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市場調查報告書

油汚濁水市場：北美的石油、葉岩、天然氣部門之機會

Produced Water Market : Opportunities in the Oil, Shale and Gas Sectors in North America

出版商 Global Water Intelligence
出版日期 2011年03月 商品編碼 139286
內容資訊 英文  
價格
US $ 3500 PDF download via website, and Hard Copy by courier


油汚濁水市場：北美的石油、葉岩、天然氣部門之機會 是由出版商Global Water Intelligence在2011年03月所出版的。 這份英文市場調查報告書價格從美金3500起跳。

簡介

本報告書為北美油汚濁水（Produced Water）市場的相關分析，包含美國、加拿大相關法規體制、油汚濁水技術與管理、處理、再利用動向、市場加入動向與各企業簡介、以及今後市場機等整理、概述如下。

總綱

第1章 油汚濁水摘要

  • 油汚濁水定義
  • 石油・天然氣資源概要
  • 油汚濁水性質

第2章 法規體制

  • 美國：聯邦機關
  • 聯邦法
  • 州法
  • 加拿大：法規體制機關
  • 加拿大：現行法規體制
  • 加拿大：新興法規體制

第3章 回收・加工水要求事項

  • 石油回收機制
  • 油田一次回收
  • 油田二次、三次回收
  • 水要求事項的變動
  • 石油砂岩的加工水

第4章 油汚濁水技術

  • 管理方法
  • 油水分離系統
  • 生物學上處理用的薄膜生物反應器
  • 最新水處理技術
  • 石油砂岩現場回收技術

第5章 油汚濁水管理、處理、再利用

  • 油汚濁水管理方法
  • 石油砂岩加工水管理技術
  • 案例研究
  • 處理過的油汚濁水販售前景

第6章 主要市場

  • 葉岩探査
  • 加拿大石油砂岩
  • 煤層甲烷
  • 做為傳統的石油異地廢棄代替策略的去除鹽分
  • 低鹽分水

第7章 油汚濁水市場分析

  • 市場分割・分類
  • 主要以及新興加入者
  • 統合
  • 供應鏈導覽
  • 市場佔有率預測
  • 將來市場成長
  • 油汚濁水費用預測
  • 運作服務

第8章 對市場的連接

  • 油汚濁水市場發展
  • 市場連接與參加概要
  • 為了加入葉岩天然氣油汚濁水市場的傳統手法　其他

第9章 市場的機會

  • 葉岩天然氣油汚濁水市場
  • 加拿大石油砂岩之市場機會
  • 油汚濁水的再利用方法
  • 自訂液體

訪談對象

參考

目錄

Abstract

Overview

The report is based on more than 30 primary research interviews with high level industry insiders and focuses on the four sectors where the potential for water treatment technology is greatest:

  • The treatment of frac water in the shale: the current moratorium on development in the Marcellus shale is led by consumer concerns about the contamination of ground water, and represents the largest political obstacle to the fracking industry' s development. How can this be overcome?
  • The desalination of oil-field produced water as an alternative to off-site reinjection: In some parts of the US it is not possible to re-inject produced on-site, due to regulation and geology. Is it economically viable to desalinate produced water for reuse?
  • The demand for “designer” water in secondary and tertiary oil recovery: most enhanced oil recovery techniques require water of a specific salinity. To what extent is this an opportunity for membrane separations technology?
  • Meeting the water needs of the Canadian oil sands: extracting heavy crude and bitumen from oil sand is a thirsty process (up to 4.5 barrels of water are required for each barrel of synthetic crude oil produced). With tighter regulatory control of water abstraction for the oil sands, is there an opportunity for greater reuse?

Produced Water Market analyses each of these themes to show you the scope of the opportunities and the nature of the challenges that will need to be overcome if you are to succeed in this sector. It takes a comprehensive look at the background to the market, including the regulatory drivers, the technologies, the supply chain, and the companies involved .

Table of Contents

Publication information

Foreword

Executive summary

  • Growth sectors
  • Market challenges
    • Figure 1.1 Energy consumption, feedwater & maximum product water salinity of desalination technologies
  • Opportunities
  • Potential Winners
  • Conclusion
  • Units and abbreviations

1. Introduction to produced water

  • 1.1 Produced water definitions
    • Figure 1.1 Produced water volumes: Globally and statewise in the U.S.
  • 1.2 Overview of sources of oil and gas covered in this report
    • 1.2.1 Onshore and offshore oil
    • 1.2.2 Shale gas
    • 1.2.3 Coal bed methane
    • 1.2.4 Oil sands
      • Figure 1.2 Typical composition of McMurray Formation oil sands
  • 1.3 The nature of produced water
    • 1.3.1 Produced water from oil and gas production
      • Figure 1.3 Typical produced water constituents from oil, gas and CBM production
      • Figure 1.4 Produced water constituents, factors and negative effects
    • 1.3.2 Produced water from CBM production
    • 1.3.3 Produced water from the Canadian oil sands
      • Figure 1.5 Typical chemistry for formation water in McMurray Formation

2. Regulations

  • 2.1 United States: Federal level organisations
    • 2.1.1 The Environmental Protection Agency
      • Figure 2.1 Overview of the relevant responsibilities of the Environmental Protection Agency
      • Figure 2.2 Injection well classification
    • 2.1.2 Onshore Subcategory of the Oil and Gas Extraction Point Source Category
    • 2.1.3 Coastal Waters Subcategory of the Oil and Gas Extraction Point Source Category
    • 2.1.4 Offshore Subcategory of the Oil and Gas Extraction Point Source Category
    • 2.1.5 Coal bed methane ELGs
      • Figure 2.3 Status of coal bed methane effluent limitation guidelines
    • 2.1.6 The Bureau of Land Management (BLM)
      • Figure 2.4 Overview of the relevant responsibilities of the BLM
    • 2.1.7 The Bureau of Ocean Energy Management, Regulation and Enforcement (BOEMRE)
      • Figure 2.5 Overview of the relevant responisbilites of the BOEMRE
  • 2.2 Federal regulations
    • 2.2.1 Shale development and environmental impacts
      • Figure 2.6 Chesapeake Bay TMDL limits
    • 2.2.2 Current legislation and changes
      • Figure 2.7 Federal legislation
    • 2.2.3 Emerging Federal regulations
      • Figure 2.8 Topics and questions to be covered by EPA study on hydraulic fracturing
  • 2.3 United States: State level regulations
    • Figure 2.9 State level regulations
    • Figure 2.10 New effluent standards for oil and gas wastewater, May 2010
    • 2.3.1 Coal bed methane regulations in Colorado, Montana, New Mexico and Wyoming
      • Figure 2.11 CBM disposal and discharge standards for Colorado, Montana, New Mexico and Wyoming
      • Figure 2.12 CBM produced water disposal options in Wyoming and Montana
  • 2.4 Canada: Regulatory organisations
    • Figure 2.13 Regulatory bodies responsible for produced water in the oil sands
  • 2.5 Canada: Current regulations
    • 2.5.1 Approval process for a proposed oil sands mine or in-situ project
    • 2.5.2 Mining water recycling
    • 2.5.3 In-situ water recycling
  • 2.6 Canada: Emerging regulations
    • 2.6.1 Mining operations
      • Figure 2.14 Phase in sequence for capturing fines in tailings water
    • 2.6.2 In-situ
      • Figure 2.15 Increasing water regulation in the oil sands
    • 2.6.3 Enforcement

3. Recovery and process water requirements

  • 3.1 Oil recovery mechanisms
    • Figure 3.1 Summary of common recovery mechanisms
  • 3.2 Primary oilfield recovery
    • 3.2.1 Natural mechanisms
      • Figure 3.2 Natural reservoir drive mechanisms
    • 3.2.2 Artificial lift
    • 3.2.3 Summary of primary oilfield recovery
  • 3.3 Secondary and tertiary oilfield recovery
    • 3.3.1 Secondary oilfield recovery
      • Figure 3.3 Treatment steps for seawater
      • Figure 3.4 Produced water re-injection volumes onshore and offshore
      • Figure 3.5 Substances in produced water that can affect reservoirs when re-injected
    • 3.3.2 Tertiary oilfield recovery (enhanced oil recovery)
    • 3.3.3 Thermal methods
    • 3.3.4 Gas injection
    • 3.3.5 Chemical flooding
    • 3.3.6 Low salinity water EOR
  • 3.4 Fracturing water requirements
    • Figure 3.6 Fracturing fluid components
    • Figure 3.7 Fracturing fluid constituents
    • Figure 3.8 Flowback reuse as fracturing fluid contaminants
    • Figure 3.9 Constituents of flowback water
    • 3.4.1 Water volumes used in hydraulic fracturing operations
      • Figure 3.10 Volumes of frac and drilling water in the Barnett, Fayetteville, Haynesville and Marcellus shale
  • 3.5 Process water in the oil sands
    • 3.5.1 Process water requirements for surface mining operations
    • 3.5.2 Wastewater disposal from surface mining operations
      • Figure 3.11 Inorganic water chemistry of tailings water at Syncrude' s Mildred Lake Settling Basin
      • Figure 3.12 Organic chemistry of tailings water at Syncrude' s Mildred Lake Settling Basin
    • 3.5.3 Process water requirements for in-situ operations
      • Figure 3.13 Major oil sands water handling tasks and equipment

4. Produced water technologies

  • 4.1 Options for produced water management
    • Figure 4.1 Three-tiered produced water management system
    • 4.1.1 Tier 1: Minimisation
    • 4.1.2 CBM gas/water separation
  • 4.2 Oil/Water separation technologies
    • 4.2.1 Gravity separation system
    • 4.2.2 Hydrocyclones
    • 4.2.3 Heater treaters
    • 4.2.4 The flotation process
    • 4.2.5 Gas flotation units
      • Figure 4.2 Differences between IGF and DGF
    • 4.2.6 Compact flotation unit
    • 4.2.7 Macro porous polymer extraction (MPPE)
    • 4.2.8 Filtration systems using nutshells
  • 4.3 Membrane bioreactors for biological treatment
  • 4.4 Advanced water treatment technologies
    • 4.4.1 Introduction to osmosis
    • 4.4.2 Reverse osmosis
    • 4.4.3 Forward osmosis (FO)
    • 4.4.4 High efficiency reverse osmosis (HERO)
      • Figure 4.3 Differences between HERO and RO
    • 4.4.5 Optimized Pretreatment and Separation (OPUS"!)
    • 4.4.6 Comparison of HERO and OPUS"!
    • 4.4.7 Brine concentrators
    • 4.4.8 Crystallizers
    • 4.4.9 Vapour compression distillation (VCD)
    • 4.4.10 Multi effect distillation (MED)
    • 4.4.11 AltelaRain"! thermal technology
    • 4.4.12 Aqua-Pure thermal technology
  • 4.5 Oil sands in-situ recovery technologies
    • 4.5.1 Solvent use
    • 4.5.2 Toe-to-heel air injection (THAI)
    • 4.5.3 Electro-Thermal Dynamic Stripping Process (ET DSP)

5. Produced water management, treatment and reuse

  • 5.1 Options for produced water management
    • Figure 5.1 The three tier approach to produced water management
    • 5.1.1 Tier 2: Recycle and reuse
    • 5.1.2 Tier 3: Disposal
      • Figure 5.2 Percentages of produced water discharged to surface water bodies
      • Figure 5.3 Discharge options by oil and gas category
  • 5.2 Oil sands process water management technologies
    • 5.2.1 In-situ operations: Increasing recycling
      • Figure 5.4 Comparison of OTSG and evaporator in-situ technologies
    • 5.2.2 In-situ operations: Decreasing water usage
    • 5.2.3 In-situ operations: Selling water
    • 5.2.4 Mining operations: Increasing recycling
    • 5.2.5 Mining operations: Reducing water intensity
      • Figure 5.5 Suncor' s water intensity at its oil sands mining operations
    • 5.2.6 Mining operations: Selling water
    • 5.2.7 Desalination for the reuse of produced water and associated costs
    • 5.2.8 The viability of reusing produced water
    • 5.2.9 Produced water treatment costs
    • 5.2.10 Oilfield brine desalination costs
      • Figure 5.6 The theoretical minimum energy required for reverse osmosis at 25oC
      • Figure 5.7 Energy requirements and salinity ranges of desalination technologies
      • Figure 5.8 Illustrative costs and choices for desalinating produced water
    • 5.2.11 Costs of treating produced water from CBM
      • Figure 5.9 Summary of CBM produced water treatment/disposal costs
    • 5.2.12 Cost of treating produced water from shale bed frac' ing
    • 5.2.13 Off-site disposal costs
      • Figure 5.10 Off-site disposal fees for produced water in the U.S.
    • 5.2.14 Transportation costs to offsite disposal facilities
      • Figure 5.11 Disposal services and costs
  • 5.3 Case studies
    • 5.3.1 Nimr Reed Bed Project, Petroleum Development Oman
    • 5.3.2 San Ardo Water Reclamation Facility, Chevron Corporation
    • 5.3.3 Mukhaizna Water Treatment Facility, Occidental Petroleum
    • 5.3.4 Wellington Oil Field, Colorado
  • 5.4 Prospects for selling treated produced water

6. Our top markets

  • 6.1 The shale explosion
    • 6.1.1 The contribution of shale gas to U.S. dry gas production
      • Figure 6.1 U.S. dry gas production including imports, projected to 2035
    • 6.1.2 Breakdown by state and by shale play
      • Figure 6.2 New field discoveries of dry natural gas reserves by state, 2000-2009
      • Figure 6.3 Proven shale gas reserves by state
      • Figure 6.4 Shale gas production by state, 2007-2009
      • Figure 6.5 Shale gas production by play, 2008-2009
    • 6.1.3 The Barnett shale
      • Figure 6.6 Barnett shale: Gas production and well permits, 2004-2010
      • Figure 6.7 Barnett Shale: Top operators in 2010
    • 6.1.4 The Fayetteville Shale
      • Figure 6.8 Fayetteville Shale: Number of wells, 2004-2011
      • Figure 6.9 Fayetteville shale: Top operators, 2004-2010
      • Figure 6.10 Fayetteville shale: Decay of gas production over time by individual wells (averaged)
    • 6.1.5 The Haynesville/Bossier shale
      • Figure 6.11 Haynesville Shale: Number of wells, 2011
      • Figure 6.12 Haynesville shale: Top operators in Louisiana
    • 6.1.6 The Marcellus shale
      • Figure 6.13 Marcellus Shale: Number of wells, 2011
      • Figure 6.14 Marcellus Shale: New wells in Pennsylvania, 2007-2010
      • Figure 6.15 Marcellus Shale: Drilling permits issued in Pennsylvania, Jan 2010-Feb 2011
      • Figure 6.16 Marcellus Shale: Permitted well depth in Pennsylvania, Jan 2010-Feb 2011
      • Figure 6.17 Marcellus Shale: Top operators in Pennsylvania and West Virginia, 2010
    • 6.1.7 The Eagle Ford shale
      • Figure 6.18 Eagle Ford shale: Drilling permits issued, 2008-2010
    • 6.1.8 The Bakken shale
      • Figure 6.19 Bakken shale wells, 1986-2010
      • Figure 6.20 New Bakken shale wells by operator, 2005-2010
      • Figure 6.21 Total Bakken shale wells by operator, 2005-2010
    • 6.1.9 Hydraulic fracturing service providers
  • 6.2 The Canadian oil sands: Production is on the rise
    • 6.2.1 An increase in oil production...
      • Figure 6.22 Canadian crude oil production forecast, 2007-2020
    • 6.2.2 ... means an increase in water handling
      • Figure 6.23 Potential growth in oil sand operators' water handling
    • 6.2.3 Major operators
      • Figure 6.24 Integrated oil sand surface mining operations
      • Figure 6.25 Major thermal in-situ projects
  • 6.3 Coal bed methane: The time is ripe for beneficial reuse
    • 6.3.1 Introduction
    • 6.3.2 Coal bed methane productions
      • Figure 6.26 Coalbed methane production by state, 2005-2009
    • 6.3.3 Coal bed methane basins
      • Figure 6.27 Summary of the main CBM basins
    • 6.3.4 Beneficial use of CBM produced water
      • Figure 6.28 Beneficial uses of CBM produced water
      • Figure 6.29 Use of CBM produced water for livestock and wildlife watering
    • 6.3.5 CBM reuse opportunities in Colorado
    • 6.3.6 CBM reuse opportunities in Montana
    • 6.3.7 CBM reuse opportunities in Wyoming
    • 6.3.8 CBM reuse opportunities in New Mexico
  • 6.4 Desalination as an alternative to off-site disposal in conventional oil
    • 6.4.1 Produced water volumes
      • Figure 6.30 Oil, gas and produced water volumes, statewise and offshore, 2007
      • Figure 6.31 WOR in selected U.S. states
      • Figure 6.32 WGR in selected U.S. states
      • Figure 6.33 U.S. oil production, 1981-2077; projected to 2035
    • 6.4.2 Desalination challenges
    • 6.4.3 Market development
      • Figure 6.34 Desalination in the on-shore conventional oil sector
  • 6.5 Low salinity water: Maximize your investment in every well
    • 6.5.1 Introduction
    • 6.5.2 Low salinity water technology
    • 6.5.3 Characteristics of low salinity water technology
    • 6.5.4 Offshore opportunities

7. Produced water market analysis

  • 7.1 Market division/segmentation
    • Figure 7.1 The produced water market by expenditure category, 2010
    • Figure 7.2 The produced water market: Opex vs capex, 2010
    • Figure 7.3 The produced water treatment market by treatment category, 2010
    • Figure 7.4 The produced water treatment equipment market by resource type, 2010
  • 7.2 Key and emerging players
    • Figure 7.5 Key players for the primary and secondary global market
    • Figure 7.6 Key and emerging players for tertiary treatment and desalination
    • Figure 7.7 Key players for chemicals
    • Figure 7.8 Key players for monitoring
  • 7.3 Consolidation
    • Figure 7.9 Significant company acquisitions, mergers and joint ventures
  • 7.4 Navigating the supply chain
  • 7.5 Market share estimates
    • Figure 7.10 Estimated market share of primary and secondary treatment equipment in North America
    • Figure 7.11 Estimated market share of tertiary treatment equipment in North America
  • 7.6 Future market growth
    • 7.6.1 Future oil and gas production
      • Figure 7.12 U.S. crude oil production forecast, 2007-2025
      • Figure 7.13 U.S. gas production forecast, 2007-2025
      • Figure 7.14 Canadian crude oil production forecast, 2007-2020
      • Figure 7.15 Canadian gas production forecast, 2007-2020
      • Figure 7.16 North American oil production forecast, 2007-2025
      • Figure 7.17 North American gas production forecast, 2007-2025
    • 7.6.2 Produced water volumes
      • Figure 7.18 North American produced water volumes 2007-2025
      • Figure 7.19 North American produced water volumes, 2010-2020
  • 7.7 Forecasting produced water expenditure
    • Figure 7.20 Produced water management market forecast, 2007-2025: Operating costs versus capital costs
    • Figure 7.21 Produced water management market forecast, 2007-2025: Breakdown by activity
    • Figure 7.22 Produced water management market forecast, 2010-2020: Data table
    • Figure 7.23 The produced water treatment equipment market, 2007-2025: Conventional oil including EOR
    • Figure 7.24 The produced water treatment equipment market, 2007-2025: Conventional and tight gas
    • Figure 7.25 The produced water treatment equipment market, 2007-2025: Oil sands processing
    • Figure 7.26 The produced water treatment equipment market, 2007-2025: Shale gas
    • Figure 7.27 The produced water treatment equipment market, 2007-2025: Coal bed methane
    • Figure 7.28 The produced water treatment equipment market, 2007-2025: By resource type
    • Figure 7.29 The produced water treatment equipment market, 2007-2025: By treatment type
    • Figure 7.30 The produced water treatment equipment market, 2010-2020: Data table
    • Figure 7.31 Produced water treatment operating costs, 2007-2025: By treatment type
  • 7.8 Operating services
    • Figure 7.32 The produced water chemicals market, 2007-2025
    • Figure 7.33 The produced water outsourced treatment operations market, 2007-2025

8. Accessing the market

  • 8.1 The evolution of the produced water market
  • 8.2 Market access and entry overview
  • 8.3 The traditional approach to entering the shale gas produced water market
  • 8.4 The approach to entering the oil sands produced water market
  • 8.5 Success factors for new technology companies entering the market
  • 8.6 Market dominance: oilfield service companies vs water technology companies
  • 8.7 Maintaining a market presence
  • 8.8 Market entry challenges and barriers

9. Market opportunities

  • 9.1 Shale gas produced water market
    • 9.1.1 Challenges facing the shale gas produced water market
    • 9.1.2 Solutions to overcome market challenges
    • 9.1.3 Best positioned companies for the market
    • 9.1.4 The critical success factors for companies
    • 9.1.5 Major customers in the shale gas produced water market
    • 9.1.6 Services versus technologies
    • 9.1.7 Shale gas produced water market size
    • 9.1.8 Market size in five years
    • 9.1.9 Obstacles affecting the shale gas produced water market
    • 9.1.10 How market obstacles can be overcome
    • 9.1.11 The dependence of the market on gas price
  • 9.2 Market opportunities in the Canadian oil sands
    • 9.2.1 Executive summary
    • 9.2.2 Evolving water treatment demands
    • 9.2.3 What is driving that evolution?
    • 9.2.4 Are there any new regulatory drivers in the market?
    • 9.2.5 What will their impact be?
    • 9.2.6 What are the biggest water problems in the oil sands?
    • 9.2.7 What are the most promising ways of dealing with a shortage in the short term?
    • 9.2.8 What are the barriers to proceeding?
    • 9.2.9 What kind of water treatment technologies will be most in demand in the future?
    • 9.2.10 Which companies are currently doing well in this setting?
    • 9.2.11 How do you think this market will change in the future?
    • 9.2.12 How low can the price of oil fall before this market dries up?
    • 9.2.13 How much water is currently reused in the oil sands?
    • 9.2.14 How will that grow?
    • 9.2.15 How big is the marketplace?
      • Figure 9.1 The oil sands water treatment marketplace, capital and operating expenditure, 2011 and 2021
    • 9.2.16 How will the marketplace grow?
  • 9.3 Reuse options for produced water
    • 9.3.1 Barriers to offsite reuse of produced water
    • 9.3.2 Overcoming these challenges
    • 9.3.3 Best positioned companies
    • 9.3.4 Market size and market areas
  • 9.4 Custom water
    • 9.4.1 Areas of demand for ‘custom made water’
    • 9.4.2 Market sector activity and development
    • 9.4.3 The demand for membrane and thermal separation technologies and challenges
    • 9.4.4 Services versus technologies
    • 9.4.5 Market drivers, success and size
    • 9.4.6 The EOR potential of low salinity water and limiting factors

Interviewees

References

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