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Downhole temperatures were as\nhigh as 400ºF (204°C), and densities as high as 17.5 lb/gal (2.1 SG) were required.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H012511.pdf","docCreatedDate":"2017-04-06T23:30:00.000-05:00","modifiedDate":"2017-04-06T23:30:00.000-05:00","publishDate":"2018-10-02T11:07:07.707-05:00","docdate":"2017-04-06T23:30:00.000-05:00","docrefNum":"H012511","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:High_Pressure:High_Pressure_(10K),Reservoir_Challenges:High_Temperature:High_Temperature_(300F),Environmental_Challenges:Deepwater-Environmental_Challenges,Reducing_Costs,Environmental_Challenges:Corrosion,Fluids_Challenges:Mud_Weight_Management,Environmental_Challenges:Pressure,Fluids_Challenges:Rheology_Control,Reservoir_Challenges:Improve_Reservoir_Productivity,|locations:Asia:Southern_Asia:India_Southern_Asia,Global,|prodgroups:Fluids_Solids_Control:Specialty_Systems,Fluids_Solids_Control:Reservoir_Drilling_Fluids,Fluids_Solids_Control:Reservoir_Fluids_Solutions,Fluids_Solids_Control:High_Impact_Technology_Services,"},{"title":"Operator Saves USD 92,000 while Drilling 2,500-m Shale Lateral with BARO-LUBE GOLD SEAL™ Lubricant","description":"The Baroid team recommended adding BARO-LUBE GOLD SEAL™ lubricant, a blend of surfactants and lubricants that can provide optimal metal-to-metal and metal-to-formation lubricity in oil- and synthetic-based systems.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/BARO-LUBE-GOLD-SEAL-Torque-Drag-Canada.pdf","docCreatedDate":"2015-03-18T23:30:00.000-05:00","modifiedDate":"2015-03-18T23:30:00.000-05:00","docdate":"2015-03-18T23:30:00.000-05:00","docrefNum":"H011634","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|brandgroups:Baroid,|locations:North_America:Canada,|prodgroups:Fluids_Solids_Control:Drilling_Fluid_Additives:Lubricants-Baroid,"},{"title":"Innovative Sag-Resistant Fluid Provides Cost-Effective Drilling Solution for High-Angle Wellbore","description":"Months of development and collaboration with the GOM operator yielded an enhanced fluid system that could meet each of the challenges presented by this extremely difficult wellbore.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H09055.pdf","docCreatedDate":"2012-08-01T23:30:00.000-05:00","modifiedDate":"2017-12-04T22:30:00.000-06:00","publishDate":"2018-10-02T11:05:43.903-05:00","docdate":"2012-08-01T23:30:00.000-05:00","docrefNum":"H09055","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Drilling_Challenges:Precise_Well_Placement,Deepwater,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|brandgroups:Baroid,|locations:Oceans_Gulfs_International_Waters:Gulf_of_Mexico,|prodgroups:Fluids_Solids_Control:Drilling_Fluids:Non-Aqueous_Drilling_Fluid_Systems,"},{"title":"SHALEDRIL® F Water-Based Fluid Proves Successful on Troublesome Fayetteville Shale","description":"The Marrowian shale that\nlies above the Fayetteville Shale in Arkansas is highly reactive\nand prone to fracturing and delamination. 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Failure to address any of these aspects can\nquickly consume additional fluids, logistics, and rig resources. When planning cleanup and\ndisplacement operations, the designer should anticipate issues such as cleaning efficiency, and\nshould address equipment limitations and mitigate potential problems such as surface volumes.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/BaraKlean648CFG-UK.pdf","docCreatedDate":"2016-12-14T22:30:00.000-06:00","modifiedDate":"2016-12-14T22:30:00.000-06:00","publishDate":"2018-10-02T11:07:02.587-05:00","docdate":"2016-12-14T22:30:00.000-06:00","docrefNum":"H012409","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|brandgroups:Baroid,|locations:Europe:Western_Europe:United_Kingdom_Western_Europe,Oceans_Gulfs_International_Waters:North_Sea,|prodgroups:Real_Time_Services,Fluids_Solids_Control:Displacement_Systems,"},{"title":"US Texas: STOPPIT® LCM enables recovery from total losses","description":"After landing the curve at 90° in an 8 ¾-inch Granite Wash well, the operator experienced complete lost returns. 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To avoid damaging the reservoir, the proposed treatment had to be applied very precisely.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/STEELSEAL-25-Wellbore-Stability-Colombia.pdf","docCreatedDate":"2015-01-30T22:30:00.000-06:00","modifiedDate":"2015-01-30T22:30:00.000-06:00","publishDate":"2018-10-02T11:05:49.688-05:00","docdate":"2015-01-30T22:30:00.000-06:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Control_Challenges:Lost_Circulation,|brandgroups:Baroid,|locations:Global,South_America:Colombia_Northern_South_America,|prodgroups:Fluids_Solids_Control:Drilling_Fluid_Additives:Lost_Cirulation_Materials-Baroid:Prevention_LCM,"},{"title":"Saudi Arabia: Inhibitive HYDRO-GUARD® System and Engineered Lost Circulation Blend Save 5 Days in Complex Wellbore","description":"Multiple severe loss zones were encountered on offset wells, ranging in depth from 5,100 ft to near total depth at approximately 9,500 ft total vertical depth (TVD). 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Coil tubing was then used to cleanout the interior of the drill string to run logs. However, the coil tubing unit was not able to get below 11,800 feet because of high friction in the 47 degree wellbore","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H09817.pdf","docCreatedDate":"2012-09-01T23:30:00.000-05:00","modifiedDate":"2018-01-12T22:30:00.000-06:00","docdate":"2012-09-01T23:30:00.000-05:00","docrefNum":"H09817","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Drilling_Challenges:Stuck_Pipe,|brandgroups:Baroid,|locations:Global,Oceans_Gulfs_International_Waters:Gulf_of_Mexico,|prodgroups:Fluids_Solids_Control:Drilling_Fluid_Additives:Lubricants-Baroid,"},{"title":"N-FLOW™ 325 Breaker System Frees Differentially Stuck Pipe in Depleted Sand, Saving USD 1.1M","description":"Successful breaker treatment saves operator several days of rig time","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/N-FLOW325BreakerOman.pdf","docCreatedDate":"2017-02-17T22:30:00.000-06:00","modifiedDate":"2017-09-19T23:30:00.000-05:00","docdate":"2017-02-17T22:30:00.000-06:00","docrefNum":"H012465","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Baroid,|locations:Middle_East:Oman_Middle_East,|prodgroups:Fluids_Solids_Control:Breaker_Systems,"},{"title":"Customized Fluid System Cuts Intermediate Casing Costs in Mississippi Lime Field","description":"In the Mississippi Lime field, the curve section of the wells entail drilling through a reactive shale where swelling and caving can cause hole stability problems. in previous wells, the 7\" casing has always been set in the top of the lime through the curve to provide sufficient stability for running a 4 ½-inch production liner. In this case, the operator requested a solution that would enable the Mississippi Lime to be drilled without setting the 7-inch intermediate casing.\n","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H010285.pdf","docCreatedDate":"2013-06-01T23:30:00.000-05:00","modifiedDate":"2017-07-10T23:30:00.000-05:00","docdate":"2013-06-01T23:30:00.000-05:00","docrefNum":"H010285","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Control_Challenges:Lost_Circulation,Fluids_Challenges:Fluid_Loss,Well_Control_Challenges:Ensure_Well_Integrity,|brandgroups:Baroid,|locations:North_America,|prodgroups:Fluids_Solids_Control:Drilling_Fluids,Fluids_Solids_Control:Drilling_Fluid_Additives:Borehole_Shale_Stabilizers-Baroid,"},{"title":"UK North Sea: BaraKlean®-648 Casing Cleaner Provides Client with Optimized Displacement, Superior Environmental Performance","description":"When a client needed an optimal casing cleanout that would minimize the volume of waste\nand be environmentally safe, Halliburton Baroid provided its BaraKlean®-648 casing cleaner\nand Completion Fluids Graphics (CFG™) displacement modeling software, thus saving the\nclient hours on the displacement and thousands of dollars in cleanout costs.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/BaraKlean648NorthSea.pdf","docCreatedDate":"2016-10-11T23:30:00.000-05:00","modifiedDate":"2016-10-11T23:30:00.000-05:00","docdate":"2016-10-11T23:30:00.000-05:00","docrefNum":"H012300","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|brandgroups:Baroid,|locations:Europe:Western_Europe:United_Kingdom_Western_Europe,Oceans_Gulfs_International_Waters:North_Sea,|prodgroups:Fluids_Solids_Control:Displacement_Systems,"},{"title":"Perfect displacement achieved despite restricted pump rate","description":"Displacement optimized with BaraKlean-648 casing cleaner delivers successful wellbore cleanout with restricted pump rate","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/CFS-648Displacement.pdf","docCreatedDate":"2016-01-13T22:30:00.000-06:00","modifiedDate":"2016-04-14T23:30:00.000-05:00","docdate":"2016-01-13T22:30:00.000-06:00","docrefNum":"H012054","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Baroid,|locations:Europe:Western_Europe:United_Kingdom_Western_Europe,Global,|prodgroups:Fluids_Solids_Control:Displacement_Systems,"},{"title":"INNOVERT® Solution Enables Operator to Complete Long Lateral Section in Combo Well","description":"During well planning the customer decided to extend the\nwell\u2019s horizontal reservoir section from 17,751 ft (5,411\nmeters) to 27,751 ft (8,459 meters), with a lateral section\nof 18,674 ft (5,692 meters). This operation was the first\ntime the customer had combined two reservoir intervals,\nand it involved running and installing the longest liner\nsection in the UAE at the time: 18,824 ft (5,738 meters)\nof a 6-5/8-inch slotted liner.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H012513-RDFNAFUAE.pdf","docCreatedDate":"2017-04-05T23:30:00.000-05:00","modifiedDate":"2017-04-05T23:30:00.000-05:00","docdate":"2017-04-05T23:30:00.000-05:00","docrefNum":"H012513","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges:Lubricity,Reservoir_Challenges:Mature_Fields,Drilling_Challenges:Extended_Reach_Drilling_(ERD),|locations:Global,Middle_East:United_Arab_Emirates_Middle_East,|prodgroups:Fluids_Solids_Control:Drilling_Fluids:Non-Aqueous_Drilling_Fluid_Systems,Fluids_Solids_Control:Breaker_Systems,"},{"title":"Production quadruples after N-FLOW™ 325 treatment","description":"Delayed-reaction N-FLOW™ 325 breaker system helps increase\nproduction from 1,000 bbl/day to 4,000 bbl/day","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/N-FLOW-Production.pdf","docCreatedDate":"2015-11-24T22:30:00.000-06:00","modifiedDate":"2015-11-24T22:30:00.000-06:00","publishDate":"2018-10-02T11:06:18.536-05:00","docdate":"2015-11-24T22:30:00.000-06:00","docrefNum":"H012019","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Middle_East:Qatar_Middle_East,Global,|prodgroups:Fluids_Solids_Control:Breaker_Systems,"},{"title":"Applied Fluids Optimization Monitoring Prevents Problems Before They Occur","description":"Halliburton proposed monitoring the well with Halliburton\u2019s Applied Fluids Optimization (AFO) service.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H08476.pdf","docCreatedDate":"2012-12-01T22:30:00.000-06:00","modifiedDate":"2017-09-25T23:30:00.000-05:00","publishDate":"2018-10-02T11:05:15.663-05:00","docdate":"2012-12-01T22:30:00.000-06:00","docrefNum":"H08476","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges:Hole_Cleaning_Cuttings_Removal,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|brandgroups:Baroid,|locations:Asia:Southwestern_Asia:Azerbaijan_Southwestern_Asia,|prodgroups:Fluids_Solids_Control:Fluids_Engineering,Optimization_Services:Fluids_Optimization,Real_Time_Services:Real-Time_&_Automation_Services,"},{"title":"N-FLOW™ 325 treatment boosts production from 100 bpd to 600 bpd","description":"Delayed-reaction N-FLOW™ 325 breaker system helps increase production\nfrom 100 bbl/day to 600 bbl/day, saving US$500,000 in rig time","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/N-FLOW-NPT.pdf","docCreatedDate":"2015-11-24T22:30:00.000-06:00","modifiedDate":"2015-11-24T22:30:00.000-06:00","publishDate":"2018-10-02T11:06:17.330-05:00","docdate":"2015-11-24T22:30:00.000-06:00","docrefNum":"H012021","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Global,Middle_East:Qatar_Middle_East,|prodgroups:Fluids_Solids_Control:Breaker_Systems,"},{"title":"Russia: BOREMAX® fresh-Water System reduces costs and enables drilling of interval in one-third of expected time","description":"An operator working in Russia\u2019s Kharyaga Field wished to improve penetration rate and reduce non productive time (NPT), caused by overloading of the solids control equipment and flowline plugging.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H09302.pdf","docCreatedDate":"2012-07-01T23:30:00.000-05:00","modifiedDate":"2012-07-11T23:30:00.000-05:00","docdate":"2012-07-01T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges:Waste_Minimization:Water_Based-Waste_Minimization,Fluids_Challenges:Hole_Cleaning_Cuttings_Removal,|brandgroups:Baroid,|locations:Asia:Northern_Asia:Russia_Northern_Asia,|prodgroups:Fluids_Solids_Control:Drilling_Fluids:Water_Base_Drilling_Fluid_Systems,Fluids_Solids_Control:Inhibitive_Water_Based_Systems,"},{"title":"Engineered HYDRO-PLUG® Pill Dramatically Cuts Loss Rate in Fractured Limestone","description":"Upon spotting the pill, drilling resumed from 1,858 meters (6,096 feet) to 2,060 meters (6,758\nfeet), but the average loss rate was 180 bbl/hr. Bapetco was unable to continue drilling to the\nplanned interval total depth (TD).","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/HYDROPLUG-FracturedLimestone.pdf","docCreatedDate":"2017-09-26T23:30:00.000-05:00","modifiedDate":"2017-09-26T23:30:00.000-05:00","publishDate":"2018-10-02T11:07:16.564-05:00","docdate":"2017-09-26T23:30:00.000-05:00","docrefNum":"H012665","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges:Fluid_Loss,|brandgroups:Baroid,|locations:Africa:Northern_Africa:Egypt_Northern_Africa,|prodgroups:Fluids_Solids_Control:Drilling_Fluid_Additives:Lost_Cirulation_Materials-Baroid,Fluids_Solids_Control:Drilling_Fluid_Additives:Lost_Cirulation_Materials-Baroid:Remediation_LCM,"},{"title":"Inhibitive Seawater-Based Fluid Saves US$130k on Offshore Well","description":"36 hours saved in rig time","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/EZMud-CLAYSEALPLUS.pdf","docCreatedDate":"2016-05-16T23:30:00.000-05:00","modifiedDate":"2016-05-16T23:30:00.000-05:00","docdate":"2016-05-16T23:30:00.000-05:00","docrefNum":"H012158","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|brandgroups:Baroid,|locations:North_America:Mexico,Global,|prodgroups:Fluids_Solids_Control:Drilling_Fluid_Additives:Borehole_Shale_Stabilizers-Baroid,"},{"title":"BaraGel™ W-602 Cross-Linked Gel System Delivers Deepwater","description":"After pumping an 8-bbl pill, losses stopped completely, saving operator over $400,000","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/CFS-602-LostCirculation.pdf","docCreatedDate":"2016-10-31T23:30:00.000-05:00","modifiedDate":"2016-10-31T23:30:00.000-05:00","publishDate":"2018-10-02T11:06:12.414-05:00","docdate":"2016-10-31T23:30:00.000-05:00","docrefNum":"H011749","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|brandgroups:Baroid,|locations:Global,Oceans_Gulfs_International_Waters:Gulf_of_Mexico,|prodgroups:Fluids_Solids_Control:Completion_Fluids_and_Filtration,Fluids_Solids_Control:Drilling_Fluid_Additives:Filtrate_Control_Agents-Baroid,"},{"title":"US Colorado: Use of SHALEDRIL® Water-Based Drilling Fluid Successfully Mitigates Intermediate Casing Run, Saving Operator Approximately $250,000","description":"In the DJ Basin of Weld County, Colorado, Baroid recommended SHALEDRIL®, its inhibitive water-based system specifically formulated to help combat swelling and sloughing of shale while drilling. The customized fluid system enabled the operator to successfully drill to TD without the time and expense of running 7-inch intermediate casing, saving approximately $250,000.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H010121.pdf","docCreatedDate":"2013-04-01T23:30:00.000-05:00","modifiedDate":"2013-05-31T23:30:00.000-05:00","docdate":"2013-04-01T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Improve_Wellbore_Integrity,|brandgroups:Baroid,|locations:North_America:United_States:Colorado,Global,North_America,|prodgroups:Fluids_Solids_Control:Drilling_Fluids,Fluids_Solids_Control:Drilling_Fluids:Water_Base_Drilling_Fluid_Systems,Fluids_Solids_Control:Drilling_Fluids_Solutions,"},{"title":"Qatar: N-FLOW™ 325 Filter Cake Breaker Applied in Long Reservoir Helps Increase Production 75%","description":"The operator wanted to stimulate the entire 3,741 m length of the reservoir by placing N-FLOW™ 325 filter cake breaker 325 inside the 8-1/2-in. open hole from 6,041 m to 4,923 m and inside the 6-5/8-in. perforated liner back to 2,300 m. Based on the Baroid global database, this would be the largest N-FLOW application performed to date. The calculated required volume was 159 m3 (1,000 bbl), including 10% excess, to stimulate 3,741 m of hole.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/N-FLOW-Delay-Time-Qatar.pdf","docCreatedDate":"2015-01-01T22:30:00.000-06:00","modifiedDate":"2015-02-02T22:30:00.000-06:00","publishDate":"2018-10-02T11:05:49.688-05:00","docdate":"2015-01-01T22:30:00.000-06:00","docrefNum":"H011600","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges:Filter_Cake_Removal,|brandgroups:Baroid,|locations:Global,Middle_East:Qatar_Middle_East,|prodgroups:Fluids_Solids_Control:Wallcake_Breaker,Fluids_Solids_Control:Reservoir_Fluids_Solutions,Fluids_Solids_Control:Reservoir_Drilling_Fluids,Fluids_Solids_Control:Breaker_Systems,"},{"title":"High-Performance Fluid System Enables Low-Pressure Circulation During Challenging Scab-Liner Run","description":"Major operator recently attempted to run and cement a 12,000-ft scab liner in a well located in the Gulf of Mexico (GOM).","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H010752.pdf","docCreatedDate":"2013-08-01T23:30:00.000-05:00","modifiedDate":"2017-09-25T23:30:00.000-05:00","publishDate":"2018-10-02T11:05:32.993-05:00","docdate":"2013-08-01T23:30:00.000-05:00","docrefNum":"H010752","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|brandgroups:Baroid,|locations:North_America:United_States:Louisiana,Oceans_Gulfs_International_Waters:Gulf_of_Mexico,Global,|prodgroups:Fluids_Solids_Control:Drilling_Fluids:Non-Aqueous_Drilling_Fluid_Systems,Fluids_Solids_Control:Drilling_Fluids_Solutions,"},{"title":"GOM: Customized Solids-Free Displacement Spacer Delivers Clean Fluid and Saves Filtration","description":"Baroid was requested to conduct a displacement in a deviated\nwell in a water depth of more than 8,000 feet (2,438 meters).\nThis followed a poor experience with a competitor\u2019s system, and\nincluded a request to avoid the use of solid weighting agents.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/BaraKlean-GOM.pdf","docCreatedDate":"2017-01-12T22:30:00.000-06:00","modifiedDate":"2017-01-12T22:30:00.000-06:00","docdate":"2017-01-12T22:30:00.000-06:00","docrefNum":"H012390","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|brandgroups:Baroid,|locations:Oceans_Gulfs_International_Waters:Gulf_of_Mexico,|prodgroups:Fluids_Solids_Control:Displacement_Systems,"},{"title":"STICK-LESS 20® lubricant beads smooth the path for whipstock","description":"STICK-LESS 20® Lubricant Beads Reduce Drag 85\u201390% and Enable Whipstock to Reach Target 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operations","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H012777.pdf","docCreatedDate":"2018-01-12T22:30:00.000-06:00","modifiedDate":"2018-01-12T22:30:00.000-06:00","docdate":"2018-01-12T22:30:00.000-06:00","docrefNum":"H012777","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges,|brandgroups:Baroid,|locations:Global,Europe:Northern_Europe:Norway_Northern_Europe,|prodgroups:Fluids_Solids_Control:Drilling_Fluids:Non-Aqueous_Drilling_Fluid_Systems,"},{"title":"Engineered Low-Density Polymer WBM Saves Rig Time and Casing String in High-Temperature Well","description":"Engineered Low-Density Polymer WBM Saves Rig Time and Casing String in High-Temperature 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operations","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H012797.pdf","docCreatedDate":"2018-01-10T22:30:00.000-06:00","modifiedDate":"2018-01-11T22:30:00.000-06:00","docdate":"2018-01-10T22:30:00.000-06:00","docrefNum":"H012797","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges,|brandgroups:Baroid,|locations:Global,Africa:Southern_Africa:Angola_Southern_Africa,|prodgroups:Fluids_Solids_Control:Separation_&_Handling:Thermal_Treatment,Fluids_Solids_Control:Solids_Control:Engineering_Services,"},{"title":"STOPPIT® and BARACARB® LCM Blends Significantly Reduce Fluid Costs and Rig Time","description":"The operator was having problems with severe lost circulation in the area. On a previous well, 1,033 bbl of oil-based fluid was lost, amounting to a total well cost of more than $380,000. As an added challenge, there was a previous recommendation of 18 lb/bbl of LCM that could be added to the drilling fluid due to the tool restrictions in the drill string.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H09820.pdf","docCreatedDate":"2012-10-01T23:30:00.000-05:00","modifiedDate":"2018-02-05T22:30:00.000-06:00","docdate":"2012-10-01T23:30:00.000-05:00","docrefNum":"H09820","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Control_Challenges:Lost_Circulation,|brandgroups:Baroid,|locations:North_America:United_States:Wyoming,Global,|prodgroups:Fluids_Solids_Control:Drilling_Fluid_Additives:Lost_Cirulation_Materials-Baroid:Remediation_LCM,"},{"title":"Custom Water-Based Fluid Achieves New Drilling Record in Iraq\u2019s Rumaila Field","description":"Customized Fluid Systems saves 6.4 days of operation","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H012747.pdf","docCreatedDate":"2017-11-10T22:30:00.000-06:00","modifiedDate":"2017-11-10T22:30:00.000-06:00","publishDate":"2018-10-02T11:07:21.680-05:00","docdate":"2017-11-10T22:30:00.000-06:00","docrefNum":"H012747","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Formation_Challenges:Shale,|brandgroups:Baroid,|locations:Middle_East:Iraq_Middle_East,Global,|prodgroups:Fluids_Solids_Control:Drilling_Fluid_Additives,Fluids_Solids_Control:Drilling_Fluid_Additives:Borehole_Shale_Stabilizers-Baroid,"},{"title":"BaraKlean-648 cleaner strips heavy wax from completion assembly","description":"BaraKlean-648 casing cleaner helps remove wax in wellbore cleanout limited by low pit and pump rate capacities","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/CFS-648WaxRemoval.pdf","docCreatedDate":"2016-01-13T22:30:00.000-06:00","modifiedDate":"2016-04-14T23:30:00.000-05:00","docdate":"2016-01-13T22:30:00.000-06:00","docrefNum":"H012053","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Baroid,|locations:Global,Europe:Western_Europe:United_Kingdom_Western_Europe,|prodgroups:Fluids_Solids_Control:Displacement_Systems,"},{"title":"Customized Kill Mud Enables Operator to Abandon Well Ahead of Time, Saving USD 1 Million","description":"» Minimize ECD while working with collapsed tubing\n» Develop a low-solids/low-rheology kill-weight mud within a tight time frame","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H012666.pdf","docCreatedDate":"2017-10-16T23:30:00.000-05:00","modifiedDate":"2017-10-16T23:30:00.000-05:00","docdate":"2017-10-16T23:30:00.000-05:00","docrefNum":"H012666","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Construction_Challenges:Abandonment,|brandgroups:Baroid,|locations:Global,Oceans_Gulfs_International_Waters:North_Sea,|prodgroups:Fluids_Solids_Control:Drilling_Fluids_Solutions,Fluids_Solids_Control:Fluids_Engineering,"},{"title":"US California: BARO-TROL® PLUS and CLAYSEAL® PLUS Shale Stabilizers Help Combat Sloughing Shale, Stuck Pipe","description":"As with several other wells in the area, operators on this well encountered issues with sloughing shale, tight hole, and packing off. The usual approach to drilling through these reactive formations is to use oil-based mud (OBM) due to its ability to inhibit the shale, thus delivering successful drilling operations. 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Offset well records in the Kadanwari field showed similar lost circulation incidents","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H012667.pdf","docCreatedDate":"2017-09-19T23:30:00.000-05:00","modifiedDate":"2017-10-02T23:30:00.000-05:00","docdate":"2017-09-19T23:30:00.000-05:00","docrefNum":"H012667","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Control_Challenges:Lost_Circulation,|brandgroups:Baroid,|locations:Global,Asia:Southern_Asia:Pakistan_Southern_Asia,|prodgroups:Fluids_Solids_Control:Drilling_Fluid_Additives:Lost_Cirulation_Materials-Baroid:Remediation_LCM,Fluids_Solids_Control:Drilling_Fluid_Additives:Lost_Cirulation_Materials-Baroid,Fluids_Solids_Control:Drilling_Fluid_Additives,"},{"title":"Dynamic pad mud solution provides wellbore stability and reduces costs","description":"Well-planned pad mud operation helps maintain wellbore stability in\ndeviated top hole riser less drilling, saving costs and eliminating casing\nstring from well design","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/PadMudAngola.pdf","docCreatedDate":"2016-02-18T22:30:00.000-06:00","modifiedDate":"2016-02-18T22:30:00.000-06:00","publishDate":"2018-10-02T11:06:32.697-05:00","docdate":"2016-02-18T22:30:00.000-06:00","docrefNum":"H011992","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|locations:Africa:Southern_Africa:Angola_Southern_Africa,|prodgroups:Fluids_Solids_Control:Drilling_Fluid_Additives:Viscosifiers-Suspending_Agents-Baroid,Fluids_Solids_Control:Drilling_Fluid_Additives:Filtrate_Control_Agents-Baroid,Fluids_Solids_Control:Drilling_Fluids,"},{"title":"Qatar: STOPPIT® Lost Circulation Material Enables Customer to Regain Circulation after Total Losses","description":"Due to previous success with STOPPIT® Lost Circulation Material (LCM) in other areas, Baroid introduced STOPPIT LCM into the planning phase and the drilling program for the current well.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H011324.pdf","docCreatedDate":"2014-08-29T23:30:00.000-05:00","modifiedDate":"2014-08-29T23:30:00.000-05:00","publishDate":"2018-10-02T11:05:41.468-05:00","docdate":"2014-08-29T23:30:00.000-05:00","docrefNum":"H011324","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Control_Challenges:Lost_Circulation,|brandgroups:Baroid,|locations:Middle_East:Qatar_Middle_East,|prodgroups:Fluids_Solids_Control:Drilling_Fluid_Additives:Lost_Cirulation_Materials-Baroid:Remediation_LCM,"},{"title":"ENVIROMUL™ HT Invert Emulsion Fluid System Enables Operator to Successfully Drill HPHT Well in North Sea","description":"An operator was planning to drill the first subsea highpressure/\nhigh-temperature (HPHT) well in the North Sea for several years. The operator challenged Baroid to provide a fluid solution that would allow for drilling the 8 1/2-in reservoir section from 13,910 feet (4,240 meters) (cased depth) to 14,859 feet (4,529 meters) without\nexceeding a drilling window of 1.5 lb/gal, which would risk fracturing formation at the casing shoe. 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They wanted to ensure that maximum communication between the reservoir formation water and the wellbore could be achieved.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H09425.pdf","docCreatedDate":"2012-08-01T23:30:00.000-05:00","modifiedDate":"2014-11-17T22:30:00.000-06:00","publishDate":"2018-10-02T11:05:20.118-05:00","docdate":"2012-08-01T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges:Filter_Cake_Removal,|brandgroups:Baroid,|locations:Oceans_Gulfs_International_Waters:North_Sea,|prodgroups:Fluids_Solids_Control:Breaker_Systems,"},{"title":"Kazakhstan: INNOVERT® System Used in Well\u2019s Record-Breaking Performance","description":"An operator working in the\nKarachaganak field was looking for an innovation that would\noptimize the incumbent drilling program in an effort to further\nreduce costs and improve the efficiency of the stimulation\nprocess.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H08032.pdf","docCreatedDate":"2010-11-01T23:30:00.000-05:00","modifiedDate":"2010-11-10T22:30:00.000-06:00","publishDate":"2018-10-02T11:05:14.543-05:00","docdate":"2010-11-01T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Formation_Challenges:Damaged_Formations,Borehole_Challenges:Borehole_Damage,|brandgroups:Baroid,|locations:Asia:Central_Asia:Kazakhstan_Central_Asia,Global,|prodgroups:Fluids_Solids_Control:Drilling_Fluids:Non-Aqueous_Drilling_Fluid_Systems,"},{"title":"Kazakhstan: Innovative Waste Management System from Baroid Surface Solutions Helps Assure Environmental Compliance and Saves Millions","description":"For more than four years the TCC system has operated successfully for this operator, handling up to three drilling rig operations, and treating more than 36,000m³ of oil based drill cuttings.","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H010798.pdf","docCreatedDate":"2014-03-01T22:30:00.000-06:00","modifiedDate":"2014-03-17T23:30:00.000-05:00","publishDate":"2018-10-02T11:05:40.346-05:00","docdate":"2014-03-01T22:30:00.000-06:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges:Waste_Management,|brandgroups:Baroid,|locations:Asia:Central_Asia:Kazakhstan_Central_Asia,|prodgroups:Fluids_Solids_Control:Separation_&_Handling:Thermal_Treatment,Fluids_Solids_Control:Waste_Management,"},{"title":"Vacuum-Feed Vertical Cuttings Dryer Simplifies Operations, Saves Costs","description":"BARAG-FORCE™ System saves operator more than USD 25K per well in Shale play","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/vacuum-feed-vertical-cuttings-dryer.pdf","docCreatedDate":"2018-09-03T14:34:00.000-05:00","modifiedDate":"2018-11-06T14:37:08.492-06:00","docdate":"2018-09-03T14:34:00.000-05:00","docrefNum":"H013035","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Fluids_Solids_Control:Separation_&_Handling,Fluids_Solids_Control:Waste_Management:Waste_Treatment_&_Disposal:Cuttings_Dryers,"},{"title":"BaraCRI™ Services Help Reduce Environmental Impact in First CRI Application in Ecuador","description":"Install BaraCRI™ cuttings reinjection system to replace surface storage pits and waste treatment equipment","path":"/content/dam/ps/public/bar/contents/Case_Histories/web/H012899.pdf","docCreatedDate":"2018-04-06T23:30:00.000-05:00","modifiedDate":"2018-04-06T23:30:00.000-05:00","docdate":"2018-04-06T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges,|brandgroups:Baroid,|locations:South_America:Ecuador_Western_South_America,Global,|prodgroups:Fluids_Solids_Control:Separation_&_Handling:Cuttings_Reinjection,"},{"title":"Russia: BARADRIL-N® Drill-In Fluid System Helped Increase Production on Multilateral Horizontal Wells","description":"The challenged invloved increasing production by drilling multilateral horizontal wells in a depleted reservoir with a low pore pressure gradient. 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This was the first horizontal well drilled by the operator in this area.\nDrilling on offset wells had been delayed by frequent backreaming and sidetracking in the 8-1/2-inch section. 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This water problem had led to the well being plugged over 20 years ago.","path":"/content/dam/ps/premium/pe/contents/Case_Histories/web/evc/122.asp","docCreatedDate":"2006-09-07T23:30:00.000-05:00","modifiedDate":"2006-09-07T23:30:00.000-05:00","publishDate":"2018-10-02T02:35:58.975-05:00","docdate":"2006-09-07T23:30:00.000-05:00","languageSet":["English"],"accessType":"R","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,Formation_Challenges:Low_Permeability_Formations,|locations:Global,"},{"title":"Ex-Tension Pac(SM) Service Effectively Controls Sand, Increases Gas Production (Case History)","description":"A 10,250 ft well in a Frio sand formation needed to be block-squeezed prior to testing. The operator shot the interval and tested it for production. But after short periods of flow, the surface equipment would plug up, and the perforations became covered with formation fines. Although the average flow rate tested at 27 BOPD and 400 MCFD with a BHP of 7400 psi, continued production had become uneconomical.","path":"/content/dam/ps/premium/pe/contents/Case_Histories/web/evc/2529.asp","docCreatedDate":"2006-05-09T23:30:00.000-05:00","modifiedDate":"2006-05-09T23:30:00.000-05:00","docdate":"2006-05-09T23:30:00.000-05:00","languageSet":["English"],"accessType":"R","dataSearch":"custchallenges:Formation_Challenges:Low_Permeability_Formations,Formation_Challenges:High_Permeability_Formations,Production_Challenges:Sand_Production,Formation_Challenges:Sandstone_Formations,|locations:Global,|prodgroups:Sand_Control,"},{"title":"Ferchek® SC Iron Control System Outperforms Competition; Adds over $1.5 Million in New Production (Case History)","description":"An operator wanted to stimulate a six foot Wolfcamp Limestone zone with 20% HCl acid in order to increase production on a 5,100 foot well.","path":"/content/dam/ps/premium/pe/contents/Case_Histories/web/evc/763.asp","docCreatedDate":"2006-05-09T23:30:00.000-05:00","modifiedDate":"2006-05-09T23:30:00.000-05:00","publishDate":"2018-10-02T02:35:58.381-05:00","docdate":"2006-05-09T23:30:00.000-05:00","languageSet":["English"],"accessType":"R","dataSearch":"custchallenges:Formation_Challenges:Low_Permeability_Formations,|locations:Global,|prodgroups:Stimulation:Acidizing,"},{"title":"Delta FracSM Fluid System Delivers More Than Five-Fold Increase in Productivity","description":"An operator needed to improve production on a 3,000-foot San Andres formation well.","path":"/content/dam/ps/premium/pe/contents/Case_Histories/web/evc/4829.asp","docCreatedDate":"2006-05-09T23:30:00.000-05:00","modifiedDate":"2006-05-09T23:30:00.000-05:00","publishDate":"2018-10-02T02:35:58.381-05:00","docdate":"2006-05-09T23:30:00.000-05:00","languageSet":["English"],"accessType":"R","dataSearch":"custchallenges:Production_Challenges,|locations:Global,"},{"title":"HydroChek® Service Eliminates Water Production, Adds Approximately $80 Million in Value (Case History)","description":"An operator had enjoyed significant success using Halliburton HydroChek® service to reduce water production in an offshore well. Now, that operator wanted to use that technology to restore production in a 2,845 foot well on the same platform that had been shut in because of water entering through a channel behind the pipe. ","path":"/content/dam/ps/premium/pe/contents/Case_Histories/web/evc/4743.asp","docCreatedDate":"2006-05-09T23:30:00.000-05:00","modifiedDate":"2006-05-09T23:30:00.000-05:00","docdate":"2006-05-09T23:30:00.000-05:00","languageSet":["English"],"accessType":"R","dataSearch":"custchallenges:Production_Challenges:Control_of_Water_and_Gas_Production,|locations:Global,|prodgroups:Stimulation:Water_Management,"},{"title":"MRIL® Tool Finds New Zone, StiMRIL Confirms It","description":"A customer working in a South Texas field drilled his first prospect and wanted as much technical support as possible to determine the potential of the well.","path":"/content/dam/ps/premium/pe/contents/Case_Histories/web/evc/227.asp","docCreatedDate":"2006-05-09T23:30:00.000-05:00","modifiedDate":"2006-05-09T23:30:00.000-05:00","publishDate":"2018-10-02T02:35:58.975-05:00","docdate":"2006-05-09T23:30:00.000-05:00","languageSet":["English"],"accessType":"R","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,Formation_Challenges:Low_Permeability_Formations,|locations:Global,|prodgroups:Stimulation:Fracturing,Wireline_and_Perforating:Evaluation_Solutions:Auxiliary_Logging_Solutions,"},{"title":"Valve Saves Twelve Hours of Rig Time in First Subsea Operation","description":"The Halliburton eRED® intelligent downhole equalizing device had been previously used successfully in several platform operations for BP in the UK and Norwegian sectors. 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However, repeatedly setting and removing the plug and\nprong in the landing string can take up a lot of valuable rig time.","path":"/content/dam/ps/public/wd/contents/Case_Histories/H012033-eRED-Vietnam.pdf","docCreatedDate":"2016-01-07T22:30:00.000-06:00","modifiedDate":"2016-01-07T22:30:00.000-06:00","docdate":"2016-01-07T22:30:00.000-06:00","docrefNum":"H012033","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Remote_Open_Close_Technology,"},{"title":"Auto-Gas Lift: SmartWell® System Collaboration Driving Success in Indonesia","description":"Collaboration was the key to success for a recent project in Jakarta, Indonesia, when two key Halliburton technologies helped a customer successfully complete its well and prompted significant interest in SmartWell® completion systems throughout Indonesia and the Asia Pacific Region. \n","path":"/content/dam/ps/public/wd/contents/Case_Histories/H07913.pdf","docCreatedDate":"2015-10-13T23:30:00.000-05:00","modifiedDate":"2015-10-13T23:30:00.000-05:00","publishDate":"2018-10-02T11:28:10.513-05:00","docdate":"2015-10-13T23:30:00.000-05:00","docrefNum":"H07913","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Intelligent_Completions:Interval_Control-WellDynamics,"},{"title":"Flexibility of eRED® Valve Aids Success of Acid Stimulation Operation","description":"An operator was looking for a reliable method of selectively perforating and acid stimulating two independent zones.","path":"/content/dam/ps/public/wd/contents/Case_Histories/H010516.pdf","docCreatedDate":"2017-08-30T23:30:00.000-05:00","modifiedDate":"2017-08-30T23:30:00.000-05:00","docdate":"2017-08-30T23:30:00.000-05:00","docrefNum":"H010516","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Workflow_Integration:HalComplete:Deepwater_Completions,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Remote_Open_Close_Technology,"},{"title":"eRED® Valve Saves Six Hours Rig-Time for BP","description":"eRED® Valve Saves 6 hours Rig-time for BP","path":"/content/dam/ps/public/wd/contents/Case_Histories/H010438_eRED-Case-History.pdf","docCreatedDate":"2016-02-10T22:30:00.000-06:00","modifiedDate":"2016-02-10T22:30:00.000-06:00","docdate":"2016-02-10T22:30:00.000-06:00","docrefNum":"H010438","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Workflow_Integration:HalComplete:Deepwater_Completions,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Remote_Open_Close_Technology,"},{"title":"Intelligent Completion in System Provides Operator Solutions in the Remote Niger Delta","description":"The Nigerian subsidiary of an international oil company wanted to pilot test intelligent completion technology in one of the largest fields in the western swamp area. However, the\nremoteness and the peculiar operating environment in the Niger Delta made installation of surface equipment required to operate/communicate with the downhole intelligent\ncompletion equipment a challenge.","path":"/content/dam/ps/public/wd/contents/Case_Histories/H011882.pdf","docCreatedDate":"2015-10-02T23:30:00.000-05:00","modifiedDate":"2015-10-02T23:30:00.000-05:00","publishDate":"2018-10-02T11:28:15.585-05:00","docdate":"2015-10-02T23:30:00.000-05:00","docrefNum":"H011882","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Intelligent_Completions:Surface_Control_and_Monitoring_Systems-WellDynamics,Completion_Equipment_and_Services:Intelligent_Completions:Zonal_Isolation-WellDynamics,Completion_Equipment_and_Services:Intelligent_Completions:Interval_Control-WellDynamics,Completion_Equipment_and_Services:Permanent_Monitoring-WellDynamics,"},{"title":"eRED® Valve Replaces Ball-Drop Method to Set Hydraulic Packer","description":"Chevron had previously experienced some\nchallenges when dropping a ball to set a hydraulic packer on another well. Faced with a\nsimilar situation on a highly deviated well with a long horizontal section, Chevron recognized\nthe potential for issues when they needed to set the packer.","path":"/content/dam/ps/public/wd/contents/Case_Histories/eRED-Valve-Replaces-Ball-Drop-H012642.PDF","docCreatedDate":"2017-09-28T23:30:00.000-05:00","modifiedDate":"2017-09-28T23:30:00.000-05:00","docdate":"2017-09-28T23:30:00.000-05:00","docrefNum":"H012642","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Workflow_Integration:HalComplete:Deepwater_Completions,Deepwater,Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Remote_Open_Close_Technology,"},{"title":"Intelligent Completion Technology Enables Selective Injection and Production in Mature Field Offshore China","description":"One operator in the South China Sea\nwas operating in a mature field that had been producing for approximately seven years, and had experienced a relatively steep production decline. The legacy single-string completions installed in the water injector wells prevented the operator from distributing injection rates across the heterogeneous reservoir. 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The operator needed a solution that would eliminate the wellbore intervention step required to clean out traditional composite frac plugs.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H012203-Illusion-Williston.pdf","docCreatedDate":"2016-05-12T23:30:00.000-05:00","modifiedDate":"2016-05-12T23:30:00.000-05:00","docdate":"2016-05-12T23:30:00.000-05:00","docrefNum":"H012203","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools:Dissolvable_Tools,"},{"title":"First Single-Trip Negative Test and Wellbore Cleanup in Egypt","description":"Inflow Tech test packer displaces fluids in a single-trip solution","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H012282-CleanWell-Egypt.pdf","docCreatedDate":"2016-10-19T23:30:00.000-05:00","modifiedDate":"2016-10-19T23:30:00.000-05:00","docdate":"2016-10-19T23:30:00.000-05:00","docrefNum":"H012282","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Workflow_Integration:HalComplete:Deepwater_Completions,|locations:Global,|prodgroups:Wellbore_Service_Tools:Wellbore_Cleaning_Tools,Wellbore_Service_Tools:Wellbore_Cleaning_Tools:Riser_Cleanout_Tools,Wellbore_Service_Tools:Wellbore_Cleaning_Tools:Debris_Extraction_Tools,Wellbore_Service_Tools:Wellbore_Cleaning_Tools:Specialty_Tools-Wellbore_Cleaning,"},{"title":"RapidStage® frac sleeves and RapidBall™ self-removing balls delivered increased efficiency and cost savings without wellbore intervention","description":"An independent oil and gas operator in Alaska was looking for new ways to help reduce well costs and intervention. The completion design called for a production liner to be run and 11 stages to be stimulated through the target section of a wellbore that was more than 20,000 feet in total measured depth (TMD).","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H011803-RapidBall-Alaska.pdf","docCreatedDate":"2015-07-24T23:30:00.000-05:00","modifiedDate":"2015-07-24T23:30:00.000-05:00","docdate":"2015-07-24T23:30:00.000-05:00","docrefNum":"H011803","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools:Dissolvable_Tools,Completion_Equipment_and_Services:Unconventional_Completions:Frac_Sleeve_Systems,Completion_Equipment_and_Services:Unconventional_Completions:Accessories-Horizontal_Completions,"},{"title":"Swellpacker&reg; Sleeve and Anchor Enables Well Abandonment","description":"An operator in the North\nSea was unable to permanently abandon a well due to the\ninability to access the main wellbore. Halliburton designed\nand manufactured a hold-open sleeve (HOS) to straddle the\nsafety valve with integral no-go and Swellpacker® tool element\ndesigned to swell and anchor the sleeve in place.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H07233.pdf","docCreatedDate":"2018-04-16T23:30:00.000-05:00","modifiedDate":"2018-04-16T23:30:00.000-05:00","docdate":"2018-04-16T23:30:00.000-05:00","docrefNum":"H07233","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Construction_Challenges:Zonal_isolation,|locations:Europe,Global,|prodgroups:Completion_Equipment_and_Services:Swell_Technology,"},{"title":"Norway: Two Production Wells in Different Pressured Reservoirs Receive High-Pressure Water Injection from One Multilateral Well","description":"StatoilHydro required a TAML level 5 multilateral junction constructed from a subsea platform with the ability to accommodate high injection pressure and possible large pressure differences between the two lateral branches in two different reservoirs.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H06600_Norway_FlexRite_Case_History.pdf","docCreatedDate":"2009-07-15T23:30:00.000-05:00","modifiedDate":"2016-08-11T23:30:00.000-05:00","docdate":"2009-07-15T23:30:00.000-05:00","docrefNum":"H06600","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Drilling_Challenges:Deepwater_Drilling,Reservoir_Challenges:Improve_Reservoir_Drainage,|locations:Europe:Northern_Europe:Norway_Northern_Europe,Global,|prodgroups:Multilateral,Multilateral:Multilateral_Completion_Systems,Multilateral:Multilateral_Pre-milled_Window_Systems,Drilling,"},{"title":"Single-trip solution to set packer and perform negative test saves operator rig time and $1.8 million","description":"A major operator challenged Halliburton to design and execute a single-trip solution to set an EZ Drill® SVB packer and to also\nperform a negative test from 13 ppg to 9 ppg of mud equivalent with the CleanWell® Inflow Tech® test packer. Additionally,\nHalliburton would need to install a wear bushing insert while running the operation in hole. When pulling out of the hole, the\nwear bushing insert would need to be removed and the setting area jetted. Performing these three applications in one run would\nbe a challenge, but the result would save the customer costly rig time.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H011979-GOM-CWT.pdf","docCreatedDate":"2015-10-29T23:30:00.000-05:00","modifiedDate":"2016-04-22T23:30:00.000-05:00","docdate":"2015-10-29T23:30:00.000-05:00","docrefNum":"H011979","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Workflow_Integration:HalComplete:Deepwater_Completions,Deepwater,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools:Packers-Service_Tools,Wellbore_Service_Tools:Wellbore_Cleaning_Tools:Specialty_Tools-Wellbore_Cleaning,"},{"title":"Halliburton Shifts to Success in Eastern European Sea","description":"Since 2008, a major operator has been pursuing a highly specialized solution for stimulating their wells in an Eastern European Sea development project. In completing the final wells of their offshore\nreentry unconventional campaign, the key challenge they faced was finding a viable solution to selectively stimulate multiple independent zones in openhole horizontal applications that were\ndrilled from existing vertical wellbores.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H011948.pdf","docCreatedDate":"2015-10-02T23:30:00.000-05:00","modifiedDate":"2015-10-02T23:30:00.000-05:00","docdate":"2015-10-02T23:30:00.000-05:00","docrefNum":"H011948","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools:Dissolvable_Tools,Completion_Equipment_and_Services:Unconventional_Completions:Frac_Sleeve_Systems,Completion_Equipment_and_Services:Packers:Openhole_Packer,Completion_Equipment_and_Services:Unconventional_Completions:Accessories-Horizontal_Completions,"},{"title":"Mag Tech casing magnet leaves Shell\u2019s wellbore free from ferrous debris","description":"Operator achieves the high rotational speeds desired for an efficient wellbore cleanup","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H012152-MagTech-Shell.PDF","docCreatedDate":"2016-04-05T23:30:00.000-05:00","modifiedDate":"2016-04-05T23:30:00.000-05:00","docdate":"2016-04-05T23:30:00.000-05:00","docrefNum":"H012152","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Fluids_Challenges:Hole_Cleaning_Cuttings_Removal,|locations:Oceania:Australia_Oceania,|prodgroups:Wellbore_Service_Tools:Wellbore_Cleaning_Tools:Debris_Extraction_Tools,"},{"title":"RapidStart® Initiator CT Sleeve Delivers Substantial Time and Money Savings to Argentina Operator Using Delayed Completions","description":"A major operator in Argentina needed to reduce the cost and time associated with its plug\nand perforate (PnP) completion operations in the Vaca Muerta shale play. The goal was to\nimprove project returns so that the operator could continue developing its acreage.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H012057-RapidStartCT-LA.pdf","docCreatedDate":"2016-02-08T22:30:00.000-06:00","modifiedDate":"2016-02-08T22:30:00.000-06:00","docdate":"2016-02-08T22:30:00.000-06:00","docrefNum":"H012057","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Frac_Sleeve_Systems,"},{"title":"RapidStart&reg; Initiator CT Sleeve Opens Successfully 32 Months After Installation","description":"Murphy Sees Repeated Reliability in DUC Wells","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H012440-RSI-CT-Sleeve-32months.pdf","docCreatedDate":"2017-01-18T22:30:00.000-06:00","modifiedDate":"2017-05-10T23:30:00.000-05:00","docdate":"2017-01-18T22:30:00.000-06:00","docrefNum":"H012440","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Frac_Sleeve_Systems,"},{"title":"XtremeGrip&trade; System Offers Metal-to-Metal Solution","description":"High-performance liner hanger solves deepwater well challenges in elevated temperature for GoM operator.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H011546-XTremeGrip-GOM.pdf","docCreatedDate":"2017-07-06T23:30:00.000-05:00","modifiedDate":"2017-07-06T23:30:00.000-05:00","docdate":"2017-07-06T23:30:00.000-05:00","docrefNum":"H011546","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Workflow_Integration:HalComplete:Deepwater_Completions,Deepwater,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Liner_Hangers:Expandable_Liner_Hanger,"},{"title":"Swellpacker&reg; Systems Help Save $3 Million by Reducing Rig Time","description":"Halliburton enables greater productivity in development wells, helping to decrease completion time by 10 days","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H06786.pdf","docCreatedDate":"2017-08-22T23:30:00.000-05:00","modifiedDate":"2017-08-22T23:30:00.000-05:00","docdate":"2017-08-22T23:30:00.000-05:00","docrefNum":"H06786","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|locations:South_America:Brazil_Eastern_South_America,|prodgroups:Completion_Equipment_and_Services:Liner_Hangers:Expandable_Liner_Hanger,Completion_Equipment_and_Services:Swell_Technology,"},{"title":"RapidStage&reg; 50+ system with AccessFrac&reg; service shines in the Bakken","description":"Dozens of applications using AccessFrac service have been successfully performed throughout the Rockies. In the Williston Basin, over 20 jobs performed with RapidStage 50+ sleeves and AccessFrac stimulation services in the past six months have resulted in a minimum of 30% sustained production improvement.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/RapidStage50-AccessFrac-Bakken.pdf","docCreatedDate":"2016-07-26T23:30:00.000-05:00","modifiedDate":"2016-07-28T23:30:00.000-05:00","docdate":"2016-07-26T23:30:00.000-05:00","docrefNum":"H011802","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools:Dissolvable_Tools,Completion_Equipment_and_Services:Unconventional_Completions:Frac_Sleeve_Systems,Completion_Equipment_and_Services:Swell_Technology,Completion_Equipment_and_Services:Unconventional_Completions:Accessories-Horizontal_Completions,"},{"title":"Integrated Solution More Than Doubles Reservoir Contact","description":"Halliburton Multilateral Services and Intelligent Completions Optimizes Oil Production Offshore Saudi Arabia","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/Saudi-MLT-IC.pdf","docCreatedDate":"2017-11-06T22:30:00.000-06:00","modifiedDate":"2017-11-06T22:30:00.000-06:00","docdate":"2017-11-06T22:30:00.000-06:00","docrefNum":"H07668","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Intelligent_Completions:Interval_Control-WellDynamics,Multilateral:Multilateral_Milled_Exit_Systems,"},{"title":"BR0 Modular Straddle increases oil production and decrease GOR","description":"A global operator in Africa had a high gas/oil ratio (GOR) well and needed a mechanical solution to isolate the high gas-producing zone in order to improve oil production performance.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H010788-Angola.pdf","docCreatedDate":"2013-11-12T22:30:00.000-06:00","modifiedDate":"2013-11-12T22:30:00.000-06:00","docdate":"2013-11-12T22:30:00.000-06:00","docrefNum":"H010788","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Horizontal_Completions,Well_Control_Challenges:Gas_Hydrates,Production_Challenges:Control_of_Water_and_Gas_Production,Production_Challenges:Long_Term_Zonal_Isolation,Production_Challenges:Improving_Oil_Recovery,|locations:Global,|prodgroups:Wireline_and_Perforating:Slickline:Mechanical_Intervention,Completion_Equipment_and_Services:Intervention_Solutions-Well_Completions,Wireline_and_Perforating:Slickline,"},{"title":"ZoneGuard® SR packers provide reliable isolation during frac job","description":"A customer in Canada wanted to perform a multi-zone\nfrac job to optimize well production.\nHalliburton proposed using hydraulically set ZoneGuard®\nSR packers to isolate all 27 zones to achieve the desired zonal isolation and in\nconjunction with the packers utilize the RapidStage™ sleeves for selectively\ntreating the zones.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H09114.pdf","docCreatedDate":"2017-03-16T23:30:00.000-05:00","modifiedDate":"2017-03-16T23:30:00.000-05:00","docdate":"2017-03-16T23:30:00.000-05:00","docrefNum":"H09114","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,North_America,|prodgroups:Completion_Equipment_and_Services:Packers:Openhole_Packer,Completion_Equipment_and_Services:Unconventional_Completions:Frac_Sleeve_Systems,"},{"title":"Cemented VersaFlex® expandable liner hanger provided superior reliability and saved 24 hours of rig time","description":"A major operator in Australia wanted to install a\n4 1/2-in. liner hanger into a 6 1/8-in. openhole wellbore. They knew that\nonce they reached total depth, if the flow rate was unacceptable, the\nliner hanger would need to be run and cemented in place to enable\nfracturing operations.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H011210.pdf","docCreatedDate":"2014-09-03T23:30:00.000-05:00","modifiedDate":"2014-09-03T23:30:00.000-05:00","docdate":"2014-09-03T23:30:00.000-05:00","docrefNum":"H011210","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Cementing,Cementing:Cementing_Solutions:Slurries,Completion_Equipment_and_Services:Liner_Hangers:Expandable_Liner_Hanger,"},{"title":"Fas Drill® Ultra Frac Plugs Reduce Time and Difficulty of Millout Operations","description":"Average millout time proves to be 4.5 minutes, less than half of a typical composite plug","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/FasDrill-Ultra-Williston-H012640.pdf","docCreatedDate":"2017-09-21T23:30:00.000-05:00","modifiedDate":"2017-09-21T23:30:00.000-05:00","docdate":"2017-09-21T23:30:00.000-05:00","docrefNum":"H012640","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools:Plugs-Service_Tools:Frac_Plugs,Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools:Plugs-Service_Tools,Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools,"},{"title":"Versatile Completion Results in 72% GOR Reduction Without Affecting Oil Production","description":"Halliburton Delivers the Most Reliable, Cost-Effective Completion Over the Competition","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/Algeria-UC-GOR-Reduction-H012594.pdf","docCreatedDate":"2017-09-13T23:30:00.000-05:00","modifiedDate":"2017-09-13T23:30:00.000-05:00","docdate":"2017-09-13T23:30:00.000-05:00","docrefNum":"H012594","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Production_Optimization,Production_Challenges:Unconventional_Resources,Well_Construction_Challenges:Zonal_isolation,Production_Challenges:Horizontal_Completions,Production_Challenges:Improving_Oil_Recovery,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Frac_Sleeve_Systems,Completion_Equipment_and_Services:Swell_Technology,Completion_Equipment_and_Services:Liner_Hangers:Expandable_Liner_Hanger,"},{"title":"CleanWell® Technology Saves Operator 18 Hours of Rig Time","description":"Utilizing CleanWell® technology with additional features for high-pressure, high-temperature (HP/HT) environments, Halliburton was able to save the operator 18 hours of rig time with zero safety incidents or NPT raised.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H011142-Vietnam.pdf","docCreatedDate":"2014-08-01T23:30:00.000-05:00","modifiedDate":"2018-09-04T23:30:00.000-05:00","docdate":"2014-08-01T23:30:00.000-05:00","docrefNum":"H011142","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Horizontal_Completions,Fluids_Challenges:Hole_Cleaning_Cuttings_Removal,|locations:Global,|prodgroups:Wellbore_Service_Tools:Wellbore_Cleaning_Tools:Casing_Cleanout_Tools,Wellbore_Service_Tools:Wellbore_Cleaning_Tools:Riser_Cleanout_Tools,Wellbore_Service_Tools:Wellbore_Cleaning_Tools:Debris_Extraction_Tools,Wellbore_Service_Tools:Wellbore_Cleaning_Tools:Specialty_Tools-Wellbore_Cleaning,"},{"title":"Illusion® Frac Plug Helps Operator Save $200,000","description":"All 15 plugs dissolved, removing the need for coiled tubing millout","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H012448-Illusion-Argentina.pdf","docCreatedDate":"2017-01-31T22:30:00.000-06:00","modifiedDate":"2017-01-31T22:30:00.000-06:00","docdate":"2017-01-31T22:30:00.000-06:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools:Dissolvable_Tools,"},{"title":"North America:Isolate Water Zone in Extreme Dogleg Through Window Without Whipstock","description":"A customer in North America drilled a horizontal well. The horizontal section exposed the well to a 70-ft water bearing interval in the heel. 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However, the\npresence of a low-pressure zone in the open hole below the 16-in. shoe often led\nto cement losses and an inability to place cement entirely into the casing above.","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H06628.pdf","docCreatedDate":"2014-06-09T23:30:00.000-05:00","modifiedDate":"2014-06-09T23:30:00.000-05:00","docdate":"2014-06-09T23:30:00.000-05:00","docrefNum":"H06628","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|locations:Europe,Global,|prodgroups:Completion_Equipment_and_Services:Swell_Technology,"},{"title":"Illusion® Plug Saves Operator Approximately USD $515,000","description":"Interventionless Solution Allows Multiple Wells to be Placed on Production After Stimulation ","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/Argentina-Illusion-515K-H012966.pdf","docCreatedDate":"2018-06-18T23:30:00.000-05:00","modifiedDate":"2018-06-18T23:30:00.000-05:00","docdate":"2018-06-18T23:30:00.000-05:00","docrefNum":"H012966","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools:Dissolvable_Tools,"},{"title":"Illusion® Dissolvable Frac Plugs Enable Extended Laterals ","description":"Extended-Reach Lateral Solution Allows Operator to Gain Greater Access to Reservoir","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/ARG-Illusion-Extended-Reach-H013017.pdf","docCreatedDate":"2018-08-17T23:30:00.000-05:00","modifiedDate":"2018-08-17T23:30:00.000-05:00","docdate":"2018-08-17T23:30:00.000-05:00","docrefNum":"H013017","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Unconventional_Completions:Drillable_Tools:Dissolvable_Tools,"},{"title":"VersaFlex System Successfully Runs To Depth Without Internal Fluids in a Shallow Extended-Reach Well","description":"First-ever 'floated-in' liner installation in complex wellbore saves operator time and money","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H012397-VersaFlex-Williston.pdf","docCreatedDate":"2017-02-09T22:30:00.000-06:00","modifiedDate":"2017-02-09T22:30:00.000-06:00","docdate":"2017-02-09T22:30:00.000-06:00","docrefNum":"H012397","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Drilling_Challenges:Extended_Reach_Drilling_(ERD),|locations:Global,|prodgroups:Completion_Equipment_and_Services:Liner_Hangers:Expandable_Liner_Hanger,"},{"title":"Operator Achieves Record Results in West Africa Deepwater Completions Project","description":"Halliburton expertise helps reduce completions time, optimize operating efficiency and run reliablity","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/record-results-deepwater-nigeria.pdf","docCreatedDate":"2017-04-17T23:30:00.000-05:00","modifiedDate":"2017-04-28T23:30:00.000-05:00","docdate":"2017-04-17T23:30:00.000-05:00","docrefNum":"H012552","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|locations:Africa:Western_Africa:Nigeria_Western_Africa,|prodgroups:Completion_Equipment_and_Services,"},{"title":"Latin America: Use of Swellpacker® Systems Achieves High Production","description":"Effective use of Swellpacker® systems achieves high production, saves time and reduces costs for Mexico operator","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H07608.pdf","docCreatedDate":"2013-11-01T23:30:00.000-05:00","modifiedDate":"2013-11-20T22:30:00.000-06:00","docdate":"2013-11-01T23:30:00.000-05:00","docrefNum":"H07608","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Construction_Challenges:Zonal_isolation,|locations:Central_America,South_America,Global,|prodgroups:Completion_Equipment_and_Services:Swell_Technology,"},{"title":"Norway: Swellpacker® systems provide isolation for multi-zone completion","description":"An operator planning a deep sidetrack from the\nmother bore faced the challenge of exiting the 10 3/4-in. liner in the\nreservoir beyond the challenges of standard multilateral wells:","path":"/content/dam/ps/public/cps/contents/Case_Histories/web/H09750.pdf","docCreatedDate":"2017-02-14T22:30:00.000-06:00","modifiedDate":"2017-05-10T23:30:00.000-05:00","docdate":"2017-02-14T22:30:00.000-06:00","docrefNum":"H09750","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Swell_Technology,"},{"title":"Swellable Packer Solves Casing Challenge, Successfully Sealing and Anchoring Tieback Liner ","description":"Swellpacker&reg; 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Therefore, prevention is of utmost importance.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/GOM-Prevent-Hydrate-Blockage-DeepSure-H012998.pdf","docCreatedDate":"2018-08-08T23:30:00.000-05:00","modifiedDate":"2018-08-08T23:30:00.000-05:00","docdate":"2018-08-08T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,Deepwater,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Hydrates:Hydrate_Inhibitors,Chemical_Services:Hydrates,"},{"title":"FAL<sup>®<\/sup> Service Proves Safer, More Cost-Effective Than Plunger Lifts","description":"After this customer initially tested Multi-Chem\u2019s FAL<sup>®<\/sup>\n(Foam Assisted Lift) service on two Marcellus Shale wells in their Central Highlands Field, they extended the FAL service trial to four additional wells. Rather\nthan installing costly plunger lifts, the customer chose FAL service in an effort to maintain operational\nexpense, reduce man hours invested in dangerous activity, and reclaim lost production due to the liquid loading.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Foam-Assisted-Lift-East-Coast-H011854.pdf","docCreatedDate":"2015-10-22T23:30:00.000-05:00","modifiedDate":"2015-10-22T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:34.902-05:00","docdate":"2015-10-22T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Liquid_Loading,"},{"title":"Consecutive Treatments Enhance Biocide Efficacy During Water Flooding of Algerian Oilfield","description":"An Algerian operator found it necessary to employ water flooding for optimal production at two of its mature oil and gas fields. The bulk injection water was comprised of a combination of saline produced water diluted with aquifer water.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Algeria-Biocide-Prevent-Corrosion-Injection-Manifold-H013019.pdf","docCreatedDate":"2018-08-16T23:30:00.000-05:00","modifiedDate":"2018-08-16T23:30:00.000-05:00","docdate":"2018-08-16T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Africa:Northern_Africa:Algeria_Northern_Africa,|prodgroups:Chemical_Services:Bacteria_Related_Issues:Biocides,"},{"title":"Infrared Imaging Identifies Composition of Leak Contents, Leads to Solution","description":"When this Operator\u2019s Midland station experienced a leak on a production line that is primarily stagnant, Multi-Chem technical services was contacted to complete a thermal imaging study to identify the contents (gas, oil, water and solids) within the line around the area of the leak.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Midstream-Midland-Infrared-Imaging.pdf","docCreatedDate":"2015-04-08T23:30:00.000-05:00","modifiedDate":"2015-04-08T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:33.583-05:00","docdate":"2015-04-08T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Midstream_Solutions,"},{"title":"Operator Returns Plugged SWD Well to Full Production with Customized Chemical Treatment","description":"An operator was experiencing plugging issues that kept re-occurring in its saltwater disposal (SWD) well in the mature Roseland Plantation field, along the Gulf Coast of Louisiana.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Plugged-Well-Full-Production-Chemical-Treatment-H012967.pdf","docCreatedDate":"2018-06-13T23:30:00.000-05:00","modifiedDate":"2018-06-13T23:30:00.000-05:00","docdate":"2018-06-13T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:North_America:United_States,|prodgroups:Chemical_Services:Emulsion_Tendencies,Chemical_Services:Scale_Deposits,Chemical_Services:Water_Quality_Issues,Stimulation:Acidizing:Scale_Control,Chemical_Services:Flowline_Issues:Scale_Inhibitors,Chemical_Services:Fluid_&_Gas_Separation:Emulsion_Breakers,Chemical_Services:Water_Quality_Issues:Water_Clarifiers,"},{"title":"Squeeze Treatment Recovers Production from an Under-Producing Well","description":"An customer experienced considerable scale formation of CaSO4 and CaCO3 downhole in one of its assets. The challenge to control the high scaling potential produced brine contributed to a loss of 10,000 BOPD across the field and resulted in the shut-in of 10 of the 70 wells.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Middle-East-Squeeze-Treatment-Recovers-Production-H012932.pdf","docCreatedDate":"2018-08-16T23:30:00.000-05:00","modifiedDate":"2018-08-16T23:30:00.000-05:00","docdate":"2018-08-16T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Middle_East,|prodgroups:Chemical_Services:Scale_Deposits,Chemical_Services:Flowline_Issues:Scale_Inhibitors,Stimulation:Acidizing:Scale_Control,"},{"title":"Geographic Information System + MVP 2.0™ Chemical Program Management Tool Helps Operator Meet Strict Pipeline Integrity Regulations","description":"An exploration and production company took over a Mid-Continent region pipeline asset from a previous Multi-Chem customer, unaware that encroaching urban expansion now positioned the gathering systems within high consequence areas (HCAs) where\npipeline integrity is strictly regulated to protect human population and environmentally sensitive areas in the event of failure.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Midstream-GIS-MVP-Tool-Improve-Service-H011719.pdf","docCreatedDate":"2015-04-21T23:30:00.000-05:00","modifiedDate":"2015-04-21T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:34.902-05:00","docdate":"2015-04-21T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Midstream_Solutions,"},{"title":"Multi-Chem Customizes Long-Term Corrosion Mitigation in High H<sub>2<\/sub>S Gathering System","description":"This Canadian producer operates a gathering system that produces and transports various volumes of gas, condensate and water from a field where the challenging terrain and quality of production causes both major pipeline corrosion problems and emulsion issues at the gas treatment plant.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/MultiChem-Customizes-Long-Term-Corrosion-H011889.pdf","docCreatedDate":"2015-12-01T22:30:00.000-06:00","modifiedDate":"2015-12-01T22:30:00.000-06:00","publishDate":"2018-10-02T11:21:36.533-05:00","docdate":"2015-12-01T22:30:00.000-06:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Corrosion_Issues,Chemical_Services:Midstream_Solutions,"},{"title":"Remediation of Asphaltenesin Deep Water Wells Results in 2,000 BOPD Production Increase","description":"Multi-Chem was approached by the customer to develop a remediation plan (xylene soak) that would reduce the tubing differential pressure and return production to normal levels. The remedial xylene soak resulted in a 1,550 psi decrease in the tubing differential pressure was decreased by 1,550 psi.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Remediation-Asphaltenes-Deepwater-Production-Increase-H012680.pdf","docCreatedDate":"2018-04-23T23:30:00.000-05:00","modifiedDate":"2018-04-23T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:38.609-05:00","docdate":"2018-04-23T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|locations:Oceans_Gulfs_International_Waters:Gulf_of_Mexico,|prodgroups:Chemical_Services:Asphaltene_Tendencies,Chemical_Services:Wax_Deposits:Asphaltene_Inhibitor-Wax_Deposits,"},{"title":"Starting Multi-Chem Scale Control Program at Completion Reduces Workover Costs","description":"A producer in the Rocky Mountains\nrequested a cost-effective scale inhibitor be added to the completion fluid to prevent\ndownhole scale formation in the early stages of the well\u2019s life.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Scale-Control-Southern-Rocky-Mountain-H011393.pdf","docCreatedDate":"2015-03-11T23:30:00.000-05:00","modifiedDate":"2015-03-11T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:33.583-05:00","docdate":"2015-03-11T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Scale_Deposits,Stimulation:Acidizing:Scale_Control,Chemical_Services:Flowline_Issues:Scale_Inhibitors,"},{"title":"Rock-on-a-Chip™ Microfluidic Device Efficiently Evaluates Relative Effects of Surfactants in the Lab","description":"A field trial was recently conducted in the Eagle Ford Shale, across 45 wells completed with similar design criteria, minerology, and frac fluid design, to test performance of the fracturing fluid surfactant selected in our lab via a new technique\u2014Rock-on-a-Chip™ microfluidic device. This technique allows most geometric features observed in shale formations to be recreated digitally through photolithography and etching methods onto the \u201cfingernail-sized\u201d device, for the purpose of investigating fracturing fluid invasion, flowback and hydrocarbon recovery during well stimulation.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Texas-ROC-Device-Efficiently-Evaluates-Effects-Surfactants-H012889.pdf","docCreatedDate":"2018-07-10T23:30:00.000-05:00","modifiedDate":"2018-07-10T23:30:00.000-05:00","docdate":"2018-07-10T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Low_Initial_Production,Chemical_Services:High_Failure_Rates:Surfactants-Multi-chem,"},{"title":"Multi-Chem Delivers Superior Local Service with MultiSweet<sup>®<\/sup> H<sub>2<\/sub>S Scavenging and NGL Conditioning","description":"H<sub>2<\/sub>S levels rose as high as 450 ppm and the operator was unable to sell the gas to the pipeline company, which has a stringent spec limit of up to 4 ppm of H<sub>2<\/sub>S in the gas stream. ","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/MultiSweet-H2S-Scavenging-Rocky-Mountain-H011851.pdf","docCreatedDate":"2015-10-22T23:30:00.000-05:00","modifiedDate":"2015-10-22T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:35.706-05:00","docdate":"2015-10-22T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:H2S_Issues,Chemical_Services:Corrosion_Issues,"},{"title":"Unique Matrix Treatment Boost Production 26 Percent in Mature Asset in Latin America Region","description":"In mature oilfields, production can decline as fields are affected by the presence of water, resulting in increased production costs. This was the case of Mexico\u2019s Cantarell field, an aging offshore field in the Bay of Campeche.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Unique-Matrix-Treatments-Boost-Production-H011720.pdf","docCreatedDate":"2015-04-20T23:30:00.000-05:00","modifiedDate":"2015-04-20T23:30:00.000-05:00","docdate":"2015-04-20T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,Deepwater,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Scale_Deposits,Stimulation:Acidizing:Scale_Control,Chemical_Services:Flowline_Issues:Scale_Inhibitors,"},{"title":"SeaWave Service Chemical-Free Water Treatment Enables Safe Discharge in Strictly Regulated Offshore Environment","description":"In offshore wells, Southern Brazil, where environmental regulations are among the strictest and rig costs among the highest in the world, one Major Operator is using the SeaWave service from Multi-Chem, a Halliburton Service, to successfully treat flowback and production water for safe and compliant discharge from a number of platforms.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/SeaWave-Offshore-Southern-Brazil.pdf","docCreatedDate":"2014-12-23T22:30:00.000-06:00","modifiedDate":"2014-12-23T22:30:00.000-06:00","docdate":"2014-12-23T22:30:00.000-06:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|brandgroups:Multichem,|locations:Global,|prodgroups:Stimulation:Water_Solutions,Chemical_Services:Offshore_Water_Solutions,"},{"title":"Combination Multi-Chem Biocide System Used to Cost-Effectively Save 650,000 Gallons of Water for Re-Use","description":"An operator located in Wheeler, Texas encountered a sudden, emergency bridge plug leak, forcing them to postpone an imminent fracturing treatment for one month during repairs. This unforeseen delay meant that the ready-to-go frac water would be left standing for approximately 30 days in 31 frac tanks on location.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Biocide-Eradicates-Acid-Producing-Bacteria-Frac-Water-H012601.pdf","docCreatedDate":"2017-06-14T23:30:00.000-05:00","modifiedDate":"2017-06-14T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:37.769-05:00","docdate":"2017-06-14T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Bacteria_Related_Issues:Biocides,"},{"title":"Multi-Chem Thermal Imaging Leads to Effective Treatment for Paraffin Buildup","description":"The terminus of the Lynch system line into the Hobbs Station has an approximately 3-foot dead area behind the booster pump injection\nfor the line, where lack of routine flow increases the likelihood of paraffin and asphaltene solids deposition and subsequent corrosion risk from under deposit attacks.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Midstream-Hobbs-Chem-Thermal-Imaging.pdf","docCreatedDate":"2015-04-08T23:30:00.000-05:00","modifiedDate":"2015-04-08T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:33.583-05:00","docdate":"2015-04-08T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Midstream_Solutions,"},{"title":"Bakken Operator Reduces Water Injection by 76%","description":"Multi-Chem worked with a Bakken operator to address a severe salt deposition issue. After relying on high volume fresh water continuous treatments to maintain normal production, a patented halite control product, MX 2-3875, was introduced to control salt precipitation and reduce the required fresh water volumes.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Halite-Inhibitor-Bakken-Operator-Reduces-Water-Injection-H012591.pdf","docCreatedDate":"2017-06-14T23:30:00.000-05:00","modifiedDate":"2017-06-14T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:37.769-05:00","docdate":"2017-06-14T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Unconventional_Resources,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Scale_Deposits,Chemical_Services:Flowline_Issues:Scale_Inhibitors,Stimulation:Acidizing:Scale_Control,"},{"title":"Unconventional Corrosion Protection Solution Includes Monitoring Assistance in \u2018Problem Area\u2019","description":"One of the country\u2019s largest natural gas distributors needed to clean a 20\u201d dry-gas pipeline and protect it from corrosion without sacrificing the gas quality. When Multi-Chem was challenged to provide a solution, it was determined that any treatment would require oil soluble chemicals in order to maintain dry-gas specs and still be effective. ","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Midstream-North-Louisiana-Unconv-Corrosion.pdf","docCreatedDate":"2015-03-26T23:30:00.000-05:00","modifiedDate":"2015-03-26T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:34.250-05:00","docdate":"2015-03-26T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Midstream_Solutions,"},{"title":"Multi-Chem Identifies Cost-Effective Solvent Solutions for More Efficient Line Pigging","description":"After a cleaning of 1.78 miles of 6\u201d pipe produced a 7-foot paraffin plug at the end of the line, this Midland operator asked Multi-Chem to conduct a solvency test to find a solvent product that would decrease the amount of soluble paraffin solids in the line to improve pigging efficiency.","path":"/content/dam/ps/public/multichem/contents/Case_Histories/web/Midstream-Midland-Cost-Effective-Solvent-Solution.pdf","docCreatedDate":"2015-03-31T23:30:00.000-05:00","modifiedDate":"2015-03-31T23:30:00.000-05:00","publishDate":"2018-10-02T11:21:34.250-05:00","docdate":"2015-03-31T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|brandgroups:Multichem,|locations:Global,|prodgroups:Chemical_Services:Midstream_Solutions,"},{"title":"InnerVue™ PipeSuite Survey Accurately Predicts Stuck Pig Location Within 0.4%","description":"Halliburton Pipeline and Process\nServices was contracted to conduct\nInnerVue™ PipeSuite surveys on a 16-in. crude oil pipeline located 125 miles offshore in the Gulf of Thailand. 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Halliburton's flange management system assures that all flanges are identified and have been mechanically completed in a controlled manner that helps minimize or eliminate integrity-related issues, such as leaks, at startup.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/Worlds-Largest-Floating-Liquefied-Natural-Gas-VesselH012641.pdf","docCreatedDate":"2018-03-21T23:30:00.000-05:00","modifiedDate":"2018-03-21T23:30:00.000-05:00","docdate":"2018-03-21T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|locations:Global,|prodgroups:Pipeline_and_Process_Services:Precommissioning_&_Commissioning,Pipeline_and_Process_Services:Process_Services:Process_Precommissioning_&_Commissioning,"},{"title":"Operator Quickly Diagnoses Root Cause of Back Pressure in Pipeline","description":"The operator of a crude oilfield located in the Bombay Offshore Basin, 60-90km from Mumbai, India, needed to get to the root cause of pipeline back pressure that was adversely impacting production, by greater than 25% throughput reduction, after months of pipeline flow deterioration.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/India-Operator-Diagnoses-Back-Pressure-Pipeline-H012673.pdf","docCreatedDate":"2018-04-03T23:30:00.000-05:00","modifiedDate":"2018-04-03T23:30:00.000-05:00","publishDate":"2018-10-02T13:09:03.292-05:00","docdate":"2018-04-03T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,Deepwater,|locations:Global,|prodgroups:Pipeline_and_Process_Services:Pipeline_Maintenance_Services,Pipeline_and_Process_Services:Flow_Assurance-PPS:Pipeline_and_Wellbore_Diagnostics,"},{"title":"InnerVue™ PipeSuite Diagnostics Accurately Predicts Stuck Pig Location","description":"The customer was experiencing\na stuck pig in its pipeline, located in North Dakota. This occurred during a routine pigging operation, when a cup pig got stuck in the pipeline\u2014most likely due to the accumulation of paraffin wax in front of the pig.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/USA-ND-Operator-PressureWave-Plan-Stuck-Pig-Retrieval-H012753.pdf","docCreatedDate":"2018-05-23T23:30:00.000-05:00","modifiedDate":"2018-05-23T23:30:00.000-05:00","docdate":"2018-05-23T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Pipeline_and_Process_Services:Flow_Assurance-PPS:Pipeline_and_Wellbore_Diagnostics,Pipeline_and_Process_Services:Pipeline_Maintenance_Services,"},{"title":"Pipeline Operator Gains Key Information on Severe Wax Deposits in Critical Pipeline","description":"The operator of an 8-inch subsea oil\nproduction pipeline, running in daisy-chain fashion from Crathes to the Kittiwake platform in the North Sea, experienced severe pipeline restrictions caused by paraffin wax deposits.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/North-Sea-UK-Pipeline-Operator-Severe-Wax-Deposits-H012675.pdf","docCreatedDate":"2018-04-03T23:30:00.000-05:00","modifiedDate":"2018-04-03T23:30:00.000-05:00","publishDate":"2018-10-02T13:09:04.215-05:00","docdate":"2018-04-03T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,Deepwater,|locations:Global,|prodgroups:Pipeline_and_Process_Services:Pipeline_Maintenance_Services,Pipeline_and_Process_Services:Flow_Assurance-PPS:Pipeline_and_Wellbore_Diagnostics,"},{"title":"Halliburton Pigging Campaign Uses InnerVue™ PipeSuite Diagnostics Service for Efficient Was Removal","description":"An offshore rig owned and operated by a major operator near Sakhalin Island faced a complex clean-out of their multi-phase export pipeline due to a \u201cstuck pig\u201d incident \u2013 just 40 days after the Berkut platform began production. This incident was caused by a build-up of hydrates and wax during the very first operational pig run.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/PressurePulse-pigging-campaign-efficient-wax-removal-H012507.pdf","docCreatedDate":"2018-04-03T23:30:00.000-05:00","modifiedDate":"2018-04-03T23:30:00.000-05:00","docdate":"2018-04-03T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,|locations:Global,|prodgroups:Pipeline_and_Process_Services:Pipeline_Maintenance_Services,Pipeline_and_Process_Services:Flow_Assurance-PPS:Pipeline_and_Wellbore_Diagnostics,"},{"title":"Operator Efficiently Resolves Pigging Complications During Offshore Pipeline Wax Removal","description":"The operator of an offshore UK\n8-in condensate export pipeline\nrunning from the Lomond platform\nto the CATS platform in the North\nSea was initially dealing with\nrestrictions caused by wax buildup\u2014common to many condensates containing dissolved waxes that can precipitate and deposit under certain environmental conditions.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/North-Sea-UK-Operator-Resolves-Pigging-Complications-Pipeline-Wax-Removal-H012672.pdf","docCreatedDate":"2018-04-03T23:30:00.000-05:00","modifiedDate":"2018-04-03T23:30:00.000-05:00","publishDate":"2018-10-02T13:09:03.292-05:00","docdate":"2018-04-03T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Pipeline_and_Process_Services:Flow_Assurance-PPS:Pipeline_and_Wellbore_Diagnostics,Pipeline_and_Process_Services:Pipeline_Maintenance_Services,"},{"title":"Operator Uses Pressure Wave Technology to Accurately Locate Stuck Tool in High-Risk Pipeline","description":"An operator in South Texas was losing valuable production uptime due to an intelligent inspection tool being stuck in one of its pipelines transporting \u2018supercritical\u2019 ethylene\u2014at a temperature and pressure above its critical point.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/USA-Operator-Uses-Pressure-Wave-Technology-Stuck-Tool-H012674.pdf","docCreatedDate":"2018-04-03T23:30:00.000-05:00","modifiedDate":"2018-04-03T23:30:00.000-05:00","publishDate":"2018-10-02T13:09:03.292-05:00","docdate":"2018-04-03T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Pipeline_and_Process_Services:Flow_Assurance-PPS:Pipeline_and_Wellbore_Diagnostics,Pipeline_and_Process_Services:Pipeline_Maintenance_Services,"},{"title":"InnerVue™ WellSuite Diagnostics Accurately Detects Restrictions in Horizontal Well","description":"A multiphase producing well in Vaca Muerta field in the Neuquen province of Argentina was producing sand from a perforated zone in the well\u2019s horizontal section. After about six months of production, the sand was causing a partial blockage in the wellbore and responsible for production inefficiencies.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/Argentina-InnerVue-Detects-Blockage-Horizontal-Well-H013024.pdf","docCreatedDate":"2018-08-20T23:30:00.000-05:00","modifiedDate":"2018-08-20T23:30:00.000-05:00","docdate":"2018-08-20T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,Production_Challenges:Unconventional_Resources,|locations:Global,|prodgroups:Pipeline_and_Process_Services:Pipeline_Maintenance_Services,Pipeline_and_Process_Services:Flow_Assurance-PPS:Pipeline_and_Wellbore_Diagnostics,"},{"title":"InnerVue™ WellSuite Survey Precisely Locates Blockage","description":"Halliburton Sakhalin Limited was contracted by a Major Operator to perform a InnerVue™ WellSuite survey in annular space between the 9-5/8-in. and 7-in. casings. This annulus was being used in normal operation to inject water into the waste disposal well (WDW)\u2014located at the wellsite in the remote region of northeastern Russia.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/Russia-Analyze-Sand-Blockage-Water-Injection-H012752.pdf","docCreatedDate":"2018-05-23T23:30:00.000-05:00","modifiedDate":"2018-05-23T23:30:00.000-05:00","docdate":"2018-05-23T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Pipeline_and_Process_Services:Flow_Assurance-PPS:Pipeline_and_Wellbore_Diagnostics,Pipeline_and_Process_Services:Pipeline_Maintenance_Services,"},{"title":"InnerVue™ PipeSuite Surveys Used for Comparative Analysis","description":"Two InnerVue™ PipeSuite surveys were carried out onboard the offshore platform in the Gulf of Mexico. The first survey operation was to establish a baseline of the wax deposition accumulated inside a 12-in. export oil pipeline\u2014running from the platform out to the Gathering\n\u2018Y\u2019 tie-in.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/GOM-Operator-Measures-Impact-Pipeline-Remediation-Treatment-H012754.pdf","docCreatedDate":"2018-06-06T23:30:00.000-05:00","modifiedDate":"2018-06-06T23:30:00.000-05:00","docdate":"2018-06-06T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Pipeline_and_Process_Services:Pipeline_Maintenance_Services,Pipeline_and_Process_Services:Flow_Assurance-PPS:Pipeline_and_Wellbore_Diagnostics,"},{"title":"FiberLog™ Service Provides Real-Time Analysis During Fluid Injection","description":"FIBER-OPTIC-ENABLED WIRELINE SOLUTION EVALUATES\nFLUID DISTRIBUTION ACROSS WELLBORE OF INJECTION WELL","path":"/content/dam/ps/public/pinnacle/contents/Case_Histories/web/FiberLog-Service.pdf","docCreatedDate":"2017-05-23T23:30:00.000-05:00","modifiedDate":"2017-05-24T23:30:00.000-05:00","docdate":"2017-05-23T23:30:00.000-05:00","docrefNum":"H012557","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Production_Optimization,|locations:Global,|prodgroups:Reservoir_Testing_&_Analysis_(Reservoir_Testing_&_Sampling):Reservoir_Performance_Monitoring:Fiber_Optic_Distributed_Temperature_Systems,Reservoir_Testing_&_Analysis_(Reservoir_Testing_&_Sampling):Reservoir_Performance_Monitoring:Fiber_Optic_Monitoring,Reservoir_&_Fracture_Monitoring:Fiber_Optic_Monitoring-Pinnacle,Reservoir_&_Fracture_Monitoring:Fiber_Optic_Monitoring-Pinnacle:Retrievable_Fiber_Optic_Services,Reservoir_&_Fracture_Monitoring:Fiber_Optic_Monitoring-Pinnacle:Fiber_Optic_Interrogators,Reservoir_&_Fracture_Monitoring:Fiber_Optic_Monitoring-Pinnacle:Distributed_Fiber_Optic_Services,"},{"title":"Breakthrough Technologies: CleanStream Service","description":"New ultraviolet light technology controls bacteria while reducing environmental risks. ","path":"/content/halliburton/en-US/ps/solutions/breakthrough-technologies-cleanstream-service.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Environmental_Challenges:Water_Management-Environmental_Challenge,|locations:Global,"},{"title":"Pore Pressure Prediction and Real-Time Monitoring and Analysis","description":"HpHt wells are typically drilled with a very narrow operating envelope between the mud and fracture gradients.","path":"/content/halliburton/en-US/ps/solutions/drill-bits/pore-pressure-prediction-and-real-time-monitoring-and-analysis.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Drilling_Challenges:Precise_Well_Placement,Reducing_Costs,Formation_Challenges:Low_Permeability_Formations,Fluids_Challenges:Fluid_Loss,Fluids_Challenges:Wellbore_Breathing_and_Ballooning,Drilling_Challenges:Increased_ROP,Drilling_Challenges:Optimize_Drilling_Conditions,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|locations:Global,"},{"title":"Reduce Nonproductive Completion Time and Increase Production Using Flow-Through Composite Frac Plugs (FTCFPs)","description":"Flow-through composite frac plugs (FTCFPs) can serve as an effective alternative to traditional isolation methods or to induced stress diversion. FTCFPs allow all zones to produce during the completion so that that no zones are shut-in for long periods. In addition, zones do not have to be killed after clean-up and when the bottomhole flowing pressure is reduced during flowback, previously treated zones contribute to the clean-up of each new treatment. FTCFP use can significantly improve completion efficiency, relative to traditional isolation methods, and improve production rates.","path":"/content/halliburton/en-US/ps/solutions/mature-fields/project-experience/reduce-nonproductive-completion-time-and-increase-production-using-flow-through-composite-frac-plugs-ftcfps.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Optimally_Place_Fractures,Production_Challenges:Horizontal_Completions,Reservoir_Challenges:Mature_Fields,Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Thin_Zones,Reservoir_Challenges:Long_Pay_Interval,Reservoir_Challenges:Improve_Reservoir_Drainage,|locations:Global,"},{"title":"Microseismic Utilized in the Wilcox Sand, Burgos Basin, Northern Mexico","description":"Pemex is actively developing the Wilcox tight-gas sands in the Arcabu-Culebra Field in the Burgos Basin, Northern Mexico.","path":"/content/halliburton/en-US/ps/solutions/mature-fields/project-experience/microseismic-utilized-in-the-wilcox-sand-burgos-basin-northern-mexico.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Horizontal_Completions,Reservoir_Challenges:Mature_Fields,Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Thin_Zones,Reservoir_Challenges:Long_Pay_Interval,Reservoir_Challenges:Improve_Reservoir_Drainage,Production_Challenges:Optimally_Place_Fractures,|locations:Global,"},{"title":"Precise Fracture Placement Increases Production and Optimizes Reservoir Drainage","description":"Without proper isolation methods, fracturing uncased horizontal wells is impractical. The SurgiFracÆ service provides fast and precise placement of fractures in deviated and horizontal wellbores without requiring mechanical or chemical plugs to isolate fracture treatments. Multiple fractures can be created within a few hours. The technique is a combination of three separate processes: hydrajetting, hydraulic fracturing, and coinjection down the annulus. Frac treatment costs are re-duced because the low fracture tortuosity inherent in the process requires less equipment and lower viscosity fluids.","path":"/content/halliburton/en-US/ps/solutions/mature-fields/project-experience/precise-fracture-placement-increases-production-and-optimizes-reservoir-drainage.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Optimally_Place_Fractures,Production_Challenges:Horizontal_Completions,Reservoir_Challenges:Mature_Fields,Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Thin_Zones,Reservoir_Challenges:Long_Pay_Interval,Reservoir_Challenges:Improve_Reservoir_Drainage,|locations:Global,"},{"title":"Multistage Pinpoint Fracturing in Low-Permeability Formations Lost Hills Field, California","description":"The pinpoint fracturing (PPF) method creates perforations by pumping abrasive slurry down coiled tubing through a jetting nozzle while the main treatment is pumped down the annulus casing/coiled-tubing annulus. Sand plugs are used to achieve isolation between fracture treatments. Application of the pinpoint stimulation technique for multistage fracturing in the Lost Hills field, California, vertical well, significantlyimproved production and reduced completion costs. Porosity in the low-permeability Belridge Diatomite reservoirs is high, 45 to 65%, but permeability ranges from 0.1 to 100 md. Previously, emphasis had been placed on reducing fracture treatment costs by pumping fewer stages and lower proppant volumes to stimulate approximately 1000 ft of net pay, but this resulted in a decrease in cumulative production. Tests using an increased number of fracture stages did not improve economics because of the increased fracturing costs and minimalproduction increases. A pilot test compared the pinpoint fracturing technique performed on 14 wells with the standard perf-and-bridge plug method in 26 wells. The same fracturingparameters, fluid volumes and types, and chemicals were used to keep the basic fracture design the same.","path":"/content/halliburton/en-US/ps/solutions/mature-fields/project-experience/multistage-pinpoint-fracturing-in-low-permeability-formations-lost-hills-field-california.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Horizontal_Completions,Reservoir_Challenges:Mature_Fields,Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Thin_Zones,Reservoir_Challenges:Long_Pay_Interval,Reservoir_Challenges:Improve_Reservoir_Drainage,Production_Challenges:Optimally_Place_Fractures,|locations:Global,"},{"title":"Water Management Glossary","description":"Water Management Definitions","path":"/content/halliburton/en-US/ps/solutions/clean-energy/oilfield-water-management/about-water-management/water-management-glossary.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Environmental_Challenges:Water_Management-Environmental_Challenge,|locations:Global,"},{"title":"Reducing Water Rates to Increase Hydrocarbon Rates\u2014Cooper Basin, Australia","description":"Identify wells, treatment designs, and placement techniques where conformance work would directly increase hydrocarbon rates while reducing the water rate. ","path":"/content/halliburton/en-US/ps/solutions/clean-energy/oilfield-water-management/project-experience/reducing-water-rates.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Environmental_Challenges:Water_Management-Environmental_Challenge,|locations:Global,"},{"title":"Massive Growth in Water Production Demands an Integrated Approach to Manage Disposal Needs (North Kuwait)","description":"The fields of North Kuwait are experiencing the growing water production associated with all maturing fields. The anticipated increase in water production is expected to be three fold within four years. ","path":"/content/halliburton/en-US/ps/solutions/clean-energy/oilfield-water-management/project-experience/water-production-demands.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Environmental_Challenges:Water_Management-Environmental_Challenge,|locations:Global,"},{"title":"Waterflood Conformance Study for a Carbonate Reservoir (West Kuwait)","description":"The Minagish Oolite is an undersaturated carbonate reservoir in the Minagish field area in West Kuwait containing several billion barrels of oil. The field was discovered in 1959 and is a mature field. ","path":"/content/halliburton/en-US/ps/solutions/clean-energy/oilfield-water-management/project-experience/waterflood-conformance-study.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Environmental_Challenges:Water_Management-Environmental_Challenge,|locations:Global,"},{"title":"24% Increase in ROP, Reduced Formation Evaluation and Rig Costs in a High-Temperature (160°C) Well","description":"An operator in the central sector of the UK North Sea was interested in using rotary-steerable drilling in their HPHT field appraisal drilling campaign. ","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/reduced-formation-evaluation-and-rig-costs-in-a-high-temperature.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Construction_Challenges:Frac_Gradient,Formation_Challenges:Anisotropic_Formations,Formation_Challenges:Low_Permeability_Formations,|locations:Global,"},{"title":"Acoustic LWD Provides Cost-Effective Wireline Quality Reservoir Characterization in Gas Condensate Field","description":"Drilling hazards, such as overpressure or borehole instability, are commonly experienced in tight-gas formations. Using acoustic logging data available in real time for gas detection, to determine the optimal-mud weight, and for look ahead predictions based on correlation with predrill seismic data, these hazards can generally be avoided. In addition, the wireline logging of the horizontal wells used to develop these reservoirs frequently requires costly pipe-conveyance methods and lower-cost alternatives are desirable.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/acoustic-lwd-in-gas-condensate-field.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Construction_Challenges:Frac_Gradient,Formation_Challenges:Anisotropic_Formations,Formation_Challenges:Low_Permeability_Formations,|locations:Global,"},{"title":"Achieving Successful Cement Slurry Placement","description":"This section contains a brief abstract of papers discussing the application of products used for displacing the drilling fluid andplacing the cement slurry in the annulus, such as, OptiCem, Displace3D and Tuned Spacer. 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","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/cement-sheath-integrity.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Control_Challenges:Annulus_Gas_Migration,Production_Challenges:Long_Term_Zonal_Isolation,Fluids_Challenges:Displacements_Effective_Displacements,Formation_Challenges:Low_Permeability_Formations,Production_Challenges:Improve_Wellbore_Integrity,Well_Control_Challenges:Ensure_Well_Integrity,|locations:Global,"},{"title":"Crossed-Dipole Shear-Wave Logs Optimize Pre-Job Fracture Analysis and Post-Job Evaluation","description":"HOCOL ran the crossed-dipole sonic tool inside casing, before and after sandstone hydraulic fracturing jobs in two wells in Columbia, to evaluate changes in anisotropy due to the treatment.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/crossed-dipole-shear-wave-logs-optimize-pre-job-fracture-analysis-and-post-job-evaluation.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Construction_Challenges:Frac_Gradient,Formation_Challenges:Anisotropic_Formations,Formation_Challenges:Low_Permeability_Formations,|locations:Global,"},{"title":"Engineered WaterFrac Service for Ultra-Low-Permeability Formations","description":"New technologies are increasing the effectiveness of water-frac treatments resuting in longer-term production increases. Water-frac treatments normally use friction-reduced water as the fracturing fluid and use small amounts of proppant. A new micro-emulsion surfactant, GasPerm 1000TM, improves production and gets gas on-line faster and at higher rates. The major benefits include 1) reduced fracture-facedamage due to phase trapping in ultra-low-permeability formations, and 2) improved environmental performance because the surfactant contains no phenols.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/engineered-waterfrac-service.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Thin_Zones,Reservoir_Challenges:Long_Pay_Interval,Reservoir_Challenges:Improve_Reservoir_Drainage,Production_Challenges:Optimally_Place_Fractures,Production_Challenges:Horizontal_Completions,Reservoir_Challenges:Mature_Fields,|locations:Global,"},{"title":"Effective Management of Borehole and Formation Pressures Increases Drilling Efficiency and Reduces NPT","description":"Pressure-maintenance problems represent a very large percentage of all nonproductive time (NPT).","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/management-of-borehole-and-formation-pressures.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Drilling_Challenges:Optimize_Drilling_Conditions,Reservoir_Challenges:Improve_Reservoir_Drainage,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),Drilling_Challenges:Precise_Well_Placement,Formation_Challenges:Low_Permeability_Formations,Drilling_Challenges:Increased_ROP,|locations:Global,"},{"title":"Identifying Wet Versus Gas Charge Reservoir","description":"The reservoir fluids in this well are gas (specific gravity of 0.68) and water (salinity of 25,000 ppm NaCl). 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","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/rapid-determination.html","docCreatedDate":"2013-05-03T00:00:30.000+08:30","modifiedDate":"2013-05-03T00:00:30.000+08:30","docdate":"2013-05-03T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Exploration_&_Seismic_Challenges,Formation_Challenges:Low_Permeability_Formations,Real_Time_Decisions,|locations:Global,"},{"title":"Microseismic Provides Drainage and Fracturing Optimization Data","description":"The Cotton Valley tight-gas sands in the Oakhill and Carthage fields, east Texas, found between 8,000 ft and 11,000 ft, have permeabilities ranging from 0.005\u20130.01 md. Successive infill drilling programs and subsequent reservoir depletion (pore pressure gradients of 0.3 to 0.4 psi/ft) necessitated a change from the massive hydraulic fracture treatments that had been typical, tolower-cost completions. However, pumping smaller fracs had unfavorable results. Pinnacle engineers working with Union Pacific Resources (UPR), now Anadarko Petroleum Corp., studied, hydromechanical response, core, production and fracture performance and determined that the Cotton Valley was an excellent candidate for waterfracs, fracture treatments using treated water and very low proppant concentrations.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/microseismic-provides-drainage-and-fracturing-optimization-data.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Horizontal_Completions,Reservoir_Challenges:Mature_Fields,Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Thin_Zones,Reservoir_Challenges:Long_Pay_Interval,Reservoir_Challenges:Improve_Reservoir_Drainage,Production_Challenges:Optimally_Place_Fractures,|locations:Global,"},{"title":"Improved Bit Reliability Saves 21.5 hr and $26,552","description":"In the Loma La Lata Field in Latin America, drilling offset wells through the 12-1/4-in., 8-3/4-in., and 6-1/8-in. hole sections required an average of 290 hr.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/improved-bit-reliability-saves.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Drilling_Challenges:Precise_Well_Placement,Reducing_Costs,Formation_Challenges:Low_Permeability_Formations,Fluids_Challenges:Fluid_Loss,Fluids_Challenges:Wellbore_Breathing_and_Ballooning,Drilling_Challenges:Increased_ROP,Drilling_Challenges:Optimize_Drilling_Conditions,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|locations:Global,"},{"title":"Formation Pressure Testing and Sampling Provides Guidance on Risks, Formation Data and Fluid Identification","description":"After a completion failed on the original well in Mexico, the well needed to be redrilled into the reservoir. 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","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/whole-rock-chemostratigraphy-resolves-complex-stratigraphy.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Formation_Challenges:Anisotropic_Formations,Formation_Challenges:Low_Permeability_Formations,Well_Construction_Challenges:Frac_Gradient,|locations:Global,"},{"title":"Integrated Field Studies Help Asset Teams Make Optimal Field Development Decisions \u2013 Consulting","description":"A horizontal well was drilled in the low-permeability Ellenberger Formation in a field located in Edwards County, Texas.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/integrated-field-studies-help-asset-teams.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Formation_Challenges:Low_Permeability_Formations,Real_Time_Decisions,|locations:Global,"},{"title":"Preventing Sealing Problems, Improves Integrity, and Reduces NPT in Liner Completions","description":"Conventional liner-top packers are prone to failure due to problems in obtaining a good primary cement seal at the top of the liner.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/preventing-sealing-problems-improves-integrity-and-reduces-npt.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Control_Challenges:Annulus_Gas_Migration,Production_Challenges:Long_Term_Zonal_Isolation,Fluids_Challenges:Displacements_Effective_Displacements,Formation_Challenges:Low_Permeability_Formations,Production_Challenges:Improve_Wellbore_Integrity,Well_Control_Challenges:Ensure_Well_Integrity,|locations:Global,"},{"title":"Holistic asset evaluation for 18 connected onshore and offshore fields resulted in a 40% NPV","description":"The challenge was to determine an optimal development plan for 18 connected fields onshore and offshore. 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A customer wanted to steer a well accurately to its narrow target in less time than previous wells in the area.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/economical-rotary-steerable-bha-custom-designed-for-the-formation.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Drilling_Challenges:Precise_Well_Placement,Formation_Challenges:Low_Permeability_Formations,Drilling_Challenges:Increased_ROP,Drilling_Challenges:Optimize_Drilling_Conditions,Reservoir_Challenges:Improve_Reservoir_Drainage,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|locations:Global,"},{"title":"Sustaining Fracture Conductivity in Tight-Gas Reservoirs Increases Cumulative Production (68-272%)","description":"In tight-gas completions, rapid post-fracture production decline is typically associated with loss of fracture conductivity, especiallyin high-temperature/high-stress wells.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/sustaining-fracture-conductivity.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Production_Optimization,Formation_Challenges:Low_Permeability_Formations,Production_Challenges:Control_of_Water_and_Gas_Production,Production_Challenges:Produced_Water,|locations:Global,"},{"title":"Lost Circulation Treatment in Gas Sand Saved $250,000 in Rig Time","description":"The operator experienced total lost returns at 12,700 ft while drilling a 6.5-in. sidetrack liner section hole with 15.5 ppg mud weight. ","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/lost-circulation-treatment-in-gas-sand.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Formation_Challenges:Low_Permeability_Formations,Fluids_Challenges:Fluid_Loss,Fluids_Challenges:Barite_Sag,Fluids_Challenges:Hole_Cleaning_Cuttings_Removal,Fluids_Challenges:ROP_Enhancement,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|locations:Global,"},{"title":"Generating Openhole Logs from Cased-Hole PNL Data Fills In Missing Data, Optimizes Drilling and Completions, Reduces Openhole Drilling Costs, Risk and NPT","description":"A variety of drilling situations and borehole conditions, tool pulls, and sensor failure may result in acquisition of inaccurate or unreliable log data in a zone or interval, and in extreme cases, may prevent acquisition or openhole data entirely.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/generating-openhole.html","docCreatedDate":"2013-05-03T00:00:30.000+08:30","modifiedDate":"2013-05-03T00:00:30.000+08:30","docdate":"2013-05-03T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Construction_Challenges:Frac_Gradient,Formation_Challenges:Anisotropic_Formations,Formation_Challenges:Low_Permeability_Formations,|locations:Global,"},{"title":"Magnetic Resonance T2 Logging Provides Improved Reservoir Description in Low-Permeability Formations","description":"In low-permeability and mineralogically complex reservoirs, e.g., low-resistivity low-contrast pay and/or tight-gas sandstones, estimates of reservoir water saturation based on conventional log analysis are frequently inaccurate due to (1) unknown or variable pore-water salinities and (2) the effect of the nonproducible bound (irreducible) water contained in the microporosity, e.g., the clays comprising the shales. In these cases, identification of pay can be difficult and when identified, it is not clear which reservoirs will produce water-free hydrocarbons or produce at all because of high irreducible water saturations, low permeability or both.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/magnetic-resonance-t2-logging.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Construction_Challenges:Frac_Gradient,Formation_Challenges:Anisotropic_Formations,Formation_Challenges:Low_Permeability_Formations,|locations:Global,"},{"title":"Dual-Well Monitoring Enhances Microseismic Imaging of Hydraulic-Fracture Stimulation","description":"In long laterals, a single monitoring well may not detect microseisms over the entire well. The use of two monitoring wells improves detection over the entire length of the lateral well. To achieve optimal production in tight-gas fields, microseismic monitoring is used to monitor the effectiveness of hydraulic fracture stimulations. Deformation associated with the stimulation, results in small magnitude micro-earthquakes whose locations are used to image the growth and geometry of the stimulated fracture network. This technique provides unique information for improving the stimulation design. Generally, receiver arrays are placed in a single observation well to record the micro-earthquakes. In long horizontal boreholes improved seismic detection and imaging can be obtained using data from additional observation wells.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/dual-well-monitoring-enhances-microseismic-imaging.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Horizontal_Completions,Reservoir_Challenges:Mature_Fields,Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Thin_Zones,Reservoir_Challenges:Long_Pay_Interval,Reservoir_Challenges:Improve_Reservoir_Drainage,Production_Challenges:Optimally_Place_Fractures,|locations:Global,"},{"title":"Lost-Circulation Treatment Stopped Losses in Deep HPHT Gas Pay Zone","description":"A Canadian operator controlled losses and a significant H<sub>2<\/sub>S kick in a deep well using HYDRO-PLUG Hydrating Lost Circulation Treatment dual-action lost circulation material. The severe losses were encountered while drilling through a high-pressure, deep gas pay zone in the foothills of west-central Alberta. ","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/lost-circulation-treatment-stopped-losses.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Formation_Challenges:Low_Permeability_Formations,Fluids_Challenges:Fluid_Loss,Fluids_Challenges:Barite_Sag,Fluids_Challenges:Hole_Cleaning_Cuttings_Removal,Fluids_Challenges:ROP_Enhancement,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|locations:Global,"},{"title":"Footage, ROP and Cost Outperformance in Tight Sandstone Field in Oklahoma","description":"QuadPack™ Plus bit performance in an eastern Oklahoma tight sandstone field outperformed competitor bits by wide margins in drilled footage (66%), ROP (35%), and cost per foot (29%). 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Saudi Aramco faced a big stimulation challenge in a new field where reservoir temperatures reached 375°F (191°C) and pressures exceeded 15,000 psi. However, the problem is greater than just this individual well.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/fluid-system-enables-effective-stimulation.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Horizontal_Completions,Reservoir_Challenges:Mature_Fields,Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Thin_Zones,Reservoir_Challenges:Long_Pay_Interval,Reservoir_Challenges:Improve_Reservoir_Drainage,Production_Challenges:Optimally_Place_Fractures,|locations:Global,"},{"title":"Optimization of Wellbore Placement, Maximization of Production and Extending Field Life","description":"The inability of conventional LWD resistivity devices to identify directional differences makes geosteering in the pay zone unpredictable and risky. 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Nonproductive time (NPT) accounts for approximately 20% of all rig time and can be much higher in difficult fields.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/drilling-optimization-improves-drilling-performance.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Drilling_Challenges:Precise_Well_Placement,Reducing_Costs,Formation_Challenges:Low_Permeability_Formations,Fluids_Challenges:Fluid_Loss,Fluids_Challenges:Wellbore_Breathing_and_Ballooning,Drilling_Challenges:Increased_ROP,Drilling_Challenges:Optimize_Drilling_Conditions,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|locations:Global,"},{"title":"Identifying Gas vs. Water in a Tight-Gas Reservoir in Mexico","description":"Permeability is one of the critical parameters used to characterize overpressured tight-gas reservoirs and to determine the best fracture design for maximizing gas recovery. 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Data from a single well in which conventional logs, conventional and NMR core analyses and NMR logs were available for the reservoir under study were used to develop a petrophysical model.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/identifying-gas-vs-water-in-a-tight-gas-reservoir-in-mexico.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Well_Construction_Challenges:Frac_Gradient,Formation_Challenges:Anisotropic_Formations,Formation_Challenges:Low_Permeability_Formations,|locations:Global,"},{"title":"Determining the best option to develop large field saves large volumes of capital and time in tight-gas field","description":"A Piceance basin operator was attempting to develop the risk-management program for over 3,000 wells.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/develop-large-field-saves.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Exploration_&_Seismic_Challenges,Formation_Challenges:Low_Permeability_Formations,Real_Time_Decisions,|locations:Global,"},{"title":"Clay-Free Diesel-Based Fluid Provided Superior Wellbore Stability in Horizontal Sand Test and Helped Operator Avoid Sidetracking","description":"Initial efforts to drill an eight-well horizontal project in the Permian Basin Bone Springs sand were unsuccessful. ","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/clay-free-diesel-based-fluid.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Formation_Challenges:Low_Permeability_Formations,Fluids_Challenges:Fluid_Loss,Fluids_Challenges:Barite_Sag,Fluids_Challenges:Hole_Cleaning_Cuttings_Removal,Fluids_Challenges:ROP_Enhancement,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|locations:Global,"},{"title":"Hostile-Environment Wireline Formation Tester Reduces NPT in HPHT Boreholes","description":"The extreme conditions and small borehole diameters typical of HPHT make wireline formation testing a challenge.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/hostile-environment-wireline-formation-tester-reduces-npt.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Formation_Challenges:Low_Permeability_Formations,Formation_Challenges:Sandstone_Formations,Formation_Challenges:Uncertain_Mineralogy,|locations:Global,"},{"title":"Optimizing Field-Wide Fracture Stimulation","description":"The remote Frac is a new concept for optimizing the efficiency of conventional hydraulic fracture stimulation operations in fieldswhere well-spacing requirements and completion schedules involve large amounts of manpower, equipment and material, e.g.,tight-gas hydraulic fracturing.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/optimizing-field-wide-fracture-stimulation.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Drilling_Challenges:Complex_Well_Trajectories,Drilling_Challenges:Improving_Drilling_Efficiency,Production_Challenges:Unconventional_Resources,Reducing_Costs,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Improve_Reservoir_Drainage,|locations:Global,"},{"title":"Cumulative Production Gain Exceeding 50% Using Chemically Treating Proppant","description":"Production rates from four offset wells were compared. The completions were similar with the exception of one that had the proppant treated with a conductivity enhancement chemical. Compared to the average production from the other three wells, the SandWedge treated conductivity enhancer proppant well produced more initially, maintained higher production and produced 50% more cumulative.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/cumulative-production-gain.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Horizontal_Completions,Reservoir_Challenges:Mature_Fields,Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Thin_Zones,Reservoir_Challenges:Long_Pay_Interval,Reservoir_Challenges:Improve_Reservoir_Drainage,Production_Challenges:Optimally_Place_Fractures,|locations:Global,"},{"title":"Clay-Free Diesel Based fluid and Engineered Wellbore Strengthening Technology Promote Successful Drilling through Severely Depleted Sands for $250,000 Savings","description":"The operator wanted to drill a 6-in. hole through severely depleted sands without losing returns. ","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/clay-free-diesel-based-fluid-and-engineered-wellbore-strengthening-technology.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Formation_Challenges:Low_Permeability_Formations,Fluids_Challenges:Fluid_Loss,Fluids_Challenges:Barite_Sag,Fluids_Challenges:Hole_Cleaning_Cuttings_Removal,Fluids_Challenges:ROP_Enhancement,Fluids_Challenges:Controlling_Equivalent_Circulating_Density_(ECD),|locations:Global,"},{"title":"Accurately Predict the Outcome of Production Enhancement Efforts","description":"Integration of reservoir description (petrophysics), reservoir performance and simulations are used to predict the outcome of production-enhancement efforts on reservoir performance and optimize the financial investment based on the economics of the treatment. MRIL logs and conventional logs are used to zone potential completion intervals and identify reservoir production haracteristics: hydrocarbon type and provide accurate determinations of porosity, permeability, clays and movable fluid volumes.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/accurately-predict-the-outcome-of-production-enhancement.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Horizontal_Completions,Reservoir_Challenges:Mature_Fields,Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,Formation_Challenges:Low_Permeability_Formations,Reservoir_Challenges:Thin_Zones,Reservoir_Challenges:Long_Pay_Interval,Reservoir_Challenges:Improve_Reservoir_Drainage,Production_Challenges:Optimally_Place_Fractures,|locations:Global,"},{"title":"Boost Production (30%), Reduce Time to Production (68%), and Reduce Proppant Flowback","description":"Proppant flowback into the wellbore reduces the width of the fracture channels, and the loss of proppant from the fractures limitsthe flow-channel conductivity, impairing the effectiveness of the fracture treatment.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/boost-production-reduce-time.html","docCreatedDate":"2013-05-01T00:00:30.000+08:30","modifiedDate":"2013-05-01T00:00:30.000+08:30","docdate":"2013-05-01T00:00:30.000+08:30","docrefNum":"","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Production_Challenges:Production_Optimization,Formation_Challenges:Low_Permeability_Formations,Production_Challenges:Control_of_Water_and_Gas_Production,Production_Challenges:Produced_Water,|locations:Global,"},{"title":"3% Reduction in Cost/ft Achieved Using New Bit Designed for Rock Strength and Directional Requirements.","description":"The 8-3/8-in. Hypercut™ bit design was chosen for drilling the horizontal section in a gas well for a major Middle East producer. 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