QHD32-6堵水酸化联作技术

堵水酸化联作工艺技术研究

ResearchonWaterShutoff－Acidizing

JointOperationTechnologyinQHD32-6OilField

西南石油学院石油工程学院SOUTHWESTPETROLEUMINSTITUTE2003.6.17,TangGuTianJin2023/2/4概述Introduction储层特点及伤害因素、开采现状、ReservoirCharacter，FormationDamageFactorsandProductionBehavior堵水酸化酸型及浓度确定DeterminingofAcidtypeandConcentration堵水酸化添加剂单项性能评价、酸液配方体系优选、性能评价Acidizingadditivesperfomanceevaluation,Acidformulaedesignanditsperformanceevaluation酸流动效果评价Acidflowtest堵剂体系合成、性能评价和流动效果评价Developmentofwatershutoffagent，perfomanceevaluationandcoreflowtest堵水酸化注入强度和速度研究DeterminingofInjectionRateandIntensity施工参数选择DeterminingofJobparameters实施工艺及方案OperationTechnologyandjobProgramme结论Conclusions汇报提纲Outline2023/2/4概述－立项背景Backgroud海洋油田开发特殊性需要加快采油速度EnhanceproductionrateQHD32-6油田储层易伤害因素多，需要解堵RemovealofFormationDamage-Acidizing油田开发早期出水，甚至水淹，产油量递减速度快Oilproductiondeclineduetowaterincursion-WaterControlling构造内幕复杂，受管柱等条件限制，机械卡水局限性强Complicatedreservoir，mechanicalwatershutoffmeasuresarelimitedforpracticing堵水酸化措施Waterpluggingandacidizing增油控水LowerwatercutEnhanceoilproductionrate2023/2/4概述－主要工作Mainworkofthestudy堵水酸化酸液体系Acidfluidsystem

堵水酸化堵剂体系Watershutoffagentsystem

堵水酸化实施工艺及参数Technologyofcombinationprocess

储层及开采特点reservoir

2023/2/4储层分析及伤害机理堵水酸化堵剂体系研究堵剂岩心流动试验研究堵水酸化酸型、添加剂配方体系研究岩心酸流动试验研究注入强度和速度研究堵水酸化实施工艺研究堵液候凝条件和关井条件研究实施方案研究概述－主要工作Mainworkofthestudy2023/2/4概述－技术关键TechnicalKeys两大类工作液体系的选择和研制DevelopmentofwaterShutoffagentsystemandacidformulaesystem堵液与酸液体系的适应性CompatbilityofwaterShutoffagentsystemandacidformulaesystem堵剂体系的交联时间确定CrosslinkingTimeofwaterShutoffagentsystem堵剂体系的强度和耐冲刷性Strengthandanti-washwaypropetyofwaterShutoffagentsystemand堵剂体系的选择性进入油藏Goodselectivityforinjectionunderreservoirconditions堵液前置液保护技术Prefluidprotectingtechniquebeforeinjectingpluggingfluid合理施工规模确定DeterminingofReasonablescaleoftreatment施工压力确定DeterminingofJobPressure施工工艺和方式确定OperatingTechnologyandMethod2023/2/4概述－研究思路ResearchApproach2023/2/4储层特点、伤害因素

ReservoirBehavoir，FactorsofFormationDamage多断层

Richfaults河流相沉积

Fluvialdeposit岩石疏松

Looserock多油水系统

Richoil-watersystem以边、底水为主

Edgewater,Bottomwater底水油藏油柱高度低LowoilColum(5~15m)

储层垂向渗透率高(Kv/Kh=0.7)

油水粘度比大

uo/uw=100－500重(稠）油

Heavycrudeoil2023/2/4储层岩芯电镜扫描分析TheSEMAnalysisofReservoirCoresQHD32-6-7井岩芯扫描电镜分析结果表明：TheSEManalysisshowsthat:储层岩石疏松，孔隙发育，粒间孔为主，溶蚀形成的次生孔隙所占比例大，孔隙的连通性良好。Therockofreservoirhasunconsolidatedstructure,growthpore,largequantityofintergranularpores,highratioofsecondaryporeformedbycorrosion,betterporeconnectivity充填物主要为伊利石和高岭石，且有少量蒙伊混层填隙物，孔隙中可见书状堆迭的高岭石，部分粘土的表面有少量莓球状黄铁矿。ThefillerismainlyIandK,littleM/I.Illiteusuallyexistsamonggrainswithclaybridgeshape.Kaolinitewithbookshapemayexistinpore.Theporefilledusuallyisgrowth.Thesurfaceofsomeclayhasafewpyriteswithberryshape.2023/2/4一定水敏性伤害晶格膨胀或分散堵塞孔喉

WaterSensitivityDamage一定流速敏感性微粒运移

VelocitySensitivity一定盐敏性粘土矿物缩聚、分散、脱落，运移堵塞孔喉

SaltSensitivity一定碱敏性粘土矿物解离和胶结物溶解后释放出微粒

AlkaliSensitivity酸敏性产生氢氧化铁沉淀

AcidSensitivity较强的出砂趋势

SandingTendency储层伤害潜在因素分析

AnAnalysisofPotentialFactorsforFormationDamage2023/2/4储层伤害机理TheMechanismofFormationDamage钻井泥浆伤害TheDrillingMudDamage

注水泥伤害TheCementingDamage(清洗液与隔离液、水泥浆、挤水泥、射孔)完井及修井液伤害

TheDamageofWellCompletionandtheWell-WorkoverLiquid砾石充填中的伤害TheDamageofGravelPack增产过程中的伤害(酸化、堵水等)TheDamageDuringStimulation(acidizing，waterpluggingetc)2023/2/4开采特点

ProductionBehaviour欠产原因

ReasonsofLowProduction含水上升快HighWaterCut边水推进(EdgeWater)底水锥进(BottomWater)水窜(WaterBreakthrough)储层伤害FormationDamage过高的比采油指数Over-designedProductionIndex2023/2/4出水类型－边水推进

TypeofWaterOut－EdgeWaterEdgeWaterEdgeWaterEdgeWaterEdgeWater2023/2/4出水类型－边水推进

TypeofWaterOut－EdgeWaterB7BW1B8EdgeWaterEdgeWater2023/2/4出水类型－边水推进

TypeofWaterOut－EdgeWater2023/2/4出水类型－底水锥进

TypeofWaterOut－ConingofBottomWater2023/2/4出水类型－底水锥进

TypeofWaterOut－ConingofBottomWater2023/2/4出水类型－底水锥进

TypeofWaterOut－ConingofBottomWater2023/2/4出水类型－水窜？

TypeofWaterOut－waterBreakthrough2023/2/4已采取的增产措施

StimulationshavePracticed机械卡水Y分采效果好，丢手管柱差，7”（56口）套管井受限Mechanicwatershutoff酸化，已显著增产效果Acidizing,yielddesiredresult换大泵UsinglargeFlowrateESP,enhaceproducingpressuredrop转注WaterInjectionChemicalWaterPluggingMeasures&StimulationneededtoReducewatercut,increaseoilproductionWaterPlugging&AcidizingJointOperation2023/2/4(1)QHD32-6油田地质条件复杂，多断层、河流相沉积、岩石疏松、多油水系统、重(稠）油。整个构造具有埋藏浅；幅度低，规模大，断层发育和局部圈闭多等特点。

ThegeologicsettingofQHD32-6OilFieldiscomplicatedwhichismuchfault,fluvialfacies,unconsolidatedrock,multi-oil-watersystemandheavycrude.Thewholestructurehasthepropertyofshallowdepth,smallrange,largescale,growthfault,andparttrap.(2)QHD32-6油田储集层埋藏浅，成岩作用较弱，砂岩疏松，储层物性好，显示为高孔、高渗储层，酸化酸型及配方的选择和实施应注意保护储层储层结构。ThereservoirofQHD32-6OilFieldhasthepropertyofshallowdepth,weakerdiagenesis,unconsolidatedsandstone,goodphysicalproperty,highporosityandpermeability.Weshouldprotectthestructureofreservoirwhenselectingacidfluidtypeinadditionprescriptionandpracticing小结A

BriefSummary2023/2/4(3)储层粘土含量主要为蒙脱石、高岭石、伊利石和伊/蒙混层，酸化过程中可能引起储层水敏、速敏、酸敏等二次伤害。TheclaymineralsofreservoirsaremainlyMontmorillonite,Kaolinite,IlliteandI/M.Itmayresultinsecondarydamagesuchaswatersensitivity,velocitysensitivity,acidsensitivityduringacidizing(4)QHD32－6油田原油属常规稠油,其密度大,粘度高,馆陶组原油性质好于明下段，地层水性质总矿化度不高，属NaHCO3型。TheoilofQHD32－6belongstoconventionalheavycrude,whichishighdensityandviscosity.ThephysicalpropertyofoilinGuantaoformationisbetterthanthatofMingxiasection.Thetrendisthephysicalpropertyofoilturnsbetterwithdepthincrease.Andtheoriginalsolutiongas–oilratioislower.Boththevolumefactorandcompressibilityfactoraresmaller.ThepropertyofformationwaterofGuantaoformationandMingxiasectionissimilarthatthetotalsalinityislow,whichbelongtoNaHCO3type.小结A

BriefSummary2023/2/4小结A

BriefSummary(5)QHD32-6油田出水类型：边水推进EdgeWater底水锥进ConingofBottomWater边水、底水复合CompositionofEdgeWater，Bottom套管外窜？OutsideCasingBreakthrough？2023/2/4堵水酸化过程中应特别注意的问题ProblemsmustbefullyconsideredDuringwaterpluggingandacidizing堵液的选择性Selectivityofpluggingagent酸液中必须考虑防膨、防微粒运移、防止铁离子沉淀、防止改变岩石的润湿性Clayswelling,theparticulateimmigrating,theironionprecipitationandthechangeofthewettability采用较低浓度的盐酸预处理，合理选择酸液浓度，防止HF溶解碳酸盐岩造成氟化钙沉淀LowconcentrationHClacidpretreatmenttodissolvecarbonate;properconcentrationisrequiredtoavoidthefluorationprecipitation.优选效能高、与地层流体和岩石相配伍的添加剂Screenoutacidadditivewithgoodperformance合理选择注酸强度、排液方式和反排压力，防止出砂Properacidconcentration,flowbackmethodandflowbackhpressure,sandcontrollmusttakenintoaccount2023/2/4堵水酸化酸液体系AcidFormulaeSystem堵水酸化堵剂体系WatershutoffAgentSystem堵水酸化实施工艺及参数WaterShutoffandAcidizingJointTechnology储层及开采特点Reservoir&ProductionBehavoir2023/2/4堵水酸化酸型及浓度确定

DeterminingofAcidtypeandConcentration酸化酸型分析砂岩储层酸化一般采用HCl和HF进行。适于QHD32－6油田酸化酸液体系分析土酸体系:溶蚀能力强，反应速度快，对地层岩石结构破坏严重SHF(SequentialHFProcess)酸液体系：粘土伤害储层可采用，但施工复杂高pH值缓速酸体系：自生土酸体系(SGMA,Self-GeneratingMudAcid)和缓冲调节土酸系统(BRMA,Buffer-RegulatedMudAcid)氟硼酸(HBF4)体系：用于敏感性较强、粘土含量较高，岩石疏松和易于造成微粒移动的地层广泛使用的深部酸化酸液体系。2023/2/4堵水酸化酸型及浓度确定

DeterminingofAcidtypeandConcentrationDissolutionResult

ofHCltoRock(65℃)盐酸可溶物的溶蚀率在2.21-3.76%之间.盐酸对储层岩石的溶蚀率较低，碳酸盐岩含量较少。各井段碳酸盐岩分布不均匀。随着浓度的增加，溶蚀率增加，但增加幅度较小。一般盐酸浓度低于8%时增加幅度要大些。盐酸对岩粉的溶蚀率低，岩芯疏松，建议酸浓度采用5-8%的盐酸较为合理。2023/2/4堵水酸化酸型及浓度确定

DeterminingofAcidtypeandConcentrationDissolutionResult

ofMudAcidtoRock(65℃)5%HCl＋x%HF

5%HCl＋x%HF

10%HCl＋x%HF

10%HCl＋x%HF

2023/2/4堵水酸化酸型及浓度确定

DeterminingofAcidtypeandConcentrationDissolutionResult

ofHBF4toRock(65℃)5%HCl＋x%HBF4

5%HCl＋x%HBF4

10%HCl＋x%HBF4

10%HCl＋x%HBF4

2023/2/4堵水酸化酸型及浓度确定

DeterminingofAcidtypeandConcentration(1)土酸体系对岩石结构破坏作用较强，氟硼酸体系则能较好的保持储层岩石的机械强度，是适于水敏性较强、岩石疏松和易于造成微粒运移的储层使用的深部酸化酸液体系。对于QHD32-6油田弱胶结疏松油藏酸化首选氟硼酸体系为主酸液体系。(2)酸液对QHD32-6油田储层岩石溶蚀率顺序为：HCl+HF>HBF4+HCl>HCl。酸化时推荐酸液浓度为：HCl浓度选用5－8%；HCl+HF浓度选用5%HCl+0.5%－1HF%；HBF4浓度选用5%HCl+5%－8%HBF4较合理。考虑到堵水后堵液对后续酸液前缘的稀释，实际应用时酸液浓度可适当提高

2023/2/4堵水酸化添加剂单项性能评价、酸液配方体系优选、性能评价

Acidizingadditivesperfomanceevaluation,AcidformulaedesignanditsperformanceevaluationAcidfluidperformanceRequirements好的酸液配方，必须具有配伍性好，表面张力低，破乳效率高，能稳定胶状铁的沉淀和防膨性能等特点。应对酸液中的各种添加剂进行单项性能筛选，综合分析，优选出性能好的添加剂。

酸液添加剂单项评价主要进行：缓蚀剂表面张力测定铁离子稳定剂测定破乳试验防膨性能试验和配伍性试验。采用盐酸、土酸、氟硼酸和混合酸进行评价：盐酸采用浓度5%

土酸采用浓度为5%HCl+1%HF

氟硼酸采用6%HBF4+5%HCl的浓度复合酸采用浓度为5%HCl+4%HBF4+0.5%HF。2023/2/4堵水酸化添加剂单项性能评价、酸液配方体系优选、性能评价

Acidadditivesperfomanceevaluation,Acidformulaedesignanditsperformanceevaluation筛选出以下添加剂系列：Aseriesofacidadditiveswerescreenedout:铁离子稳定剂推荐2种：SA1-7，CT1-7Ferricionstabilizer防膨剂推荐3种：SA-18B或KCS-18、BCS-851Claystabilizer 助排剂推荐2种：SA5-5B最好，其次是CT5-4Cleanupadditive缓蚀剂推荐2种:SA1-3B和CT1-3Corrosioncontrolagent破乳剂推荐3种：SA1-1、SD-1和SD2-11

Demulsifier2023/2/4配方酸液的筛选

SelectionofAcidfluidFormulae酸液名称Item酸液＋添加剂组合Acid+Additives前置液Padfluid5%HCl1%SA1-7+1%SA1-3B+1%SA1-1+1%SA-18B+0.5%SA5-5B+2%EGMBE+1%胶束剂处理液1TreatmentfluidI处理液2TreatmentfluidII处理液3TreatmentfluidIII5%HCl+6%HBF41%SA1-3B+1%SA1-7+1%SA-18B+1%SA1-1+0.5%SA5-5B+1%EGMBE+1%胶束剂5%HCl+1.0%HF1%SA-18B+1%SA1-3B+0.5%SA5-5B+1%SA1-7+1%SA1-1+1%EGMBE+1%胶束剂5%HCl+5%HBF4+0.5%HF1%SA1-7+1%SA-18B+1%SA1-1+1%SA1-3B+0.5%SA5-5B+1%EGMBE+1%胶束剂后置液Postpadfluid5%HCl1%SA1-3B+1%SA1-7+1%SA-18B+1%SA1-1+0.5%SA5-5B+2%EGMBE+1%胶束剂

综合储层岩性分析、岩石结构情况、对储层岩石溶蚀试验结果和酸液添加剂单项评价结果及分析，采用SA系列的添加剂与盐酸、土酸、氟硼酸和复合酸互配，组合成以下配方：2023/2/4配方酸液特点

CharacteristicofAcidFormulae对储层的弱溶蚀和堵塞物的有效溶蚀，保护岩石结构，并保证深部穿透；应用性能优良的缓蚀剂，与酸液具有很好的配伍性和防腐蚀作用；在配方酸液中增加了胶束剂，加强酸液配方与地层流体和有机物的互溶性，提高酸液对反应产物的悬浮能力；采用性能优良的粘土稳定剂，提高了配方酸液的防膨性能加强了化学助排剂性能，应用了助排剂和乙二醇丁醚，有效降低酸液的表面张力，提高残酸返排速度；加强溶解地层孔隙表面的油组分；使地层为水润湿以提高油的相对渗透率；在配方酸液中增加了胶束剂，加强酸液配方与地层流体和有机物的互溶性，提高酸液对反应产物的悬浮能力。2023/2/4配方酸液的破乳性能评价DemulsificationPerformanceEvaluationofAcidfluidFormulaeTesttemperature:650C:Testperiod:2hour:Acid/cruderatio:40ml/40mlDemulsificationperiod:15min2023/2/4配方酸液的表面张力评价MeasurementofSurfaceTensionofAcidfluidFormulaeLowSurfaceTension，easyFlowback2023/2/4配方酸液的配伍性评价CompatibilityEvaluationofAcidfluidFormulaeTesttemperature:7C,65CAcidfluid:padfluid,treatmentfluid(I,II,II),postpadfluidAcid/formationwater:10ml/10mlFormationwater:formationwaterdepth1416.50～1391.00minQHD32-6-4wel1Salinityofformationwater:16734mg/LExcellentCompatibility

2023/2/4配方酸液的缓速性能评价RetardingPerformanceEvaluationofAcidfluidFormulaeTreatmentFluidII>TreatmentfluidIII>PadFluid>TreatmentFluidI2023/2/4配方酸液的缓蚀性能评价CorrosionCotrolPerformanceResultofAcidfluidFormulaeCorrosionspeedofpadfluidis2.1432g/(m2.hr)CorrosionspeedoftreatmentfluidIis2.42g/(m2.hr)CorrosionspeedoftreatmentfluidIIis2.99g//(m2.hr)CorrosionspeedoftreatmentfluidIIIis2.88g/(m2.hr)Corrosionpattern:UniformCNPCStandardRequirement:CorrosionRate<5g/(m2.hr)2023/2/4配方酸液的铁离子稳定剂的性能评价FerricIonStabilizerPerformanceEvaluationinAcidFluidFormulaeAcidformulaeallhavepreferableabilitytostabilizeferricionFerricIonStabilizingAbilityofAcid>78%TreatmentFluidI>TreatmentFluidII>TreatmentFluidIII,padFluidPreventgeneratingabundantgelprecipitationofFe(OH)3,andkeepferricionalwaysintheionicstatementsuspendedinacidfluid,2023/2/4配方酸液的防膨性能评价AntiswellingPerformanceofAcidFluidFormulaeFluidType2hrExpansionRatio(%)24hrExpansionRatio(%)ReductionofFinalExpansionRatio(%)Freshwater89.597.85Padfluid53.4555.2543.5TreatmentfluidI52.6454.7544.0TreatmentfluidII53.6555.7643.0TreatmentfluidIII53.5856.0342.7Antiswellingperformance:TreatmentfluidI>padfluid>TreatmentfluidII>TreatmentfluidIII2023/2/4配方酸液的酸渣试验AcidsludgeTestofAcidfluidFormulaeAcidsludgequantityinpadfluidis0.0171gIntreatmentfluidIis0.0218gIntreatmentfluidIIis0.0327gIntreatmentfluidIIIis0.0366gLowAcidSludge

2023/2/4对组合的前置液、处理液(土酸、氟硼酸、复合酸)和后置液进行综合评价表明，酸液配方具有：Theacidfluidformulaearechractersiticof:破乳效果好Demulsificationeffect与地层水配伍性好Goodcompatibility表面张力低Lowsurfacetension降低酸对设备腐蚀Lowcorrosionrate络合铁离子能力高Highcapacityofchelateferricion防膨胀性能好Avoidingofclayswelling

其中以处理液1体系效果最佳，具有很好的返排能力，对储层伤害小。

TreatmentFluidIsystemisbestformula.小结ABriefSummary2023/2/4酸流动效果评价AcidCoreFlowtest酸化流动试验方法MethodofAcidCoreFlowingTestKvs.PVofAcid驱替顺序DisplacementOrder4%NH4Cl(MeasureK0)→Padfluid→TreatmentFluid→Post-Pad→Post-PadReversely→4%NH4ClReversely.

2023/2/4堵水酸化效果岩心酸流动试验结果StudyResultsofWaterShutoff&AcidizingEffectTest未污染岩芯-处理液IUndamadgedCoreWithTreatmentFluidIUndesiredAcidzingEffect2023/2/4堵水酸化效果岩心酸流动试验结果StudyResultsofWaterShutoff&AcidizingEffectTest未污染岩芯-处理液IIUndamadgedCoreWithTreatmentFluidIIUndesiredAcidzingEffect2023/2/4堵水酸化效果岩心酸流动试验结果StudyResultsofWaterShutoff&AcidizingEffectTest未污染岩芯-处理液IIIUndamadgedCoreWithTreatmentFluidIIIUndesiredAcidzingEffect2023/2/4堵水酸化效果岩心酸流动试验结果StudyResultsofWaterShutoff&AcidizingEffectTest污染岩芯-处理液IDamadgedCoreWithTreatmentFluidIDesiredAcidzingEffect2023/2/4堵水酸化效果岩心酸流动试验结果StudyResultsofWaterShutoff&AcidizingEffectTest污染岩芯-处理液IIDamadgedCoreWithTreatmentFluidIIDesiredAcidzingEffect2023/2/4堵水酸化效果岩心酸流动试验结果StudyResultsofWaterShutoff&AcidizingEffectTest污染岩芯-处理液IIIDamadgedCoreWithTreatmentFluidIIIDesiredAcidzingEffect2023/2/4堵水酸化酸液体系AcidFormulaeSystem堵水酸化堵剂体系WatershutoffAgentSystem堵水酸化实施工艺及参数WaterShutoffandAcidizingJointTechnology储层及开采特点Reservoir&ProductionBehavoir2023/2/4耐酸性SPA系列堵剂体系研究StudyontheSPA-031Anti-acidPluggingAgentSystem堵水剂材料无机和有机两大类:无机类堵剂价格便宜、强度高，但成胶时间不易控制，一旦误堵则不易解封有机类堵剂应用更广泛新型调堵剂SPA-031属就地共聚合交联体(30-130℃)SPA-032低聚腈胺盐物质(50℃~90℃)2023/2/4耐酸性SPA-031堵剂研究StudyontheSPA-031Anti-acidPluggingAgent化学作用机理MechanismofChemistryReaction由第一主剂、第二主剂、引发剂、速度控制剂和热稳定剂组成。将主剂和添加剂混配成水溶液，注入地层后在地层条件下发生共聚合反应，形成凝胶。SPA-031pluggingagentwascomposedofSPA-031-M1as1stmainagent,SPA-031-K1as2ndmainagent,initiator,controllingrateagentandthermo-stabilityagent.Aqueoussolutionwaspreparedwithmainagentsandadditivesatcertainproportioninsitu.Thentheaqueoussolutionwasinjectedformation.Themainagentsintheaqueoussolutionpolymerized,andshapedcolloidfinally.2023/2/4影响SPA-031成胶性能的因素FactorsofEffectonSPA-031’sPerformance

配方组成Formulations：第一主剂为4～5%第二主剂为0.8～1.2%、引发剂为0.01～0.12%、热稳定剂5～20mg/l时，体系成胶时间在7～45小时可控(温度为30～130℃)TheconcentrationofSPA-031-M1:4-5%TheconcentrationofSPA-031-K1:0.8-1.2%Theamountofcross-linkingagentintherawmaterials:0.01-0.12%Theconcentrationofthermo-stabilizer:5-20mg/LReactiontime:7-45hrBathtemperature:30-120℃

2023/2/4影响SPA-031成胶性能的因素FactorsofEffectonSPA-031’sPerformance

主剂1对成胶时间影响EffectofSPA-031-K1

C12%3%4%5%t(hr)(gellingtime)／48-5424-3015流动性Flowability水一样稀Likewater倒置略变形Littlechangingshape倒置不动Stillness倒置不动StillnessNote：C1ConcentrationofSPA-031-K1

；“／”符号表示5天未成胶第一主剂浓度增加，成胶时间明显缩短，凝胶硬度增大ThegeltimeisshortenedwiththeincreasingoftheconcentrationofSPA-031-K1

2023/2/4影响SPA-031成胶性能的因素FactorsofEffectonSPA-031’sPerformance

主剂2对成胶时间影响EffectofSPA-031-K1

(90OC)随着第二主剂浓度的增加,成胶时间缩小,但进一步增加浓度,成胶时间延长

GeltimeisshortenedwiththeincreasingoftheconcentrationofSPA-031-K1,however,thegeltimewouldbepostponedwiththemoreincreasingoftheconcentrationofSPA-031-K1

CSPA-031-K100.75%2.5%3.75%4.5%5.75%7.5%成胶时间t(h)/2015101318/胶体流动性MobilityofgelAlikeWaterDistortasbeinginvertedImmobilizeasbeinginvertedImmobilizeasbeinginvertedImmobilizeasbeinginvertedSlightlyDistortasbeinginvertedViscosityincreasingNote：“/”----nogelin24h；Formulation:5%SPA-031-M1+0.01%initiatingagent+10mg/Lheatstabilizer

2023/2/4影响SPA-031成胶性能的因素FactorsofEffectonSPA-031’sPerformance

引发剂对成胶时间影响EffectofPolymerInitiatingAgentConcentration(90oC)引发剂浓度在0.005%~0.025%时均可成胶，随引发剂浓度增加，成胶时间明显缩短，且胶体流动性变差Allsystemcouldformgelwhentheconcentrationofinitiatingagentis0.005%~0.025%.Withtheincreasingconcentrationofinitiatingagent,thetimeofgelobviouslyshortenedConcentrationofinitiatingAgent0.005%0.01%0.015%0.02%0.025%成胶时间t(hr)41382063流动性MobilityofgelAlikewaterDistortasbeinginvertedImmobilizeasbeinginvertedImmobilizeasbeinginvertedImmobilizeasbeinginvertedFormulation：5%SPA-031-M1＋1%SPA-031-K1＋5mg/Lheat-stabilizer2023/2/4影响SPA-031成胶性能的因素FactorsofEffectonSPA-031’sPerformance

阻聚剂对成胶时间影响

EffectofPolymerRetardingAgentConcentration随阻聚剂浓度增加，成胶时间延长；当阻聚剂浓度为20mg/L时,体系仅增稠；浓度继续增加，体系中单体不能被引发，故体系的外观仍像水Thetimeofgelextendedwithincreasingtheconcentrationofpolymeringretardingagent.Theconcentrationofpolymeringretardingagentis20mg/L,thesystemthickenonly,andthesinglecouldn’tbeinitiatedwithcontinuallyincreasingtheconcentration，thesystemstillresemblethewater.C3(g/L)2510152030成胶时间t(hr)3037427070/胶体流动性MobilityofgelSlightlyDistortasbeinginvertedSlightlyDistortasbeinginvertedSlightlyDistortasbeinginvertedSlightlyDistortasbeinginvertedFlowasbeinginvertedAlikeWaterNote：“/”----nogel；C3----concentrationofpolymeringretardingagentFormulation:4%SPA-031-M1+0.05%polymerretardingagent

2023/2/4影响SPA-031成胶性能的因素FactorsofEffectonSPA-031’sPerformance

温度对成胶时间影响

EffectofTemperatureonGelTimeThetemperature30~50℃：氧化-还原引发体系即引发剂＋亚硫酸氢钠

Theformulationoftheredoxinitiatingsystemis5＃：3%SPA-031-M1＋1%SPA-031-K1＋0.015%initiatingagent＋0.015%deoxidant

温度T(℃)304050成胶时间t(hr)544124胶体流动性MobilityofgelDistortasbeinginvertedDistortasbeinginvertedDistortasbeinginvertedUpwards60℃,theformulationis6＃:5%SPA-031-M1＋0.01%initiatingagent＋1%SPA-031-K1＋10mg/Lheatstabilizer温度

(℃)708090100120130t(hr)81~84502420~1818~1518~15MobilityofgelDistortasbeinginvertedDistortasbeinginvertedDistortasbeinginvertedDistortasbeinginvertedDistortasbeinginvertedDistortasbeinginverted体系配方一定时,随温度升高,成胶时间缩短,即聚合交联反应速度加快2023/2/4影响SPA-031成胶性能的因素FactorsofEffectonSPA-031’sPerformance

堵剂粘时关系Viscosityvs.Time

RelationshipofAgentFormulation：SPA-031-M1is3%,4%or5%,0.01%initiatingagent,1%SPA-031-K1and10mg/Lheat-stabilizer.2023/2/4影响SPA-031成胶性能的因素FactorsofEffectonSPA-031’sPerformance

堵剂热稳定性和盐稳定性TheThermalStabilityandSalt-StabilityofWaterShutoffAgent良好的热稳定性FavorableThermalStability胶体在90℃下于100ml不锈钢瓶中置放六个月，粘度由9.1×104mPa.s下降为7.6×104mPa。s，粘度损失率约16.5%，Beingputinthe100mlsteelbottleforsixmonthsat90℃,theviscosityofthegeldropfrom9.1×104mPa.sdownto7.6×104mPa.s,thelosingrateofviscosityisabout16.5%较好的抗盐性Finesaltresistance用总矿化度为1.36×105mg/l的人工盐水配置堵剂，在90℃温室条件下静放三个月，粘度由7.3×104mPa.s变为5.2×104mPa.s，粘度损失为28.8%。

Watershutoffagentiscompoundedwiththeman-madebrineofgeneralmineraldegreeas1.36×105mg/l,beingsetforthreemonthsat90℃,theviscosityofthewatershutoffagentdropfrom7.3×104mPa.sdownto5.2×104mPa.s，thelosingrateofviscosityisabout28.8%.

2023/2/4影响SPA-031成胶性能的因素FactorsofEffectonSPA-031’sPerformance

堵剂体系强度StrengthOfSPA-0312023/2/4选择性堵水作用

SelectivityWaterShutoffAgent将SPA-031胶体分别置于油田人工地层水和混合油(原油∶煤油为1∶1)中，5天后水中胶体体积胀大1~3倍油中胶体体积缩小约1/4TheSPA-031gelisputinman-madestratumwaterandmixoilseparately(crudeoil∶coaloil=1∶1),thegelinwaterinflateto1~3times，thegelinoildeflateto1/4in5days影响SPA-031成胶性能的因素FactorsofEffectonSPA-031’sPerformance

2023/2/4SPA-031体系的岩心模拟试验

TheSimulationCoreExperimentofSPA-031System

2023/2/4堵剂封堵效率，耐冲刷性和耐酸性

BlockEfficiency,anti-scourandanti-acidabilityofWatershutoffagentCoreD×L(cm)PV(ml)Breakthroughpressure(MPa)Strength(MPa/m)TreatingSolutionWaterphasepermeabilitybeforetreatmentμm2Waterphasepermeabilitybeforetreatmentμm2Bridgingefficiency%BridgingDecreaseEfficiency(50pv)12.5×8.54.773.01235.4SPA-03Blocker0.08110.001997.695.6%22.5×7.15.503.41248.7Soakgacidafterblockergels0.04210.004689.132.5×8.14.296.14077SPA-03Blocker0.02050.032599.993.1%42.5×8.45.687.55089.9Soakacidafterblockergels0.02630.002889.6TestofAcidSensitivityandEffectofWaterBlock堵剂自身强度高，耐冲刷性和封堵性好,良好酸敏性SPA-031体系的岩心模拟试验

TheSimulationCoreExperimentofSPA-031System

2023/2/4堵剂选择进入性

SelectiveEntryTestofWaterShutoffWaterpotentiometricPermeabilitym2PermeabilityDifference

Entryflowrate(m3/h)

Core’sporevolume(ml)

Injectedporevolume(ml)

Volumeratio

87.41:5.51010.5612415.88.131031:7.51012.210.012.513.68.870.87151:151014.3715754710.20.2不同级差双并联岩心中流量体积比VolumeRatioinDoubleParallelCoreswithVariousPermeabilityDifferences渗透率级差增大，高低渗透层体积比显箸提高，有利于堵液笼统注入、使优先进入高渗透层volumetricratioinhighandlowpermeabilityformationincreasesremarkablyaspermeabilitydifferencebecomeslarge.Itdoesgoodtoinjecttogetherblockersolventandmakeitenterhighpermeabilityformation(usuallywaterproducingformation)atpriory2023/2/4堵剂选择进入性

SelectiveEntryTestofWaterShutoff不同排量时双联岩心中流量体积比FlowRateVolumeRatioinDoubleParallelCoresatDifferentFlowRate当渗透率级差一定时，随排驱速度的增加，高低渗透层流量分配比下降；排量较低时，进入高低渗透层的流量体积比差异减小采用低排量注入方式堵液将主要进入高渗区

Atagivenpermeabilitydifference,asdrivevelocityraises,distributionratiobetweenhighandlowpermeabilityformationdecreases.Soduringconstructionwhengellingtimematchtheneedoftechnology,blockerfluidwhoseflowrateislowerwillmainlyenterhighpermeabilityformation.WaterpotentiometricPermeability10-3μm2PermeabilityDifferenceCore’sporevolume(ml)Flowrate5m3/hInjectedporevolume(ml)Flowrate7m3/hInjectedporevolume(ml)Flowrate10m3/hInjectedporevolume(ml)Flowrate13m3/hInjectedporevolume(ml)117.41:5.311.761212121221.88.41.82.644.6Flowratedistributionratio6.674.632.62023/2/4前置液保护试验

ApplicationofPadfluid(PreventWaterplugagentFromDiluting)

TestofProtectingPadfluidCoreNo.Core’spermeability(10-3μm2)Volumeofpadfluid(PV)Volumeofblockerfluid(PV)Gel’sstrength(MPa/m)Pr-113300.3/Pr-29600.57.1Pr-31450.30.36.5Pr-41130.30.518对堵液采取弱凝胶前置液保护措施是行之的效的

Itisworkabletoprotectblockersolventbyweakgelaspadfluid2023/2/4SPA-031堵剂小结

ABriefSummaryonShutoffagentSPA-0311)SPA-031具有较强的抗酸性SPA-031canresistacidatsomedegree.2)该堵剂具有良好的选择注入性、高强度性和高效封堵性SPA-031hasthegoodabilityofselectivewaterflowing,strengthandshutoff.3)前置液对SPA-031体系具有保护作用SPA-031canbeprotectedbypadfluid.4)堵酸联合作业是油田控水稳油中的一项新的措施，且行之有效Jointoperationofpluggingagentandacidizingisthenewmeasurementinoilfield.2023/2/4耐酸性SPA-032堵剂研究StudyontheSPA-032Anti-acidPluggingAgent油田常用堵剂主剂为聚丙烯酰胺(HPAM)，但溶解性实验表明，在海水和馆陶水中无论是低分子量聚合物还是高分子量聚合物的溶解性都达不到施工要求，而低聚物腈胺盐易溶于水MainagentofpluggingagentusedinoilfieldisusuallyHPAM.TheresultsindicatethatthedissolutionofpolymerwithneitherhighnorlowmolecularweightcanreachtheconstructionneedsinseawaterandGuantaowater.WhileSPA－032-Z2withlowpolymerizingdegreecandissolveinwateranditsgelstrengthishigherthanfreshwatergel.weselectSPA－032-Z2withlowpolymerizingdegreeasmainagent.低聚物腈胺盐作为耐酸堵剂的主剂2023/2/4影响SPA-032主剂的选择SelectionofSPA-032MainAgent低聚物腈胺盐(AY-Ⅱ)使用浓度的确定，AY-Ⅱ浓度太低，不能成胶，浓度太高，将增加作业成本，确定交联剂浓度为5000mg/L，改变AY-Ⅱ的浓度TheEffectofLow-PolymerizationAY-Ⅱ(%)78910成胶时间Geltime(h)18181615强度描述IntensityABCDA.Flowinggel:inversebottle,gelhaveobviousflowability.B.Hardlyflowinggel:inversebottle,gelhardlyflowingand/orinverseagreatpartofgeldon’tflow.C.Notflowinggelwithhighdeform:inversebottleandgelcan’tflow(gelonlyflowinsmallareaofbottle).D.Notflowinggelwithgentlydeform:inverseonlythesurfaceofgelcandeformgently.AY-Ⅱ浓度在8%~10%的范围内能满足强度的要求Thecon.ofAY-Ⅱbetween8%to10%cansatisfytherequestofintensity2023/2/4交联剂选择和浓度确定TheSelectionofCrosslinkingAgentAndDeterminingofConcentration交联剂浓度对成胶时间影响不大，但影响凝胶的最终强度。建议交联剂的用量范围为4000mg/L~6000mg/LTheconcentrationofcrosslinkingagentnothavehigheffectongeltime,butfinallyeffectgelintensity.Recommendedconcentrationbetween4000mg/Lto6000mg/L.

有机铬交联体系和有机复合交联体系SPA-032-J2AdoptorganicchromiumcrosslinkingsystemandorganiccompoundcrosslinkingsystemSPA-032-J2CrosslinkingagentSPA－032-J2Con,mg/L成胶时间Geltime,hr强度描述Intensity2000---Notgel300022A400019B500018C600016DTheEffectofCrosslinkingAgentOnGelQuality,60℃,GuantaoWater2023/2/4SPA-032堵剂耐酸性TheAnti-AcidQualityofSPA-032WaterShutoffAgent酸液能使凝胶脱水收缩(因为液体的总量增加了)，凝胶的强度得到了进一步增强，在实验的10天时间内，凝胶未见被破坏。表明凝胶具有耐酸性

Acidcandehydrategel,(Becauseliquidgrossincreased)，Theintensityofgelreceivedmorebuildup,withinthetendaysoftest,gelnotbefoundtodestroy,whichshowgelhaveanti-acidquality

堵剂的耐酸性实验现象TestPhenomenaofAnti-AcidWaterShutoffAgent酸浸时间Dunktime(hr)试验现象Testph