DOCSLIB.ORG

Artifi Cial Lift Techbook 2

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
Artifi Cial Lift Techbook 2 2 018 Artifi cial Lift Techbook A supplement to All the brands you know and love. Now part of Apergy. We’re the same iconic companies we’ve always been. So you get the same service you’ve always had. But now we’re part of an independent, publicly owned wellsite services organization. Apergy. Operating under four industry-leading divisions emerging from Dover Energy, in Apergy Artificial Lift, you benefit from a network with 440 years of expertise in total wellsite management. Visit Apergy.com – great brands. One great big name. Apergy-8x10.5 inches ad-01June18-aw.indd 1 01/06/2018 15:46 Hart Energy’s Techbook Series The 2018 Artificial Lift Techbook is the 16th in a series of techbooks in which Hart Energy will provide comprehensive coverage of effective and emerging technologies in the oil and gas industry. Each techbook includes a market overview, a sample of key technology providers, case studies of field applica- tions and exclusive analysis of industry trends relative to specific technologies. To learn more about E&P technology trends, visit EPmag.com. Artificial Lift The 2018 Techbook A supplement to E&P Table of Contents HART ENERGY 1616 S. Voss, Suite 1000 | Houston, Texas 77057 Tel: +1 (713) 260-6400 | Fax: +1 (713) 840-8585 OVERVIEW hartenergy.com Artificial Lift Market on the Move 2 Companies seek artificial lift technologies and innovations Group Managing Editor, Print Media JO ANN DAVY that can handle a wide array of operating environments. Executive Editor JENNIFER PRESLEY Chief Technical Director RICHARD MASON Associate Editor BRIAN WALZEL KEY PLAYERS Associate Managing Editor ARIANA BENAVIDEZ Maximizing Production with Artificial Lift and 4 Assistant Editor ALEXA WEST Automation These key players have mastered the art of recovering more production via artificial lift. Contributing Editors JOSE LEON ARAUJO STEPHEN FAUX GRAHAM MAKIN JENNIFER PALLANICH TECHNOLOGY The Future is Near YAHYA SARAWAQ 24 Artificial lift technology continues to mature on all fronts as BLAKE WRIGHT contractors target the sweet spots. LARA ZSOHAR Group Managing Editor, Digital News Group LEN VERMILLION TECHNOLOGY SHOWCASE Technologies to Optimize Well Performance 34 Operators depend on reliable and innovative products and Corporate Art Director ALEXA SANDERS services to maximize the well production life cycle. Marketing Art Director MELISSA RITCHIE Senior Graphic Designer MAX GUILLORY Production Manager SHARON COCHRAN CASE STUDIES Vice President, Marketing GREG SALERNO Improving ESP Installs by Removing the Rig For additional copies of this publication, Coiled tubing-deployed ESP system allows for faster and safer contact Customer Service +1 (713) 260-6442. installations in wells both onshore and off. 40 Senior Vice President , Media RUSSELL LAAS Publisher, Gas Lift in the Digital Oil Field Oil and Gas Investor KEVIN HOLMES Digital intelligent artificial lift system creates a paradigm shift Publisher, in gas-lift operations. 43 Midstream Business DARRIN WEST Optimizing Artificial Lift 24/7 surveillance service captures, interprets and recommends action to boost performance. 46 Vice President , Editorial Director PEGGY WILLIAMS Chief Financial Officer CHRIS ARNDT Chief Executive Officer RICHARD A. EICHLER On the cover: Beam pumps at work producing oil from southeastern New Mexico’s Delaware Hart Energy © 2018 Basin. (Photo by Jennifer Presley, Hart Energy) EPmag.com | July 2018 | 1 ARTIFICIAL LIFT: OVERVIEW Artificial Lift Market On the Move Companies seek artificial lift technologies and innovations that can handle a wide array of operating environments. By Jennifer Pallanich Contributing Editor s the oil and gas industry continues recovering mation Technology. “It seems there’s a trend back to from the most recent bust cycle, the artificial financial discipline and operating within cash flow.” Alift segment is finally beginning to climb out Stability in oil pricing is having another effect, of its slump. Because artificial lift equipment typi- he said. cally is not purchased until a well is completed—or “A lot of the operators are getting back to taking much later—the sector’s recovery has lagged behind care of their wells. There’s more maintenance and other oilfield services. repairs. Well servicing activity is starting to pick up According to Dimitar Kostadinov, a senior ana- slightly and is projected to pick up some more here lyst with McKinsey Energy Insights, the artificial lift in the balance of this year,” Mahoney said. market has been improving with the recent rise in When it comes to artificial lift in unconventional well completions. The firm expects the artificial lift plays, he noted there seems to be a move toward pro- sector to be strong in 2018 and to turn in even stron- viding lift earlier in a well’s life. ger results in 2019 due to completions of new wells. “It’s driving more activity on the gas-lift, electric Kostadinov does not, however, believe pricing will submersible pumps and, in some cases, the hydraulic recover to pre-2015 levels. lift area. We’re seeing more activity and good growth One reason is because beam pumping units and rates in those areas,” Mahoney said. “You have some gas-lift technologies have been largely commoditized of the shorter laterals from earlier unconventionals but also because international players have aggres- work in 2013 and 2014 starting to mature, and the sively entered the local market to put pressure on production rates have declined to a point where some prices, according to McKinsey. decisions on a change of technology is afoot, convert- Operators changed the way they bought artificial ing to the tried and true reciprocating rod lift arena.” lift equipment during the downturn. In the past they According to Kostadinov, the last few years have preordered units and even paid extra for access to shown some changes in the preferred technology used manufacturing capacity for beam pumping units in artificial lift, with operators installing more gas and electric submersible pumps (ESPs), according lift at the expense of ESPs and some higher capacity to Kostadinov. Now the operators are tending to beam pumping units. The cost of installing gas lift contract for the units much closer to the expected is lower than other technologies, associated gas pro- installation date. The shift minimizes inventory and duction is abundant and compressors can be rented improves cash flow. The company said if such an to spread the cost over time. McKinsey noted some approach continues, artificial lift procurement will Permian-focused independents have entirely shifted be more of a spot market than a bulk market. to gas lift for their newly completed wells. “It’s been an interesting journey since the down- The last year has shown a resurgence in ESP use, turn and the commodity price change,” said Paul boosted by rental offerings, according to the company. Mahoney, president of Apergy Production and Auto- Beam pumping units have been pushed back in the 2 | July 2018 | hartenergy.com ARTIFICIAL LIFT: OVERVIEW Beam pumps, like these located alongside the salt flats just outside of Carlsbad, N.M., on the road to Jal, are a popular form of artificial lift in many basins. (Photo by Jennifer Presley) pecking order for new wells in the Permian but remain Mahoney added. “There’s no silver bullet, but a com- popular in other basins. pany like ours is working on four or five major new things to support the industry.” Drive for innovation According to Kostadinov, oilfield services compa- Operators are favoring automation and remote nies have gradually raised the overall quality of their monitoring systems in an effort to improve effi- artificial lift offerings, incrementally improving gas ciency. Operators are clamoring for technologies handling and lifting liquids from deeper laterals. The that can widen the operating envelop for artificial overall resistance of pumps and related equipment lift, Mahoney said. also has improved. The modularization of artificial “There’s been a renewed emphasis on developing lift, especially ESPs, has resulted in less rig time and technology that helps the operator with the wider lower installation costs, with equipment coming in operating range in downhole conditions. That’s get- fewer parts and also preloaded with consumables ting more and more prominent,” he noted. like oil, he added. Conditions include declining production rates as One of the existing challenges in artificial lift is well as handling large amounts of gas, solids and sand. access to people and parts, which is crucial for sup- The biggest push is around automation and analyt- porting customers. Education also can be helpful, ics with the goal of monitoring wells, analyzing data Mahoney said. The company’s Artificial Lift Academy to extend equipment life, predicting failure patterns offers more than 50 courses to help train industry and fieldwide production management, he added. personnel on artificial lift technologies, engineering “We’re trying to marry our installation base, our tools and digital technologies. application knowledge and collaboration with cus- “Some operators know the guidebook or playbook tomers to bring digital automation capability to the they want to exercise for artificial lift and … a good market that drives outcomes and better decision-mak- percentage of customers don’t know what their play- ing for the operator,” Mahoney said. “We’re working book is and they’re looking to companies like ours to on new product development to extend the ranges be able to provide that guidebook for them [and] what and handle adverse downhole conditions.” makes sense over the life of the well,” Mahoney said. Apergy’s efforts target a combination of extending While the market for artificial lift equipment has existing technologies and developing completely new been a difficult one in the most recent downturn, industry technologies. Mahoney is optimistic about the sector’s future. “We have some things in the early ideation stage “Artificial lift will always be needed,” with preliminary engineering work going on,” Mahoney said.
Load more

Recommended publications
  • 1981-04-15 EA Plan of Development Production
    United States Department of the Interior Office of the Secretary Minerals Management Service 1340 West Sixth Street Los Angeles, California 90017 OCS ENVIRONMENTAL ASSESSMENT July 8, 1982 Operator Chevron U.S.A. Inc. Plan Type Development/Production Lease OCS-P 0296 Block 34 N., 37 W. Pl atfonn Edith Date Submitted April 15, 1981 Prepared by the Office of the Deputy Minerals Manager, Field Operations, Pacific OCS Region Related Environmental Documents U. S. DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Environmental Impact Report - Environmental Assessment, Shell OCS Beta Unit Development (prepared jointly with agencies of the State of California, 1978) 3 Volumes Environmental Assessment, Exploration, for Lease OCS-P 0296 BUREAU OF LAND MANAGEMENT Proposed 1975 OCS Oil and Gas General Lease Sale Offshore Southern California (OCS Sale No. 35), 5 Volumes Proposed 1979 OCS Oil and Gas Lease Sale Offshore Southern California (OCS Sale No. 48), 5 Volumes Proposed 1982 OCS Oil and Gas General Lease Sale Offshore Southern California (OCS Sale No. 68), 2 Volumes u.c. Santa Cruz - BLM, Study of Marine Mammals and Seabirds of the Southern California Bight ENVIRONMENTAL ASSESSMENT CHEVRON U.S.A. INC. OPERATOR PLAN OF DEVELOPMENT/PRODUCTION, PROPOSED PLATFORM EDITH, LEASE OCS-P 0296, BETA AREA, SAN PEDRO BAY, OFFSHORE SOUTHERN CALIFORNIA Table of Contents Page I. DESCRIPTION OF THE PROPOSED ACTION ••••••••••••••••••••• 1 II. DESCRIPTION OF AFFECTED ENVIRONMENT •••••••••••••••••••• 12 III. ENVIRONMENTAL CONSEQUENCES ••••••••••••••••••••••••••••• 29 IV. ALTERNATIVES TO THE PROPOSED ACTION •••••••••••••••••••• 46 v. UNAVOIDABLE ADVERSE ENVIRONMENTAL EFFECTS •••••••••••••• 48 VI. CONTROVERSIAL ISSUES ••••••••••••••••••••••••••••••••••• 48 VII. FINDING OF NO SIGNIFICANT IMPACT (FONS!) ••••••••••••••• 51 VIII. ENVIRONMENTAL ASSESSMENT DETERMINATION ••••••••••••••••• 55 IX.
    [Show full text]
  • View Annual Report
    ANNUAL 2017 REPORT Financial Highlights (Millions of dollars and shares, except per share data) 20171 20161 20151 Revenue Dividends to in billions Shareholders Revenue $ 20,620 $ 15,887 $ 23,633 in millions Operating Income (Loss) $ 1,362 $ (6,778) $ (165) Amounts Attributable to Company Shareholders: Loss from Continuing Operations $ (444) $ (5,761) $ (666) $614 $626 $620 $15.9 Net Loss $ (463) $ (5,763) $ (671) $20.6 $23.6 Diluted Income per Share Attributable to Company Shareholders: Loss from Continuing Operations $ (0.51) $ (6.69) $ (0.78) Net Loss $ (0.53) $ (6.69) $ (0.79) Cash Dividends per Share $ 0.72 $ 0.72 $ 0.72 Diluted Common Shares Outstanding 870 861 853 Working Capital2 $ 5,915 $ 7,654 $ 14,733 Capital Expenditures $ 1,373 $ 798 $ 2,184 Total Debt $ 10,942 $ 12,384 $ 15,355 17 16 15 17 16 15 Debt to Total Capitalization3 57% 57% 50% Depreciation, Depletion and Amortization $ 1,556 $ 1,503 $ 1,835 4 Total Capitalization $ 19,291 $ 21,832 $ 30,850 Capital Expenditures in billions 1 Reported results during these periods include impairments and other charges of $647 million for the year ended December 31, 2017, merger-related costs and termination fee of $4.1 billion and impairments and other charges of $3.4 billion for the year ended December 31, 2016, and impairments and other charges of $2.2 billion for the year ended December 31, 2015. 2 Working Capital is defined as total current assets less total current liabilities. $1.4 $0.8 $2.2 3 Debt to Total Capitalization is defined as total debt divided by the sum of total debt plus total shareholders’ equity.
    [Show full text]
  • JX Report for a Sustainable Future 2010 JX Report for a Sustainable Future 2010 the JX Group Was Formed in April 2010 in Quest of a Sustainable Future
    2010 Report for a Sustainable Future JX JX Holdings, Inc. JX Report for a Sustainable Future 2010 The JX Group was formed in April 2010 in quest of a sustainable future. Under our new mission statement, the JX Group aims to make major advances in the fields of energy, resources and materials. Guided by the slogan of “The Future of Energy, Resources and Materials,” the JX Group is determined to shape the future. JX Group Mission Statement JX Group Slogan JX Group Mission Statement JX Group will contribute to the development of a sustainable economy and society through innovation in the areas of energy, resources and materials. JX Group Values Our actions will respect the EARTH. Ethics Advanced ideas Relationship with society Trustworthy products/services Harmony with the environment About JX The name “JX” symbolizes the JX Group’s mission statement. The letter “J” represents our position as one of the world’s largest integrated energy, resources and materials business groups from Japan, while the letter “X” represents our willingness to pioneer new frontiers, our future growth and development potential and innovation. About the JX Corporate Brand Mark The JX corporate brand mark symbolizes the continuity of the global environment and the JX Group based on the JX Group’s mission statement. The design, in which the “JX” logo overlaps with a sphere, represents the JX Group’s commitment to a green earth—i.e., our contribution to the development of a sustainable economy and society, through innovation in the areas of energy, resources and materials. * The JX corporate brand mark is common to JX Holdings, Inc., JX Nippon Oil & Energy Corporation, JX Nippon Oil & Gas Exploration Corporation and JX Nippon Mining & Metals Corporation.
    [Show full text]
  • Appendix 3: Projection Factors for Point and Area Sources (Adopted
    APPENDIX 3 PROJECTION FACTORS FOR POINT AND AREA SOURCES Eastern Research Group, Inc. PROJECTION FACTORS FOR POINT AND AREA SOURCES Final Prepared for: Texas Commission on Environmental Quality Air Quality Division MC-164, P.O. Box 13087 Austin, TX 78711-3087 August 16, 2010 ERG No. 0227.03.027.006 TCEQ Contract No. 582-07-84003 Work Order No. 582-07-84003-FY10-27 PROJECTION FACTORS FOR POINT AND AREA SOURCES Final Prepared for: Texas Commission on Environmental Quality Air Quality Division MC-164, P.O. Box 13087 Austin, TX 78711-3087 Attn: Mr. Greg Lauderdale Prepared by: Eastern Research Group, Inc. 10860 Gold Center Drive, Suite 275 Rancho Cordova, CA 95670 August 16, 2010 TABLE OF CONTENTS Section Page ES.0 EXECUTIVE SUMMARY .....................................................................................................1 1.0 INTRODUCTION ...................................................................................................................1 2.0 DATA COLLECTION............................................................................................................2 2.1 Economy.com Economic Data and Projections............................................................ 3 2.2 Texas Industrial Production Index................................................................................ 3 2.3 Annual Energy Outlook ................................................................................................ 4 2.4 EGAS Model................................................................................................................
    [Show full text]
  • Advancing Artificial Lift
    Advancing artificial lift Sven Olson, Leistritz Advanced Technologies Corp., USA, explains how artificial lift and gathering systems can be optimised through the use of multiphase pumps. he application of artificial lift in oil and gas exposure for well service and interventions. Today’s trend production continues to grow as operators strive to for optimising production and total recovery is to further Tmaximise recovery and the use of existing facilities extend the outreach from a single pad, which results in the and processes, as well as accessing tight formations and low application of more deviated and horizontal drilling. This permeability shale assets. Drill centres and pad production leads to complex well architecture with long horizontal are becoming very common as producers work to reduce sections, which makes lifting with conventional downhole facility footprints and minimise the environmental impact. products challenging, and in turn creates a whole new set However, along with the benefits of growing numbers of of problems facing the operator. Depending on the specific artificial lift installations also comes added complexity in production scenario of a formation, different artificial lift producing an asset, which leads to increased operator cost technologies are used. Figure 1 provides a depiction of a typical split of lifting alternatives for an operator producing 8000 onshore wells. Over 5 million wells are on artificial lift worldwide; in North America alone, it is estimated that 85% of all wells use artificial lift. In onshore applications the SRPs (sucker rod pumps) dominate, however ESPs (electrical submersible pumps) or PCPs (progressing cavity pumps) are increasingly gaining ground. Other commonly used technologies include velocity strings, plungers, jet pumps and gas lift systems.
    [Show full text]
  • Options for Removing Accumulated Fluid and Improving Flow in Gas Wells
    Lessons Learned from Natural Gas STAR Partners Options for Removing Accumulated Fluid and Improving Flow in Gas Wells Executive Summary At different stages in the life of a gas well, various alternatives to repeated well venting can be deployed to When first completed, many natural gas wells have move accumulated liquids to the surface. These options sufficient reservoir pressure to flow formation fluids include: (water and liquid hydrocarbon) to the surface along with the produced gas. As gas production continues, the Foaming agents or surfactants reservoir pressure declines, and as pressure declines, the velocity of the fluid in the well tubing decreases. Velocity tubing Eventually, the gas velocity up the production tubing is no longer sufficient to lift liquid droplets to the surface. Plunger lift, operated manually or with ‘smart’ well Liquids accumulate in the tubing, creating additional automation pressure drop, slowing gas velocity, and raising pressure in the reservoir surrounding the well perforations and Downhole pumps, which include reciprocating (beam) inside the casing. As the bottom well pressure approaches pumps and rotating (progressive cavity) pumps. reservoir shut-in pressure, gas flow stops and all liquids accumulate at the bottom of the tubing. A common Natural Gas STAR Partners report significant methane approach to temporarily restore flow is to vent the well to emission reductions and economic benefits from the atmosphere (well “blowdown”), which produces implementing one or more lift options to remove substantial methane emissions. The U.S. Inventory of accumulated liquids in gas wells. Not only are vented Greenhouse Gas Emissions and Sinks 1990—2008 methane emissions reduced or eliminated, but these lift estimates 9.6 billion cubic feet (Bcf) of annual methane techniques can provide the additional benefit of increased emissions from venting of low pressure gas wells.
    [Show full text]
  • UKCS Technology Insights
    UKCS Technology Insights April 2019 Unless identified elsewhere, all data is from the OGA UKSS 2017 and 2018 Cover photos: High frequency FWI image – courtesy of DownUnder Geosolutions using Capreolus 3D data from TGS Ocean bottom nodes – courtesy of Magseis Fairfield Riserless mud recovery – courtesy of Enhanced Drilling Carbon composite pipe – courtesy of Magma Global Contents Foreword 5 1. Seismic and exploration 22 Executive summary 6 2. Well drilling and completions 28 Operators’ technology plans 8 3. Subsea systems 34 Existing technologies for MER UK 12 4. Installations and topsides 40 Emerging technologies – MER UK priorities 14 5. Reservoir and well management 46 OGA’s technology stewardship 16 6. Facilities management 52 The Oil & Gas Technology Centre (OGTC) 18 7. Well plugging and abandonment 58 Technology plan feedback 21 8. Facilities decommissioning 64 Conclusions 70 Appendix - Technology spend 72 Image courtesy of Airbourne Oil & Gas Foreword I am pleased to see constant progress in the way our industry is OGTC, MER UK Taskforces and industry sponsors. A small maturing and deploying new technologies for the UK Continental technical team will be established to measure progress on all key Shelf (UKCS). This important effort is being supported by the objectives. Ultimately, these objectives will be followed up and coordinated work of the Oil and Gas Authority (OGA), the monitored through the OGA stewardship to further encourage Technology Leadership Board (TLB) and the Oil & Gas Technology uptake and share best practice. Centre (OGTC). There are huge prizes in reserves growth, production value and, This year’s Technology Insights summarises the rich content of most importantly, safe asset operation and life extension from the UKCS operators’ technology plans, submitted through the OGA use of current and new technologies.
    [Show full text]
  • Trends in U.S. Oil and Natural Gas Upstream Costs
    Trends in U.S. Oil and Natural Gas Upstream Costs March 2016 Independent Statistics & Analysis U.S. Department of Energy www.eia.gov Washington, DC 20585 This report was prepared by the U.S. Energy Information Administration (EIA), the statistical and analytical agency within the U.S. Department of Energy. By law, EIA’s data, analyses, and forecasts are independent of approval by any other officer or employee of the United States Government. The views in this report therefore should not be construed as representing those of the Department of Energy or other federal agencies. U.S. Energy Information Administration | Trends in U.S. Oil and Natural Gas Upstream Costs i March 2016 Contents Summary .................................................................................................................................................. 1 Onshore costs .......................................................................................................................................... 2 Offshore costs .......................................................................................................................................... 5 Approach .................................................................................................................................................. 6 Appendix ‐ IHS Oil and Gas Upstream Cost Study (Commission by EIA) ................................................. 7 I. Introduction……………..………………….……………………….…………………..……………………….. IHS‐3 II. Summary of Results and Conclusions – Onshore Basins/Plays…..………………..…….…
    [Show full text]
  • Study of Development Alternatives for Remote Offshore, Low Energy Reservoirs: the Wisting Field Case
    Study of development alternatives for remote offshore, low energy reservoirs: the Wisting field case Elshad Yadigarov Petroleum Engineering Submission date: July 2017 Supervisor: Milan Stanko, IGP Norwegian University of Science and Technology Department of Geoscience and Petroleum Abstract This work summarizes a series of analysis conducted to determine an optimized field development plan for Wisting oil field. The field presents several unique challenges, such as low reservoir pressure, very shallow reservoir depth and remoteness from the available infrastructure. The study used a homogeneous reservoir simulation model built during the Specialization Project. Some of the crucial data, such as porosity, permeability and horizontal-to-vertical permeability ratio had a huge uncertainty involved in it. In order to account for this, 27 reservoir models with a combination of those uncertain properties were constructed and integrated with the 3 production network models. As a result, 81 integrated models were run and the oil production data was then used to evaluate the NPV (Net Present Value) of each of the considered cases. 3 production network models have been used for the analysis – wells with no artificial lift, wells with gas lift and subsea multiphase boosting. Gas lift rate optimization study was conducted to maximize the production and the economics of this development option. Multiphase booster pump power requirements, which would meet the field operational conditions were also determined. NPV was set as an objective to decide on the most preferable development alternative. The capital expenditures for each of the development options were estimated with a commercial software, which was available for a limited period.
    [Show full text]
  • New Era of Oil Well Drilling and Completions.Indd
    Rod Pumping White Paper D352548X012 June 2020 New Era of Oil Well Drilling and Completions — Does It Require An Innovation In Rod Pumping? Abstract A new era of oil well drilling and completions is changing the face of rod pumping forever. Horizontal drilling with multistage hydraulic fracturing often results in very challenging production conditions. Pump placement below the kick-off (i.e., in non-vertical dogleg section), frequent gas slugs, large volumes of fl owback frac sand, signifi cant fl uctuations in fl uid fl ow rates, and steep decline curves are examples of the common challenges affecting the production of horizontal wells. Even the most sophisticated conventional pumpjack with an AC motor and variable frequency drive/variable speed drive (VFD/VSD) does not have the precise rod string control required to help mitigate and resolve many of these complex rod pumping issues that are frequently associated with horizontal multistage, hydraulically fractured wells. Linear pumping units, and more specifi cally linear hydraulic pumpjacks, have fundamental differences in geometry and control capabilities. Coupled with the fact that both natural gas and AC drive units support the same functionality, linear hydraulic pumpjacks provide the sophisticated rod string control required by today’s demanding wells. This paper will compare and contrast the different rod pumping methods and their abilities to address these production challenges. The paper will also discuss the additional benefi ts of combining the unique capabilities of a linear hydraulic pumpjack with sophisticated optimization control and remote access. The combination of these three key features provides an unprecedented solution that has the potential to become the next-generation rod pumping technology for cost effectively producing today’s challenging wells.
    [Show full text]
  • Installing Plunger Lift Systems in Gas Wells (Pdf)
    Lessons Learned from Natural Gas STAR Partners Installing Plunger Lift Systems In Gas Wells Executive Summary Technology Background In mature gas wells, the accumulation of fluids in the well Liquid loading of the wellbore is often a serious problem in can impede and sometimes halt gas production. Gas flow aging production wells. Operators commonly use beam lift is maintained by removing accumulated fluids through the pumps or remedial techniques, such as venting or “blowing use of a beam pump or remedial treatments, such as down” the well to atmospheric pressure, to remove liquid swabbing, soaping, or venting the well to atmospheric buildup and restore well productivity. These techniques, pressure (referred to as “blowing down” the well). Fluid however, result in gas losses. In the case of blowing down removal operations, particularly well blowdowns, may a well, the process must be repeated over time as fluids result in substantial methane emissions to the reaccumulate, resulting in additional methane emissions. atmosphere. Plunger lift systems are a cost-effective alternative to both Installing a plunger lift system is a cost-effective beam lifts and well blowdowns and can significantly alternative for removing liquids. Plunger lift systems have reduce gas losses, eliminate or reduce the frequency of the additional benefit of increasing production, as well as future well treatments, and improve well productivity. A significantly reducing methane emissions associated with plunger lift system is a form of intermittent gas lift that blowdown operations. A plunger lift uses gas pressure uses gas pressure buildup in the casing-tubing annulus to buildup in a well to lift a column of accumulated fluid out push a steel plunger, and the column of fluid ahead of it, of the well.
    [Show full text]
  • Artificial Lift for High-Volume Production
    Artificial Lift for High-Volume Production Rod pumps bring oil to surface in many fields, but for better flow rates more than 100,000 wells use subsurface electric pumps or inject external gas to lighten the fluid column. Specialized approaches are needed to optimize existing gas-lift or submersible systems and to design new installations for more complex applications. Roy Fleshman Less than a fourth of producing oil wells flow nat- but there is overlap between systems depending Bartlesville, Oklahoma, USA urally. When a reservoir lacks sufficient energy on subsurface conditions, fluid types, required for oil, gas and water to flow from wells at rates, well inclination angles, depths, comple- Harryson desired rates, supplemental production methods tion configurations, lift-system hardware and Obren Lekic can help. Gas and water injection for pressure surface facilities. Houston, Texas, USA support or secondary recovery maintain well pro- Lift optimization to get the most fluid from a ductivity, but artificial lift is needed when reser- well or field at the lowest cost offers opportuni- voir drives do not sustain acceptable rates or ties for substantial production gains in new wells cause fluids to flow at all in some cases. Lift pro- or mature fields. When selecting and designing cesses transfer energy downhole or decrease lift systems, engineers must consider reservoir fluid density in wellbores to reduce the hydro- and well parameters, but field development static load on formations, so that available reser- strategies should be factored in as well. voir energy causes inflow, and commercial Artificial-lift selection is specialized and often For help in preparation of this article, thanks to Rick Bailey hydrocarbon volumes can be boosted or displaced tedious, but guidelines provide the relative appli- and Duane Russell, Reda, Bartlesville, Oklahoma, USA; to surface.
    [Show full text]