a total power
rating equal to or greater than 750 kW;

(i) an application for a Clean Air Act permit and licence, and

(ii) evidence as outlined in Appendix 4 to verify that the
engine exhaust stack has been designed to maintain the
total maximum calculated concentration nitrogen dioxide
(NO2) for all compressors within the maximum allowable
of 0.21 ppm or any other standard the Board or Alberta
Environment may specify.

4. Increased Stack Height at Existing Compressors

The Board and the Alberta Environment will review the maximum calculated
ground-level concentrations of nitrogen dioxide (NO2) upon receipt of
an application to modify or expand the facility, or in the case of
compressors larger than 750 kW, upon receipt of an application for,
or renewal of, a Clean Air licence.

The requirements for installing higher stacks at existing compressor,
as defined in Appendix 1 are as follows:

(a) Category I

Modification of most Category I exhaust stacks is not anticipated.
For each facility, the maximum ground-level concentration of NO2
will be examined taking into consideration the conversion of NOx
to NO2. Should the level of NO2 be deemed unacceptable, the
applicant may be required to monitor actual ground-level concen-
trations in the vicinity of the facility for a minimum of one
year. An evaluation of the monitoring results will then be made
to determine the action to be taken.

(b) Category II

Existing compressors that are classified as Category II as a
result of a proposed expansion must be modified in accordance
with the design criteria for new facilities as outlined in
Appendix 4.

APPENDIX 3

CALCULATION OF MINIMUM EXHAUST STACK HEIGHT
FOR SINGLE-UNIT COMPRESSORS SMALLER THAN 750 kW

For a single isolated compressor unit the exhaust stack height may be
determined using the larger of:

(1) hg = 1.5 hb,

(2) hg = ht - 0.1 Xt

where: hg = exhaust stack height (m)

h^ = height (m) to peak of compressor building
ht = tree height (m)

x^ = shortest distance (m) between exhaust
stack and trees

These requirements are intended to apply to both reciprocating engines and
gas turbines.

Should the applicant wish to use a more detailed method for determining
exhaust stack height, he must submit his complete calculations as part of
the application.

For multiple-unit compression facilities the exhaust stack heights shall
be determined by the method prescribed in Appendix 4.

APPENDIX 4 CALCULATION OF MINIMUM EXHAUST STACK HEIGHT

FOR COMPRESSION FACILITIES LARGER THAN 750 kW
AND FOR MULTIPLE-UNIT COMPRESSION FACILITIES

Applications shall contain the following details for each compression unit
in addition to the requirements specified in the Oil and Gas Conservation
Regulations and the Pipeline Regulations:

1. size (kW) of proposed compressor unit

2. calculated exhaust stack height (m) (see procedure below)

3. exhaust gas temperature (°C)

4. exhaust gas exit velocity (m/s)

5. exhaust stack inside diameter (m)

6. NO^^ emission rate (g/kW/h)

7. height (m) to peak of the compressor building

8. average height (m) of forest in the area

9. distance (m) from the base of the stack to the forest

10. distance (m) between compressor exhaust stacks shall be shown on the
plot plan, and

11. the above information for all existing compressor units if the
application is for additional compression.

The exhaust stack height shall be determined using the following method:

1. From the NO^ emission rate determine the pollutant flow rate (m^/s)
of nitrogen dioxide (NO2) for the engine or turbine.

NOTE: Recent studies conducted by Alberta Environment

have demonstrated that for the purposes of stack
design, 40 percent of the NO^ emission from
compressor stations should be assumed to convert
to NO2 before the plume impinges upon the nearby
surroundings .

2. Choose the remaining input parameters as recommended by the Alberta
Environment's publication "Guidelines for Plume Dispersion Calcula-
tions", giving consideration for factors such as terrain, number of
stacks, forest, total exhaust flow rate, stack diameter, and stack
exit temperature.

3. Calculate the "reduced stack height", hg', using Alberta Environment's
dispersion model. (See Section 2.2 of the above mentioned Guideline
for further explanation) .

4. Calculate the actual stack height, hs^
(a) if hg' < 2.5 hb, then

hs = hg' + 1.25 hb

2

(b) if hg' 1 2.5 hb, then

hs = ^s'

5. In no case may hs be less than 1.5 h^ or (h^ - 0.1 xt) •

Nomenclature

hg' = reduced stack height as calculated by model (m)

hg = actual stack height (m)

hb = peak height of building (m)

h|- = tree height (m)

X|- = shortest distance between exhaust stack and trees (m)

These requirements are intended to apply to both reciprocating engines
and gas turbines.

In determining the NO^ emission rates from a compression facility,
other significant sources of NO^^ such as boilers and electric gener-
ators shall be included in the overall stack design analysis.

I

APPENDIX 5

LIQUID WASTES

As a general rule, the operation of compressor stations can be conducted
in a manner that precludes the continuous discharge of liquid effluent,
including both process waste waters and sanitary sewage to the environ-
ment within the vicinity of the plant. Storage tanks may be used to
confine process waste waters, and septic tank and tile field installations
permit the confinement and treatment of sanitary wastes if necessary. The
storage and disposal of lubricants and chemicals shall be done in a
manner satisfactory to the Board and Alberta Environment.

An application for a Clean Water Act permit and licence will not be
required provided the applicant files a declaration of intent to conform
to the Class A Gas Processing Plant Standards as outlined in the current
Alberta Environment "Gas Processing Plants Waste Water Management
Standards".

APPENDIX 6

DECIBEL LEVELS

Ambient noise levels for all types of compressors are subject to the
noise control guidelines set out in Interim Directive ID 80-2 "Noise
Control Guidelines".

The graph provides a method of predicting the total expected decibel
level from two or more sources. It may be used to estimate the effect
of additional gas compressor units on the expected sound level in the
vicinity of a station.

It should be noted that there is approximately a six decibel attenuation
of sound pressure level with each doubling of distance away from a
particular point source,
y

C diff*r«nct b«tw*«ntotol
ond larger level (dbA)

0 12 34 5678

A-B difference between two levels being odded (db^)

SUMMING DECIBEL LEVELS

Energy Resources 640 Fifth Avenue SW
Conservation Board Calgary, Alberta
Canada T2P3G4

Informational
Letter

IL 80-30

Amendment

TO: All Oil, Gas and Pipeline Operators 21 November 1984

AMENDMENT OF ERCB IL 80-30
APPLICATION FOR APPROVAL OF
NATURAL GAS COMPRESSORS

Applications for approval of gas compression facilities are subject to
the requirements outlined in Informational Letter IL 80-30. Appendix 2
of that informational letter set criteria for certain existing
compression facilities. Those criteria were applied to applications to
modify or expand such facilities, and in the case of compressors larger
than 750 kW, the criteria were also applied to applications for renewal
of a Clean Air Licence.

In view of recent findings in Alberta and elsewhere, and in view of the
industry's commitment to fund a single major study of compressor
exhaust chemistry and wake diffusion. Alberta Environment and the Board
are prepared to amend section 4(a) of Appendix 2 of IL 80-30. For the
period needed to conduct the study this amendment suspends the
requirement to build taller stacks or monitor the ambient air in the
vicinity of existing Category I compression facilities. The results of
the study (expected to be available in 1986) will determine any further
action to be taken.

Effective immediately section 4(a) is replaced with the following:

(a) Category I

Modification of most Category I exhaust stacks is not
anticipated. For each facility, the maximum ground-
level concentration of NO2 will be examined taking
into consideration the conversion of NO^ to N02.
The results of the examination and the details of the
calculations shall be submitted to the Standards and
Approvals Division of Alberta Environment.

2

Facility operators will be required to correct

unacceptable ground-level concentrations of NO2

if the Industry funded compressor exhaust chemistry

and wake diffusion study confirms the need for corrective

action.

The remainder of IL 80-30 is not affected.

V. E. Bohme
Board Member