Natural Gas Delivery Plan

Total Page:16

File Type:pdf, Size:1020Kb

Natural Gas Delivery Plan 4th Quarter 2021 – 2031 Natural Gas Delivery Plan F Natural Gas Delivery Plan 4th Quarter 2021 – 2031 Revision 1 Date: December 11, 2020 Page 1 of 121 4th Quarter 2021 – 2031 Natural Gas Delivery Plan Table of Contents Table of Figures .......................................................................................................................................................5 List of Tables ............................................................................................................................................................8 Acronyms ..................................................................................................................................................................9 Revision History .................................................................................................................................................... 11 I. Executive Summary ....................................................................................................................................... 12 A. Introduction ............................................................................................................................................... 12 B. Consumers Energy’s Natural Gas System .......................................................................................... 13 C. Pipeline Supply ........................................................................................................................................ 16 D. Asset Classes ........................................................................................................................................... 16 1. STORAGE .............................................................................................................................................. 16 2. COMPRESSION ..................................................................................................................................... 17 3. TRANSMISSION .................................................................................................................................... 17 4. DISTRIBUTION ...................................................................................................................................... 18 E. Operational Capabilities .......................................................................................................................... 18 F. Initiatives ................................................................................................................................................... 20 G. References................................................................................................................................................ 20 II. Consumers Energy Natural Gas Delivery Plan ......................................................................................... 21 A. Vision Statement ...................................................................................................................................... 21 B. Objectives ................................................................................................................................................. 21 C. Objectives and Goals .............................................................................................................................. 21 D. Alignment with Objectives, Goals, and Outcomes.............................................................................. 24 E. “Future Back” Scenario Modeling .......................................................................................................... 26 F. Asset Focus and Changes in the Plan ................................................................................................. 28 G. References................................................................................................................................................ 29 III. Pipeline Supply ............................................................................................................................................... 30 A. Overview of Pipeline Gas Commodity Cost Trends ........................................................................... 30 B. Ongoing Refinement of Supply Plans ................................................................................................... 32 C. References................................................................................................................................................ 35 IV. Asset Classes ................................................................................................................................................. 36 A. Storage Asset Plan .................................................................................................................................. 36 1. STORAGE ASSET MANAGEMENT ......................................................................................................... 37 2. STORAGE WELL INTEGRITY PROGRAM ................................................................................................ 42 Page 2 of 121 4th Quarter 2021 – 2031 Natural Gas Delivery Plan 3. STORAGE FIELD ASSET PLAN ................................................................................................................ 44 4. STORAGE ASSET FINANCIALS ............................................................................................................... 46 B. Compression Asset Plan ........................................................................................................................ 47 1. COMPRESSION ASSET MANAGEMENT ................................................................................................. 50 2. COMPRESSION ASSET PLAN ................................................................................................................. 57 3. COMPRESSION ASSET FINANCIALS ...................................................................................................... 62 C. Transmission Asset Plan ........................................................................................................................ 63 1. TRANSMISSION ASSET MANAGEMENT ................................................................................................ 65 2. TRANSMISSION ASSET PLAN AND FINANCIALS .................................................................................... 70 3. REFERENCES ......................................................................................................................................... 70 D. Distribution Asset Plan ............................................................................................................................ 71 1. DISTRIBUTION ASSET MANAGEMENT.................................................................................................. 75 2. OVERVIEW OF DISTRIBUTION SERVICES AND VINTAGE SERVICE REPLACEMENT PROGRAM ............. 78 3. ACCELERATION OF VINTAGE MATERIAL REMEDIATION ...................................................................... 81 4. INTRODUCTION AND RECOMMENDATION FOR REGULATOR STATIONS, ODORIZERS AND STANDS.. 85 5. LEAK REMEDIATION ............................................................................................................................. 87 6. AUGMENTATION .................................................................................................................................. 90 7. CUSTOMER METERING ........................................................................................................................ 90 8. NEW BUSINESS ..................................................................................................................................... 92 9. DISTRIBUTION ASSET FINANCIALS ....................................................................................................... 93 10. REFERENCES ......................................................................................................................................... 93 V. Operational Capabilities ................................................................................................................................ 94 A. People – Talent and Workforce Approach ........................................................................................... 94 B. Process – Operating Systems Approach ............................................................................................. 95 1. THE CE WAY ......................................................................................................................................... 95 2. WORK MANAGEMENT ......................................................................................................................... 95 3. GAS SAFETY MANAGEMENT SYSTEMS ................................................................................................. 97 4. LOST AND UNACCOUNTED FOR GAS ................................................................................................ 103 C. Technology – Digital Approach ............................................................................................................ 104 VI. Initiatives ........................................................................................................................................................ 113 A. Gas System Decarbonization .............................................................................................................. 113 1. METHANE
Recommended publications
  • BAUER GRU™ BAUER Solutions for Biogas
    BAUER GRU™ BAUER Solutions for Biogas WORLDWIDE QUALITY INNOVATION RELIABILITY BAUER COMPRESSORS BIOGAS SOLUTIONS | CONTENTS | 3 CONTENTS PURELY THE RIGHT CHOICE THE CASE FOR BIOGAS › The Problem ..................................................................... 4 › The Solution: Generating Biogas As An Alternative Clean Energy Source ................... 5 › Complete Solutions .............................................................. 6 TURNKEY SOLUTIONS FOR BIOGAS › 75 Years Of Experience In Gas Compression And Processing ............................ 8 › Turnkey Solutions For Biogas Generation ............................................. 9 BAUER GRU™ Biogas Recovery Compressors For Injection Into PSA or Membrane Gas Conditioning Systems › BAUER GRU™ Overview .............................................................................................................. 10 › BAUER GRU™ Micro. .................................................................................................................. 12 › BAUER GRU™ 3 .......................................................................................................................... 13 › BAUER GRU™ 6. ......................................................................................................................... 14 › BAUER GRU™ 9. ......................................................................................................................... 15 › BAUER GRU™ 15. ......................................................................................................................
    [Show full text]
  • Appendix 10C Routing Analysis Report, Missouri River Crossing Options Routing Analysis
    NORTHERN NATURAL GAS - South Sioux City to Sioux Falls A-line Replacement Project REPORT NO. 10 ALTERNATIVES Appendix 10C Routing Analysis Report, Missouri River Crossing Options Routing Analysis South Sioux City to Sioux Falls A-Line Replacement Project Missouri River Crossing Options Dixon County, Nebraska Prepared for: Northern Natural Gas Company Prepared by: Stantec Consulting Services, Inc. July 30, 2019 ROUTING ANALYSIS SOUTH SIOUX CITY TO SIOUX FALLS A-LINE REPLACEMENT PROJECT MISSOURI RIVER CROSSING OPTIONS DIXON COUNTY, NEBRASKA Table of Contents 1.0 INTRODUCTION ................................................................................................................ 1 2.0 FEASIBILITY STUDY METHODS ........................................................................................... 1 3.0 FEASIBILITY STUDY RESULTS .............................................................................................. 3 3.1 PREFERRED ROUTE SELECTION ........................................................................................... 3 4.0 CONCLUSION .................................................................................................................. 4 5.0 REFERENCES...................................................................................................................... 5 APPENDIX A – TABLE 1 APPENDIX B – FIGURES • Figure 1 Project Location and Topography • Figure 2 National Wetlands Inventory, National Hydrography Dataset, Public Waters and Impaired Streams • Figure 3 NRCS Soil Survey Data APPENDIX
    [Show full text]
  • Yntfletic Fne]R OIL SHALE 0 COAL 0 OIL SANDS 0 NATURAL GAS
    2SO yntfletic fne]R OIL SHALE 0 COAL 0 OIL SANDS 0 NATURAL GAS VOLUME 28 - NUMBER 4- DECEMBER 1991 QUARTERLY Tsit Ertl Repository Artur Lakes Library C3orzdo School of M.ss © THE PACE CONSULTANTS INC. ® Reg . U.S. P.I. OFF. Pace Synthetic Fuels Report is published by The Pace Consultants Inc., as a multi-client service and is intended for the sole use of the clients or organizations affiliated with clients by virtue of a relationship equivalent to 51 percent or greater ownership. Pace Synthetic Fuels Report Is protected by the copyright laws of the United States; reproduction of any part of the publication requires the express permission of The Pace Con- sultants Inc. The Pace Consultants Inc., has provided energy consulting and engineering services since 1955. The company experience includes resource evalua- tion, process development and design, systems planning, marketing studies, licensor comparisons, environmental planning, and economic analysis. The Synthetic Fuels Analysis group prepares a variety of periodic and other reports analyzing developments In the energy field. THE PACE CONSULTANTS INC. SYNTHETIC FUELS ANALYSIS MANAGING EDITOR Jerry E. Sinor Pt Office Box 649 Niwot, Colorado 80544 (303) 652-2632 BUSINESS MANAGER Ronald L. Gist Post Office Box 53473 Houston, Texas 77052 (713) 669-8800 Telex: 77-4350 CONTENTS HIGHLIGHTS A-i I. GENERAL CORPORATIONS CSIRO Continues Strong Liquid Fuels Program 1-1 GOVERNMENT DOE Fossil Energy Budget Holds Its Ground 1-3 New SBIR Solicitation Covers Alternative Fuels 1-3 USA/USSR Workshop on Fossil Energy Held 1-8 ENERGY POLICY AND FORECASTS Politics More Important than Economics in Projecting Oil Market 1-10 Study by Environmental Groups Suggests Energy Use Could be Cut in Half 1-10 OTA Reports on U.S.
    [Show full text]
  • Reducing Emissions When Taking Compressors Off-Line (PDF)
    Lessons Learned from Natural Gas STAR Partners Reducing Emissions When Taking Compressors Off-Line Executive Summary blowdown valve and from reciprocating compressor rod packing, total emissions can be significantly reduced. Four Compressors are used throughout the natural gas industry options for reducing emissions when taking compressors to move natural gas from production and processing sites off-line are discussed in this paper. These include: to customer distribution systems. Compressors must periodically be taken off-line for maintenance, operational Keeping compressors pressurized when off-line. stand-by, or emergency shut down testing, and as a result, methane may be released to the atmosphere from a Connecting blowdown vent lines to the fuel gas number of sources. When compressor units are shut down, system and recovering all, or a portion, of the vented typically the high pressure gas remaining within the gas to the fuel gas system. compressors and associated piping between isolation valves is vented to the atmosphere (‘blowdown’) or to a Installing static seals on compressor rod packing. flare. In addition to blowdown emissions, a depressurized system may continue to leak gas from faulty or improperly Installing ejectors on compressor blowdown vent sealed unit isolation valves. lines. Natural Gas STAR Partners have found that simple Keeping compressors fully pressurized when off-line changes in operating practices and in the design of achieves immediate payback—there are no capital costs blowdown systems can save money and significantly and emissions are avoided by reducing the net leakage reduce methane emissions by keeping systems fully or rate. Routing blowdown vent lines to the fuel gas system partially pressurized during shutdown.
    [Show full text]
  • A Brief Review of Compressor Stations Prepared By: Nathan Kloczko, Yale University Graduate Student Assistant November 2015
    www.environmentalhealthproject.org A Brief Review of Compressor Stations Prepared by: Nathan Kloczko, Yale University Graduate Student Assistant November 2015 Compressor Stations and Pipelines To transport natural gas across the country, the oil and gas industry relies on an extensive network of inter- and intrastate pipelines. A crucial component of this network is the compressor station. As gas is transported, it needs to remain under pressure (800-1500 psi) to ensure consistent movement against the friction and elevation changes it experiences through the pipeline. Compressor stations, located every 40- 70 miles along the pipeline, are used to increase the gas pressure and to scrub the gas of any liquids or solids that may have accumulated through transport. These stations typically consist of 8-16 compressors of 1,000 horsepower or more running in parallel, operating continuously.i Sources of Emissions There are three types of compressor stations: reciprocal, centrifugal, and electric. Reciprocal and centrifugal stations are powered by unprocessed natural gas taken directly from the pipeline. Depending on the composition of the shale play from which the gas in the pipeline was extracted, this gas can be considered 'dry' or 'wet.' Wet gas, or gas that contains a higher composition of C2+ hydrocarbons such as ethane and butane, (commonly found in the Marcellus shale playii), often does not meet the necessary specifications for compressor engines, causing incomplete combustion of the natural gas and increased emissions of a number of chemicals, explained in detail below. Electric compressors are powered independently, so there are significantly fewer emissions associated with their operation. Two other sources of pollutant emissions from compressor stations are from fugitive emissions (leaks) and blowdowns.
    [Show full text]
  • Small Scale Liquefaction & Distribution
    SMALL SCALE LIQUEFACTION & DISTRIBUTION - Biomethane and Natural Gas CLEAN ENERGY SMALL SCALE LIQUEFACTION & DISTRIBUTION Biomethane and Natural Gas 1 The Cryostar Group Specialising in equipment and expertise for industrial gas, LNG, hydrocarbons and clean energy, Cryostar is an international company exporting more than 90% of its products and serving customers worldwide. Founded in 1966, Cryostar is present on all continents, supported by its business centres and subsid- iaries. Today the company combines the resources and competencies of a local network with decen- tralised teams and its management and research headquarters in France. Cryostar delivers pumps, turbines, compressors, heat exchangers, automatic filling and refuelling stations, natural gas liquefaction/regasification plants and power plants to customers with the most demanding requirements. Cryostar’s innovative solutions have a proven track record of improving customers’ process performance. Cryostar has always been at the forefront of cryogenic technology. In 1967, it was the first company in Europe to produce cryogenic distribution pumps for liquefied air gases. It is in this spirit of consistently bringing innovative solution to customers that Cry- ostar has developed packaged solutions from small scale natural gas liquefaction to distribution. Headquarters and production facility Hésingue, France Think global, act local To stay close to its customers around the globe, Cryostar has established several Business & Service Centres and collaborates with experienced local agents and distributors. CRYOSTAR United Kingdom CRYOSTAR France CRYOSTAR Automation CRYOSTAR USA East CRYOSTAR USA West CRYOSTAR China CRYOSTAR India CRYOSTAR Singapore CRYOSTAR Brazil CRYOSTAR BUSINESS CENTRES GLOBAL CRYOSTAR AGENTS 2 SMALL SCALE LIQUEFACTION & DISTRIBUTION - Biomethane and Natural Gas Safety Safety is an integral part of Cryostar’s management and manufacturing commitments.
    [Show full text]
  • Module Electric Power Generation
    Copyright © 2011 Revised 2018 Center for Energy Workforce Development MODULE 3 ELECTRIC POWER GENERATION STUDENT GUIDE REVISED 06/2018 © 2011 – Revised 2018 Center for Occupational Research and Development Center for Energy Workforce Development Educational providers and their respective instructors have the right to duplicate and use these materials for instructional purposes. ISBN 978-1-1-57837-649-1 Neither the Center for Occupational Research and Development nor the Center for Energy Workforce Development assume any liabilities with respect to the use of, or for damages resulting from the use of, any information, apparatus, method, or process described in this publication. For questions or additional information regarding these materials, please contact Julie Strzempko at [email protected]. This work is licensed under the Creative Commons Attribution-NonCommercial-ShareAlike 3.0 Unported License. To view a copy of this license, visit http://creativecommons.org/licenses/by-nc-sa/3.0/ or send a letter to Creative Commons, 444 Castro Street, Suite 900, Mountain View, California, 94041, USA. MODULE 3 ELECTRIC POWER GENERATION Table of Contents Unit A: Conventional Electric Power Generation Systems ....................................................... 7 Unit B: Overview of Generation Fuel Sources ...................................................................... 43 Unit C: Overview of Emerging and Alternative Generation Technologies ............................... 72 Unit A: Conventional Electric Power Generation Systems Energy Industry Fundamentals — Module 3 7 Energy Industry Fundamentals — Module 3 8 UNIT A: CONVENTIONAL ELECTRIC POWER GENERATION SYSTEMS Electric Power Generation As mentioned in Module 1, most electricity is generated by electromechanical generators that are driven by mechanical energy forces. The most common electricity generation mechanical force source is what is referred to as a “steam-electric cycle.” Water (in liquid form) is heated in a furnace to produce steam.
    [Show full text]
  • Origins and Growth of the British Gas Plant Operations Department
    The Origins and Growth of the British Gas Plant Operations Department The Plant Operations Department had its origins in the organizational changes which took place in the gas industry in the 1960s to pave the way for the arrival of natural gas. It was to be responsible for the operation of all terminals, storage plants and compressor stations which were to form part of the new National Transmission System. Six maps of the developing National Transmission System from 1966 to 1977 are attached as an Appendix. The Importation of Algerian LNG After experimenting with liquefied natural gas (LNG) cargoes from Lake Charles, Louisiana, the Gas Council began in 1964 to ship LNG from Algeria into a newly-built onshore storage terminal at Canvey Island. Gas produced there was fed into an 18inch diameter “Backbone Feeder” which was built specially to take natural gas from Canvey towards Leeds with offshoots to Sheffield and Manchester for use in reformer plants to produce town’s gas. The Arrival of North Sea Gas The discovery of natural gas in commercial quantities off the east coast of England in 1965 led to the signing of a contract with BP in 1966 for the delivery of natural gas from the offshore West Sole field to a new onshore terminal at Easington near Hull. This was also connected into the 18 inch feeder. Later in 1966, further substantial offshore discoveries were made in the southern sector of the North Sea and it became clear that enough natural gas would be available to supply the whole of the UK directly and to justify the construction of the major new transmission network which became known as the National Transmission System (NTS).
    [Show full text]
  • Department of Homeland Security
    Vol. 77 Thursday, No. 110 June 7, 2012 Part III Department of Homeland Security Coast Guard 46 CFR Parts 25, 27, 28, et al. Carbon Dioxide Fire Suppression Systems on Commerical Vessels; Final Rule VerDate Mar<15>2010 18:52 Jun 06, 2012 Jkt 226001 PO 00000 Frm 00001 Fmt 4717 Sfmt 4717 E:\FR\FM\07JNR2.SGM 07JNR2 tkelley on DSK3SPTVN1PROD with RULES2 33860 Federal Register / Vol. 77, No. 110 / Thursday, June 7, 2012 / Rules and Regulations DEPARTMENT OF HOMELAND call Renee V. Wright, Program Manager, mandates regulations, including fire SECURITY Docket Operations, telephone 202–366– protection regulations, for vessels 9826. carrying liquid bulk dangerous cargoes; Coast Guard SUPPLEMENTARY INFORMATION 46 U.S.C. 4102 authorizes regulations, after consultation with the Towing 46 CFR Parts 25, 27, 28, 31, 34, 35, 62, Table of Contents for Preamble Safety Advisory Committee (TSAC), for 71, 76, 78, 91, 95, 97, 107, 108, 112, 115, I. Abbreviations fire protection and suppression 118, 119, 122, 131, 132, 147, 162, 167, II. Regulatory History measures on towing vessels; 46 U.S.C. 169, 176, 181, 182, 185, 189, 190, 193, III. Basis and Purpose 4302 authorizes safety equipment 194, and 196 IV. Background regulations for recreational vessels; and V. Discussion of Comments and Changes 46 U.S.C. 4502 mandates fire [USCG–2006–24797] VI. Incorporation by Reference VII. Regulatory Analyses extinguisher regulations for some RIN 1625–AB44 A. Regulatory Planning and Review uninspected commercial fishing vessels B. Small Entities and authorizes safety equipment Carbon Dioxide Fire Suppression C. Assistance for Small Entities regulations for certain other Systems on Commercial Vessels D.
    [Show full text]
  • Natural Gas Pipeline Compressor Stations | 2
    Business & Technology Strategies Tech Surveillance c&i case studies in beneficial electrification Electrifying Natural Gas Opportunities for Beneficial Electrification and Load Flexibility in Natural Gas Pipeline Compressor Stations BY PETER MAY-OSTENDORP AND KATHERINE DAYEM , XERGY CONSULTING, MAY 2018 subject matter expert for questions on this topic Brian Sloboda, Program and Product Line Manager-Energy Utilization/Delivery/ Energy Efficiency, [email protected] INTRODUCTION The wise use of electricity, Beneficial Electrification, has sparked widespread re-thinking of policies that encourage or mandate less electricity use and promote infrastructure planning. Advancements in electric technologies continue to create new opportunities to use electricity as a substitute for on-site fossil fuels like natural gas, propane, gasoline and fuel oil, with increased efficiency and control. It also offers local economic development and enhances the quality of the product used by the customer. Electrifying industrial and commercial processes is a proven method to help local businesses stay competitive. Beneficial electrification strengthens the cooperative presence in the community and offers benefits to the electric system, such as environmental performance, reduced total energy costs to the consumer, and grid flexibility. Cooperatives can start by working with their C&I members to identify opportunities amongst potentially large loads. To provide examples of various approaches to working with C&I customers on beneficial electrification initiatives, NRECA is developing a series of case studies . s business and technology strategies distributed energy resources work group C&I Case Studies in Beneficial Electrification: Natural Gas Pipeline Compressor Stations | 2 This case study focuses on electric cooperatives in oil-and-gas country that have started promoting the adoption of electric and dual-drive (gas-electric) compressors for natural gas pipeline compressor stations.
    [Show full text]
  • Historic Manufactured Gas and Related Gas Storage Facilities on Long Island
    Historic Manufactured Gas and Related Gas Storage Facilities on Long Island Prepared by KeySpan Corporation For The Long Island Power Authority May 2007 TABLE OF CONTENTS EXECUTIVE SUMMARY__________________________________________ PAGE 4 ABBREVIATIONS AND ACRONYMS_________________________________19 GLOSSARY _________________________________________________________21 MAP OF HISTORIC MANUFACTURED GAS AND RELATED GAS STORAGE FACILITIES ON LONG ISLAND ______________________________________26 MAJOR FACILITIES_________________________________________________28 MANUFACTURED GAS PLANTS _____________________________________29 Nassau County Sites __________________________________________________ 32 Glen Cove MGP ____________________________________________________ 33 Hempstead - Clinton Road MGP ______________________________________ 36 Hempstead - Intersection Street MGP __________________________________ 37 Suffolk County Sites ___________________________________________________ 39 Babylon MGP_______________________________________________________ 40 Bay Shore MGP _____________________________________________________ 42 Halesite MGP _______________________________________________________ 47 Patchogue MGP ____________________________________________________ 49 Sag Harbor MGP ____________________________________________________ 51 Queens County Sites __________________________________________________ 53 Far Rockaway MGP _________________________________________________ 54 Rockaway Park MGP ________________________________________________ 56 May
    [Show full text]
  • Industrial Hydrocarbon Processes
    Handbook of INDUSTRIAL HYDROCARBON PROCESSES JAMES G. SPEIGHT PhD, DSc AMSTERDAM • BOSTON • HEIDELBERG • LONDON NEW YORK • OXFORD • PARIS • SAN DIEGO SAN FRANCISCO • SINGAPORE • SYDNEY • TOKYO Gulf Professional Publishing is an imprint of Elsevier Gulf Professional Publishing is an imprint of Elsevier The Boulevard, Langford Lane, Kidlington, Oxford OX5 1GB, UK 30 Corporate Drive, Suite 400, Burlington, MA 01803, USA First edition 2011 Copyright Ó 2011 Elsevier Inc. All rights reserved No part of this publication may be reproduced, stored in a retrieval system or transmitted in any form or by any means electronic, mechanical, photocopying, recording or otherwise without the prior written permission of the publisher Permissions may be sought directly from Elsevier’s Science & Technology Rights Department in Oxford, UK: phone (+44) (0) 1865 843830; fax (+44) (0) 1865 853333; email: [email protected]. Alternatively you can submit your request online by visiting the Elsevier web site at http://elsevier.com/locate/ permissions, and selecting Obtaining permission to use Elsevier material Notice No responsibility is assumed by the publisher for any injury and/or damage to persons or property as a matter of products liability, negligence or otherwise, or from any use or operation of any methods, products, instructions or ideas contained in the material herein. Because of rapid advances in the medical sciences, in particular, independent verification of diagnoses and drug dosages should be made British Library Cataloguing in Publication Data
    [Show full text]