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This affected the pressure maintenance of the field, resulting in a decline of the reservoir pressure at a higher rate than desired.","path":"/content/dam/ps/public/wd/contents/Case_Histories/H011940-Vietnam.pdf","docCreatedDate":"2018-10-02T11:28:16.681-05:00","modifiedDate":"2015-10-02T23:30:00.000-05:00","publishDate":"2018-10-02T11:28:16.681-05:00","docdate":"2015-10-02T23:30:00.000-05:00","docrefNum":"H011940","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,Workflow_Integration:HalComplete:Deepwater_Completions,Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Intelligent_Completions:Interval_Control-WellDynamics,"},{"title":"eRED® Valve Provides Efficiencies and Time Savings in Downhole Operations","description":"Valve Operates Remotely After 23 Months Down Hole","path":"/content/dam/ps/public/wd/contents/Case_Histories/eRED-Opened-After-23-Months-H012809.pdf","docCreatedDate":"2018-10-02T11:28:19.975-05:00","modifiedDate":"2018-07-25T23:30:00.000-05:00","publishDate":"2018-10-02T11:28:19.975-05:00","docdate":"2018-07-25T23:30:00.000-05:00","docrefNum":"H012809","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,Workflow_Integration:HalComplete:Deepwater_Completions,Deepwater,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Remote_Open_Close_Technology,"},{"title":"eMotion&reg;-LV Barrier Valve Saves 29 Hours Rig Time","description":"Interventions eliminated during packer-setting operations - saving time and removing risk","path":"/content/dam/ps/public/wd/contents/Case_Histories/H011341.pdf","docCreatedDate":"2018-10-02T11:29:33.115-05:00","modifiedDate":"2017-05-26T23:30:00.000-05:00","docdate":"2017-05-26T23:30:00.000-05:00","docrefNum":"H011341","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Reservoir_Challenges:Mature_Fields,|locations:Global,|prodgroups:Completion_Equipment_and_Services:Remote_Open_Close_Technology,"},{"title":"Successful Auto Gas-Lift Using Intelligent Completion Boosted Oil Production","description":"A major customer operating in a mature field in Oman\nhad a few wells that were shut-in due to insufficient\nreservoir pressure to sustain natural flow. 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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":"2018-10-02T11:21:54.072-05:00","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":"2018-10-02T11:21:34.902-05:00","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":"2018-10-02T11:21:36.533-05:00","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":"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":"2018-10-02T11:21:55.204-05:00","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":"2018-10-02T11:21:35.706-05:00","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":"2018-10-02T11:21:49.348-05:00","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":"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":"2018-10-02T11:21:33.583-05:00","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":"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":"2018-10-02T11:21:34.250-05:00","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":"2018-10-02T11:21:34.250-05:00","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. The objective of the survey operation was to locate the position of a pig mandrel stuck in the pipeline.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/Thailand-Operator-Uses-Pressure-Blocked-Pipeline-H012751.pdf","docCreatedDate":"2018-10-02T13:09:10.407-05:00","modifiedDate":"2018-07-30T23:30:00.000-05:00","docdate":"2018-07-30T23:30:00.000-05:00","languageSet":["English"],"accessType":"P","dataSearch":"custchallenges:Deepwater,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":"Removing blockage of a 40-km subsea gas export pipeline offshore Brazil without cutting pipe","description":"Halliburton product service line integrates the services of three sub-PSLs to remove blockage without cutting pipe, saves costs.","path":"/content/dam/ps/public/pps/contents/Case_Histories/web/H011553-BAC-Brazil-Case-Study.pdf","docCreatedDate":"2018-10-02T13:09:03.977-05:00","modifiedDate":"2015-03-02T22:30:00.000-06:00","docdate":"2015-03-02T22:30:00.000-06:00","docrefNum":"H011553","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,Intervention:Coiled_Tubing,Pipeline_and_Process_Services:Pipeline_Maintenance_Services:Pipeline_Precommissioning_&_Commissioning,Pipeline_and_Process_Services:Flow_Assurance-PPS:Pipeline_Remediation,Pipeline_and_Process_Services:Nitrogen_Services,"},{"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":"2018-10-02T13:09:03.292-05:00","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":"2018-10-02T13:09:09.635-05:00","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":"2018-10-02T13:09:04.215-05:00","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":"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":"2018-10-02T13:09:03.292-05:00","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":"2018-10-02T13:09:03.292-05:00","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":"2018-10-02T13:09:10.556-05:00","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":"2018-10-02T13:09:07.949-05:00","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":"2018-10-02T13:09:09.315-05:00","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":"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":"2018-10-02T03:12:53.940-05:00","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":"2018-10-02T03:12:53.882-05:00","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":"2018-10-02T03:12:54.196-05:00","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":"2018-10-02T03:12:54.258-05:00","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":"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":"2018-10-02T03:13:05.621-05:00","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":"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":"2018-10-02T03:13:09.393-05:00","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":"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":"2018-10-02T03:13:05.785-05:00","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":"Completion System Allows Interventionless Stimulation Treatments in Horizontal Wells","description":"While neither of the examples below are tight gas, these technologies are often used in tight gas low permeability wells. Operators often encounter problems in wells with multiple pay zones when attempting to isolate and fracture these zones using conventional openhole completion and stimulation methods. In many cases, conventional completion methods cannot be used because theyallow only partial treatment of a zone. Typically, operators can only perform three or possibly four fracture stages per day in a single well using these methods.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/completion-system-allows-interventionless-stimulation-treatments-in-horizontal-wells.html","docCreatedDate":"2018-10-02T03:13:05.032-05:00","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":"Fluid System Enables Effective Stimulation in Deep, Hot Reservoirs","description":"A new high-temperature, high-density fracturing fluid system, designed by Halliburton\u2019s Saudi Arabia Production Enhancement team, in conjunction with experts in Duncan, Oklahoma, and Houston, recently entered service in Saudi Arabia. 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":"2018-10-02T03:13:07.319-05:00","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":"High-Temperature, Low-Permeability Wells Require Low Gel Frac Fluids to Protect from Formation Damage","description":"A customizable, salt-compatible, low-polymer, organometallic crosslinked-gel (CMHPG) fracturing fluid (The SiroccoSM system) is designed for use in high-temperature wells.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/high-temperature-low-permeability-wells-require-low-gel-frac-fluids.html","docCreatedDate":"2018-10-02T03:13:06.883-05:00","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":"Calibrated Fracture-Growth Models Optimize Fracture Staging in Wells with Large Pay Intervals","description":"The Jonah field in Wyoming is a giant gas field producing from the low-permeability (0.024 md) Lance formation, a 2,800+ ft stacked sequence of 20 to 50 lenticular fluvial channel sands interbedded with associated overbank siltstone and floodplain shaledeposits. Sandstone bodies occur as individual 10- to 25-ft thick channels and stacked-channel sequences greater than 200-ft thick, in some cases. The sands are generally discontinuous and sandstone-body geometries are largely uncertain. Within this interval,the net-to-gross ratio varies from 25 to 40%. One of the most important challenges is to obtain effective fracture-height coverage over the entire Lance formation.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/calibrated-fracture-models.html","docCreatedDate":"2018-10-02T03:13:04.563-05:00","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,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,Reservoir_Challenges:Small_Uneconomical_Reservoir_Pockets,|locations:Global,"},{"title":"High-Temperature Zonal Isolation During Horizontal-Well Stimulation Yields Three-Fold Increase in Production Rate vs. Vertical Well","description":"A customer in south Texas faced the challenge of completing a deep, non-cemented, horizontal well for the purpose of increasing production in tight sand formations. The job called for isolation of multiple zones in a 2000 + ft openhole horizontal section forCobraMaxÆ pinpoint stimulation service and later production. Bottomhole static temperatures could reach 360°F and differential pressures up to 4000 psi were expected. A mixed string of 5½-in. casing on top and 3½-in. casing in the horizontal section would be used, and complete isolation of the planned itervalss and entire annulus was needed.","path":"/content/halliburton/en-US/ps/solutions/unconventional-resources/tight-gas-complex-gas/challenges-solutions/high-temperature-zonal-isolation-during-horizontal-well-stimulation.html","docCreatedDate":"2018-10-02T03:13:06.802-05:00","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":"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":"2018-10-02T03:13:05.704-05:00","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":"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":"2018-10-02T03:13:13.077-05:00","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,"}]}]