1、 Survey of Underground Storage Of Natural Gas In the United States And Canada: 2013/2014 Copyright 2014 American Gas Association. All rights reserved. Produced in cooperation with the AGA Underground Storage Committee Catalog No. XU1401 July 2014FOREWORD The first Survey of Underground Gas Storage F
2、acilities in the United States and Canada (Catalog No. X54266) was undertaken during 196566 and published by the American Gas Association (AGA) in 1966. Pertinent data on the general physical characteristics of known underground gas storage projects were reported. The second edition (and first revis
3、ion Catalog No. X54270) was published in 1970. Subsequent editions were published as follows: third edition published in 1978 (Catalog No. XU0678); fourth edition published in 1983 (Catalog No. XY0783); fifth edition published in 1988 (Catalog No. XU8809A); sixth edition published in 1993 (Catalog N
4、o. XU9307); seventh edition published in 1997 (Catalog No. XU9701); eighth edition published in 1999 (Catalog No. XU9901); ninth edition published in 2001 (Catalog No. XU0212) ); tenth edition published in 2007 (Catalog No. XU0404). Eleventh edition published in 2011 (Catalog No. XY1102). This is th
5、e twelfth edition in the series. This document contains information as provided by the operators and/or owners of the underground storage facilities and/or reported to the editor (in the case of sold facilities) for the participation year listed in under “Last Updated“ or noted in “Footnotes“. Part
6、I provides a brief synopsis of the history of underground gas storage in North America. Part II lists data reported by the storage facility operators/owners. All facilities active, inactive, abandoned, in the process abandonment or under construction are listed and identified. Information is reprodu
7、ced as submitted to AGA. In instances where the data were provided in units other than requested, conversions were made accordingly. This survey is a product of the AGA Underground Storage Committee (USC). AGA would like to thank the officers of the USC and the members of the Statistics / Computer C
8、apabilities task group, in particular, Mark Gredell, Thomas Chrisfield and Matthew Rowan, for their significant contributions to this edition of the publication. Furthermore, the USC would like to acknowledge all survey respondents who provided facility data updates. Notice: In issuing and making th
9、is publication available, AGA is not undertaking to render professional or other services for or on behalf of any person or entity. Nor is AGA undertaking to perform any duty owed by any person or entity to someone else. Anyone using this document should rely on his or her own independent judgment o
10、r, as appropriate, seek the advice of a competent professional in determining the exercise of reasonable care in any given circumstances. The statements in this publication are for general information and represent an unaudited compilation of statistical information that could contain coding or proc
11、essing errors. AGA makes no warranties, express or implied, nor representations about the accuracy of the information in the publication or its appropriateness for any given purpose or situation. Information on the topics covered by this publication may be available from other sources, which the use
12、r may wish to consult for additional views or information not covered by this publication. Copyright 2014 American Gas Association. All rights reserved. This work may not be reproduced or transmitted in any form or by any means, electronic or mechanical, including photocopying, recording, or by info
13、rmation storage and retrieval system without permission in writing from the American Gas Association.PART I UNDERGROUND GAS STORAGE HISTORY Page 4 Underground Gas Storage History The Purpose of Underground Gas Storage Natural gas supply sources often experience large variations of flow. Gas demand f
14、rom pipelines also can fluctuate seasonally, daily and even hourly. Underground gas storage is an efficient way to balance these discrepancies between gas supply input and gas market demand. Gas goes into storage when market requirements are lower than supply volumes flowing into the pipeline. Gas c
15、omes out of storage when market demand exceeds available supply. Effective use of underground gas storage requires delivery and permanent containment of a certain level of gas as “base” or “cushion” gas. The base gas maintains the pressure required for gas delivery at the minimum acceptable flow rat
16、e. Gas delivery from an underground gas storage facility requires the pre-injection of the desired level of “top” or “working” gas. The rate at which an underground gas storage facility can take gas on injection and deliver gas on withdrawal is normally dependent on the characteristics of both the u
17、nderground reservoir and the surface facilities. A Brief History of the Development of Underground Gas Storage In 1915, the first recorded experiment that successfully stored gas underground was accomplished in Welland County, Ontario, Canada. Several old wells in a partially depleted gas field were
18、 reconditioned for gas storage service. The pressure in the reservoir increased as injected gas entered the wells. Gas withdrawn from the wells the following winter was used for peaking purposes. Thus, the underground gas storage industry was born. M.J. Judge (National Fuel Gas Company) envisioned t
19、his novel approach for natural gas storage, inspired by the experiences of East Ohio Gas Company (EOG). Several years earlier EOG unsuccessfully attempted to dewater an abandoned salt mine near Cleveland, Ohio, for gas storage use. There had been other unrecorded attempts at gas storage in partially
20、 depleted sands. These efforts were temporary and operational in nature (for controlling high line pressures and for recycling operations in oil fields), not for managing gas supply and demand. The success of the Welland County experiment prompted Iroquois Gas Company (a National Fuel affiliate) to
21、apply the same technology in 1916 to the depleted Zoar Field south of Buffalo, N.Y. This project was also successful, and the Zoar project (the first storage operation in the United States) today is the oldest continuously operated underground gas storage facility. By the end of 1930, the gas storag
22、e industry consisted of nine storage pools in six states, with total capacity of 18 billion cubic feet (Bcf). In 1931, Louisville Gas and Electric Company (LG usually depleted gas or oil field. Aquifer: Porous and permeable rock stratum; pore space, which was originally filled with water, into which
23、 stored gas is confined by suitable structure, permeability barriers and hydrostatic water pressure Domal Salt Cavern: An artificially created solution-mined cavity within a domal salt body. Bedded Salt Cavern: An artificially created solution-mined cavity within a laterally extensive, layered or be
24、dded salt body. Mined Cavern: An artificially created mined cavity within any rock type. Abandoned Mine: A structure originally created to extract mineral deposits and has been converted for gas storage. Other: A type of storage not listed above. Please specify. Original Content The original content
25、s of the reservoir or storage space: gas, water, oil, salt water, salt, rock, or coal Discovery Pressure (Psig wh) (well head pressure) The average shut-in surface wellhead pressure of the gas filled porosity. (Omit for cavern facilities “na” should be used.) Original In-Place Reserves (Omit for cav
26、ern and aquifer facilities “na” should be used). Gas (MMcf): The original estimated total quantity of gas in place for a depleted gas field (includes both recoverable and non-recoverable) Oil (bbls): The original estimated total quantity of oil in place for a depleted oil field (includes both recove
27、rable and non-recoverable) Storage Formation Name The geologic or drillers name for the rock strata being used for storage. Storage Lithology The type of rock constituting the storage formation, e.g. sandstone, granite, carbonate, domed salt, bedded salt, coal, etc. Gross Thickness (feet) The averag
28、e thickness of total formation intervals containing gas. For caverns, average height of caverns used for gas storage. Page 8 Type of Geological Trap The type of geologic containment mechanism used to trap the gas. Select from the list below: Structural Trap: A sealed geologic structure in deformed s
29、trata such as a fold or fault. Principal hydrocarbon sealing mechanism is due to the shape or contour of the overlying caprock, preventing escape of the hydrocarbons contained within the reservoir rock. Stratigraphic Trap: Principal hydrocarbon trapping mechanism is due to lateral changes from reser
30、voir rock to trapping rock because of changes in rock type, pinchouts, rock quality, hydrodynamics, unconformities, sedimentary features etc., not due to shape or contours of the reservoir or trapping rock. Struct./ Strat.: Principal hydrocarbon trapping mechanism is due a combination of structural
31、and stratigraphic trapping conditions as defined above. Reef: Principal hydrocarbon trapping mechanism is due to confinement of hydrocarbons in a mound-like reservoir rock type built by organisms such as corals, etc., surrounded by gas-impermeable, trapping non-reef rock types. Domal Salt Cavern: An
32、 artificially created solution-mined cavity within a domal salt body. Bedded Salt Cavern: An artificially created solution-mined cavity within a laterally extensive, layered or bedded salt body. Mined Cavern: An artificially created mined cavity within any rock type. Maximum Depth to Formation (feet
33、) The maximum depth in feet to the TOP of the storage formation from ground level. For caverns, the maximum depth to the bottom of the cavern space. Minimum Depth to Formation (feet) The minimum depth in feet to the TOP of the storage formation from ground level. For caverns, the minimum depth to th
34、e top of the cavern space. Areal Extent of Reservoir (acres) Approximate number of acres occupied by the gas bubble (excluding buffer zone). FACILITY DATA Injection/ Withdrawal Wells Total: Total number of active wells used for injection and/ or withdrawal of gas (includes vertical, horizontal and d
35、eviated). Horizontal/Deviated: Number of active wells used for injection and/ or withdrawal of gas that are horizontal or highly deviated with an inclination greater than 75 degrees Pressure Control and/ or Observation Wells The number of wells used for monitoring pressure and/ or fluid levels. Tota
36、l Horsepower The total horsepower rating of compression available for injection or withdrawal for the reservoir/cavern. This compression may be dedicated to the specific reservoir or shared with other reservoirs/caverns. If horsepower is shared, indicate “Yes” after the value and list under “Footnot
37、es” the name(s) of the other reservoir(s)/cavern(s). Gathering Lines (miles) Total: The number of miles of storage pipeline within the storage facility. Max Size (inches): The largest diameter pipe for injection/withdrawal in the storage field. DESIGN VALUES Base Gas (MMcf) (injected plus native bas
38、e) The volume of gas required to provide enough pressure to cycle the normal working storage volume. (Base gas volumes are reported in total without reference as to whether the volume reported might be recovered when storage operations are ultimately terminated). Working Gas Capacity (MMcf) The maxi
39、mum designed gas capacity in the reservoir above the designed level of base gas. This volume is NOT tied to any specific date or pressure. It may or may not be completely injected or withdrawn during any particular season. Conditions permitting, the total working capacity could be used more than onc
40、e during any season (see annual cycling capability). Maximum Storage Pressure (Psig wh) (well head pressure) The average shut-in surface wellhead pressure at planned maximum design capacity of gas in storage. Maximum Design Deliverability (MMcf/d) The maximum daily volume of gas planned to be availa
41、ble for delivery on a design day basis using current facilities (e.g., well, pipeline, compression, metering, dehydration) and taking into account other operational constraints. (This is not tied to a specific date). Page 9 Late Season / Last Day Deliverability (Mcf/d) The maximum daily volume of ga
42、s available for delivery using current facilities (e.g., well, pipeline, compression, metering, dehydration) and taking into account other operational constraints when the reservoir or cavern is at or near its base gas volume. (This is not tied to a specific date). Annual Cycling Capability The typi
43、cal number of times the working gas is cycled (withdrawn and re-injected) on an annual basis. Traditionally, depleted reservoirs and aquifers have been cycled once per year; however, todays environment may increase the cycles. Salt caverns and other void space storage formation may have capabilities
44、 of multiple cycles each year. FOOTNOTES Please use the Footnotes section to further explain your responses as needed. NOTES ON UNITS USED Bbls 42 U.S. gallons MMcf Millions of cubic feet. Mcf Thousands of cubic feet Mcf/d Thousands of cubic feet per day Psig-wh Pounds per square inch gage at wellhe
45、ad EXPLANATION OF “nr”, “na” The current information on the data sheets may include the following notations: “nr” This means “no response” has been received to date. Respondents are encouraged to fill in missing information. “na” This means “not applicable” and is used when the information does not
46、apply to your situation (e.g. initial reserves for a salt cavern storage facility is “na”.) Page 10 TABLE OF CONTENTSPage NumberPart I 4Underground Gas Storage History 5Part II Storage Directory 7Definitions for Underground Storage Facility Data Sheets 8Directory EntriesAlabama 11Alberta 11Arkansas
47、13British Columbia 14California 15Colorado 19Illinois 22Indiana 32Iowa 39Kansas 42Kentucky 48Louisiana 56Maryland 61Michigan 62Minnesota 80Mississippi 80Missouri 83Montana 84Nebraska 85New Mexico 86New York 87Ohio 95Oklahoma 102Ontario 107Oregon 118Pennsylvania 121Quebec 138Saskatchewan 139Texas 143
48、Utah 155Virginia 156Washington 156West Virginia 157Wyoming 166Page 11State/Province Alabama Alberta AlbertaOperating Company Bay Gas Storage Co. AEC Oil and Gas Co. ATCO Gas and Pipelines Ltd.Storage Facility Name McIntosh Salt Dome Hythe Gas Storage CarbonFacility Status Active Active ActiveCounty
49、Washington Hythe KneehillYear Activated/ Deactivated 1994 1984 1967Discovery/ Development Year 1945 1978 1955RESERVOIR DESCRIPTIONType of Storage Salt Cavern Depleted Reservoir Depleted ReservoirOriginal Contents Salt Gas GasDiscovery Pressure 2,978 1,303 Original In-Place Reserves - Gas16,460 115,000 Original In-Place Reserves - OilStorage Formation Name Louann Salt Gething GlauconiteStorage Lithology Salt SandstoneGross Thickness 1,000 20 21 Type of Geological Trap Salt Cavern Stratigraphic Trap Stratigraphic TrapGeologic Age CretaceousMax Depth to Formation 5,000 6,
