1 Presentation onWell Testing and completion Well Testing Well perforation Well Activation Well Completion Well Stimulation 2 ProductionTesting operations 3 WELL TESTING Well testing is the firstmajor activity by production after completion ofdrilling operations Well testingis carriedoutto get the followinginformation 1.Deliverability of the well 2.Average reservoirpressure 3.Optimum selection of completion equipment 4.Predictionofreservoir performance andneed of other applications4 WELL TESTING Detailedtesting plan should be prepared InvolvementsinceGTOpreparation Agood testingtechnique, reliable equipment must for reliable results Equipment layout and theirplacement should suit local conditions Equipmentcheck list and operatibility test shouldbe done priorto well testing Completionequipment & alternative if anyto be preparedin advance Back ground Well drilling & completionprojectis undertaken either by Basin or SST. Location is released and well stacking is done as per the availability of land . A draft GTOis preparedby Basin/SST indicating the well depth, pore pressure temperature and lithology. Depending upon these parameters, suitable casing, well head,are selectedas per API6A specifications. Type of drilling rig, Mud system, cementing, logging, testing methodsarealso selectedat the time of preparation of GTO. LM-DS,LM-Mud,LM-WCT,LM-cmtg,AreaManager(G),LM-WCT,I/COps( Logging) & I/C QHSE are the signatories on the GTO. Eachdepartmentshallverifytheparametersandshallbeabletokeepthe required things ready during drilling and testing operations. Nodalanalysis/Softwareisavailablefordesigningsuitablecasing,wellhead and tubular. GTO(Geological Technical order)Conventional packer-less testing with X-mas tree Conventionalpacker-lesstestingis carried out inLow pressure wells Christmasis installed and tested Activationperiodis longer thanDST test killfluidisconditionedandmadeavailable perforationsarecarriedoutto establishcommunicationfrom reservoir to well borewellisthenactivatedbycreating sufficient differentialpressure Ifwelldidnotbecomeactive, suitablestimulationjob is carried out. ifwellproduces,measurementare taken and then connected to GGS. TestingwithHydraulicpackerandX-mastreeisalsocarriedoutuptoa differential pressure of 7500 PSI. Conventionalperforationsarecarried out. Hydraulic packer along with tubing are lowered up to desired depth. N/D BOP and N/Up of X-mas treeDisplacementoftubingvolumeof liquidwith lighter fluids and setting of packer. Ifwelldidnotbecomeactive, furtherdrawdownandstimulationjob is carried outthrough CTU. Testing with X-mas tree and Hydraulic packerAdj ChokeTesting with control Head and Mech Packer TestingwithControlheadand mechanicalpacker is also carried out uptoadifferentialpressureof7500 PSI and3500F rating. Conventionalperforationsarecarried out.Mechanicalpackeralongwith tubing/Drillpipesareloweredupto desired depth. Displacement of tubing Volume of mud with lighter fluids. Setting of packer and flowing of well. Adj ChokeTesting with control Head and TCP-DST & RetrievablePacker TCP-DST with Control head andretrievablepacker is carried out uptoadifferential pressure of 10000 PSI and 3500F rating. Flex operation of string with BHA. RIHTCP-DST&BHAbyfillingstringwith water. Depthcorrelationforstringspaceoutfor gunsagainst perforations. Setting packer and confirmation. Perforation ofobject by hydraulic firing. Openwellandobserveforactivityand subsequent reservoir studies. Any further drawdown is required to be give only thru CTU. Adj ChokeHigh pressure Pumper Testing with control Head and TTV-J & Permanent packer 5,15K,4500F FlexoperationofstringwithBHAandtest up to desired pressure. Conventionalperforationinthedesired interval RIHHPHTpermanentpackerwithdepth correlation and setting at desired depth . RIH DST TTV-J& LTSA and string & carry out depth correlation. Stab into packer and land tubing hanger. N/ down of BOP and N/Up X-Mas tree. Displacementofmudinstringwith brine with CTU.(unconventional). Openwellandobserveforactivityand subsequent reservoir studies. Adj ChokeDST Testing with TTV-J& Control head15K,Offshore FlexoperationofstringwithBHAandtestupto desired pressure. RIHHPHTpermanentpackerwithdepth correlation and setting at desired depth . RIH TCP with TTV-J & LTSA . Space out the string so thatthe E-Z valve is placedagainst the BOP after stab-in of LTSA. Stab into packer and lock open TTV-J & stab-out. Displace tubing volume of liquid with lighter fluids. Stab LTSA inside the packer. confirm setting. Open well and observe for activity and subsequent reservoir studies.Any further activation or drawdown is possible only through CTU. Adj ChokeHigh pressure Pumper Testing with TTV-J&control Head and CTU FlexoperationofstringwithBHAandtestupto desired pressure. RIHHPHTpermanentpackerwithdepth correlation and setting at desired depth . RIH TCP & TTV-J with LTSA . Space out the string so thatthe E-Z valve is placedagainst the BOP after stab-in of LTSA. Stab into packer and lock open TTV-J & stab-out. Displace tubing volume of liquid with lighter fluids. Stab LTSA inside the packer. confirm setting. Open well and observe for activity and subsequent reservoir studies.Anyfurtheractivationoperationsiscarriedout throughCTU only. ( Unconventional)Design considerations Selection of well head Selection of casing selection of tubular selection of packers selection of testing methodology. Selection of completion Features: 1.Straight-bore design with 45load shoulder. Selection of secondary seals and pack-off bushings provide versatility. 2.Working Pressure: Up to 10,000 psi (Excluding tubing spool) 3.Operating Temperatures: -20 F to +150 F (-29 C to +65 C) 4.Hang-Off Capacity: Up to 50% pipe body yield 5.Casing Head Housings: IC-2, IC-2-BP6.Casing Head Spools: IC-2, IC-2-BP, IC-2-L 7.Casing Hangers: IC-1, IC-1P, IC-2 slip and seal assemblies Tubing Spools And Hangers: 1.C tubing spool: HT, HT-2, T, T-CL, C-SRL, CXS hangers 2.MTBS tubing spool: MTBS hanger 3.CD-2 tubing spool: CD-2, CD-T, CD-T-CL hangers WellHead & X-Mas tree WellheadandChristmasTree equipment,thekeyequipmentused inoil/gasproduction,consistsof casinghead,tubingheadand Christmas Tree, which are applicable forfixingwellhead,hangingcasing stringandtubingstring,sealingthe annularspacebetweencasingand tubing,andcontrollingthepressure oftheproductionwellheadand adjustingtheflowrateofoil/gas wellheadaswellassomespecial operationssuchasacidfracture, water-injection, testing and so on. APISpecification6A(ISO10423)istherecognizedindustrystandardfor wellheadandchristmastreeequipmentthatwasformulatedtoprovidefor theavailabilityofsafe,dimensionallyandfunctionallyinterchangeable wellhead and christmas tree equipment. This specification includes detailed requirementsforthe manufactureoftubularsuspensionequipment,valves, andfittingsusedatthelocationofoilandgaswellstocontainandcontrol pressure and fluid flows. API Specification 6A StandardAPI 6A Rated working pressure 2000~20000Psi Product specification level PSL1~PSL3G Rated working tempterature L,N,P,S,T,U,V Performance requirement level PR1,PR2 Material classAA,BB,CC,DD,EE,FFSuitable medium Oil, natural gas, mud and water Temperature Classification * Operating Range ( Degrees Fahrenheit [F] ) Min.Max. K-75to180 L-50to180 N-50to140 P-20to180 RRoom Temperature S0to140 T0to180 U0to250 V35to250 X **0to350 Y **0to650 * Purchaser may combine temp classes e.g. KU, -75 TO 250 F **May require derating AA-General ServiceCarbon or low alloy steel BB-General ServiceCarbon or low alloy steel CC-General ServiceStainless steel DD-Sour Service aCarbon or low alloy steel b EE-Sour Service aCarbon or low alloy steel b FF-Sour Service aStainless steel b HH-Sour Service aCRA bcd aAs defined by NACE Standard MR0175 / ISO 15156. bIn compliance with NACE StandardMR0175 / ISO 15156. cCRA required on retained fluid wetted surfaces only; CRA cladding of low allow or stainless steel permitted. dCRA as defined in API 6A latest edition. NACE MR0175 / ISO 15156 definition of CRA does not apply. Material classMinimum Material Requirements Body & Flange Back ground Hermetical test: Negativetest:AfterinstallingtheXMTDrillfluidsare displaced with waterand keptopentocheckthe influxofanyliquid/gasintothewellbore.Thiscan also be done by displacing with wellfluidswith Nitrogen/air compressor twice to check the influx. Positivetest:Drillfluidsaredisplacedwithwaterand pressurized to a desired Hermeticalpressureto check the integrityofcasing.Thetestpressureis calculated assuming thatthe well is completely filled with formation gas.Oncecasingistestedhermeticallyitisfollowedby CBL/VDL . Back ground HERMETICAL TEST PRESSURE INPUT BHT137DEG C SG1.85 DEPTH2900M PORE PRESSURE1.75SG Z FACTOR1.1 HYDROSTATIC HEAD4126.7 FORMN PRESSPSI 7222 OUTPUT HERMETICAL PRESS= 6329.9 PSI Ps= P b / e 0.0341634*g*D/(ZXT) Ps= Surface Pressure in Kg/cm2 P b =Bottom hole pressurein Kg/cm2 g = Specific gravity of gas with respect to air D= Vertical depth in mts Z= Gas compressibility factorT= Mean temperature in 0K (273+0C) =0K Well Head Rating for HPHT wellsWell Name Mud wt SG/Temp (F) Depth (mts) Hermetical press (a) PSI operating pressure for down-hole tools, circulation(b) PSI* Total Pressure (a+b) PSI Total pressure reqmt with SF of 1.2= 1.2(a+b) PSI** Well head rating PSI SVLAA1.7032938007500150090001080015000 KNDAA1.80356440095501500110501326015000 NPAA1.7029840007750150092501110015000 KOTAA1.7036042508250150097501170015000 SMAAB1.503563700641015007910949210000 BTSAA1.6535045007560150091601099015000 NVVAA1.854465450113001500128001530015000 KONAA1.90356450097301500112301347515000 MUKAA1.7537440007860150093601123015000 VNSAA1.7030237007250150097501170015000 SUAF1.7533838007470150099701196015000 * WH rating after taking 1500 PSI allowance for circulation and down hole tools ** Provision of safety factor of 1.2 burst for well head rating.CASING:Function of casing:To keep the hole open and provide support to weak fracturedformation.To isolate porous media with different fluids / pressure regimes fromcontaminating the pay zone, in conjunction with cementation.To prevent contamination of near surface fresh water zones.To provide passage for hydrocarbon fluid.To provide connections for well head equipments like BOP etc. To facilitate running of completion tools with respect to their knowndiameter. Types of casing: Stove pipeConductor pipeSurface casingIntermediate casingProduction casingLiner casingPrimary function of tubing is to form a conduitbetween formation fluid & surface equipments. For well killing, circulation and workover . To provide optimized flow channel to produce maximumefficient rate from a well. To isolate casing form effect of high pressure, temperature and corrosive fluids. To enable to produce from different types of completions. To facilitate artificial lift. Tofacilitateinstallationofcommonwire-lineoperateddownhole tools.Function of Tubing:Flow rate range as a function of the tubing diameter Tubing Size (inches) Tubing weight (PPF) Tubing ID (inches) Range of oil flow rate (M3/day) Range ofGas flow rate (KM3/day) 2.3754.61.995< 150< 50 2.8756.42.441 150-50050-250 3.59.22.992300-100080-400 4.512.63.958500-1600180-1000 Adownholedeviceusedinwellcompletiontoisolate theannulusfromtheproductionconduit,enabling controlled production, injection or treatment. Atypicalpackerassemblyincorporatesameansof securing the packer against the casing or liner wall, such as a slip arrangement, and a means of creating a reliable hydraulic sealto isolate the annulus, typically by means of an expandable elastomeric element. Packers are classified by application, setting method and possible retrievability. PACKERSTYPES OF PACKERS Mainly three kinds of packers Mechanical Packers Hydraulic packers Permanent packers APISpecification6A(ISO10423)recommends productspecificationlevels(PSLs)forequipment withqualitycontrolrequirementsforvarious serviceconditions.PSLsapplytoprimary equipment: Tubing heads Tubing hangers, hanger couplings Tubing head adapters Lower master valves Allotherwellheadpartsareclassifiedas secondary.ThePSLforsecondaryequipment may be the same or less than the PSL for primary equipment. Product Specification Levels (PSL) PSL-Product safety leveldecision treePSL-1 Continued Process Inspection Hydrostatic Test (except for Loose Connectors. PSL-2 Equipment meets all the requirements of API Spec 6A PSL-1 and: Controls the limits of variance between the material qualificationtestcouponandtheproduction material.CVNtestingforservicetemperature-20 F and below. Volumetric inspection of welds (RT or UT). Magneticparticleinspectionofaccessiblewell wetted surfaces. PSL-3 Equipment meets all the requirements of API Spec6A PSL-2andrestrictsthetoleranceofmaterialchemistry. Increases the maximum size of the material qualification test coupon in relation to the section thickness of the equipment components. CVN testing for all service temperatures. Volumetricinspectionofallmaterialinbody,bonnets, flanges & stems.. WetMagneticParticleinspectionofallaccessible surfaces. HydrostaticTesttimeextended(exceptforLoose Connectors). PSL-3GincludesalltherequirementsofPSL3plus additionalpracticesdescribedinAPI6A,AnnexA.PSL-3Gdesignatesanadditionalgas-testingrequirementfor assembled equipment. Back ground PSL-4 : Equipmentmeetsalltherequirements of API Spec 6A PSL-3 and: Increasesthemaximumsizeofthe materialqualificationtestcouponin relation to thesectionthicknessofthe equipment components. Prohibits welding except for overlay/inlayofcorrosionresistantalloy on well wetted surfaces. Gas testing of assembled equipment. 1234567 NACENOYESYESYESNONO high H2S connection NONOYESNoNoYES Close proximity ? NONONOYESYESYES PSLPSLPSLPSLPSLPSL 5000 (34.5)112213 10000 (69.0)223334 15000 (103.4) AND UP 334444 Table- recommended minimum PSL for primary parts of wellheads and x-mas tree equipment Rated working pressure, psi (MPa) Start here Rated working pressure 15000 psi HighH2S concentration Close proximity? Rated working pressure HighH2S concentration? NACE ? Close proximity? Close proximity? Close proximity? Rated working pressure Rated working pressure Rated working pressure Close proximity? Y N Y NN N N N N N N Y Y YY PSL 4 PSL 1 PSL 3 PSL 2 PSL 1 PSL 2 PSL 3 PSL 2 PSL 2 PSL 3 PSL 4 PSL 3 PSL 3 PSL 4 >5,000 PSI (34.5MPa) >5,000 PSI (34.5MPa) >5,000 PSI (34.5MPa) >5,000 PSI (34.5MPa) 5,000 PSI (34.5 MPa) 5,000 PSI (34.5 MPa) 5,000 PSI (34.5 MPa) 5,000 PSI (34.5 MPa) CONVENTIONAL WELL TESTING PROCEDURE ACTIVATIONPLANNING WELL TESTEQUIPMENT CHECK FIELD TEST INGHERMETICALTESTINGWELL REPAIRJOBPERFORATIONOK NOTOK OK WELL COMPLETIONNOTOK STIMULATIONOK NOTOK ZONE ABANDON CONECTIONTOGGSOK PRODUCTION TESTING METHODOLOGY SEQUENCE OF OPERATIONS: Conventional testing:

Clearing andscraping oftheholetotherequired depth usually 10 mtsbelow the bottom most perforation of the object.

Recording ofCementbondLog/variabledensitylog toensureproper cement bond / isolation above andbelow the object under test.

Hermeticaltestingoftheproductioncasing/linerinwatertothemaximumexpected surface pressure. Changing over to mud of specific gravity used during drilling and its conditioning.

Conventionalperforationoftheobject,junkbaskettrip and setting of permanentpacker at suitable depth through wire line of logging . Running in of production string, packer testing and spacing out. Rigging-up of surface equipments and lines and then pressure testing of the same. Displacementof string volume with cushionfluid(diesel / water)depending upon the expected formation pressure and draw-down to be provided Flowing back the well. Reservoir studies ( Virginpressure recording,3beanstudies, build-up studies, gradient survey, PVT sampling) to be carried out incase the well becomes active. Stimulation job, if required, for skin removal. Incase,welldoesnotbecomeactive,thenpressuresurgingandkeepingthewellunderobservation.Reversingoutforbottomhole sample collection. After conclusive testing of the object,killingof well by bulldozingthe well fluid into the perforation interval of the object tested. Conditioning of the mud. Pulling out the production string. Isolationoftheobjectbybridgeplug/cementsqueezeintoobject perforation. CONVENTIONAL WELL TESTINGINCASED HOLESChristmasis installed and tested Activationperiodis longer thanDST testkill fluidis conditionedand madeavailableperforations toestablish communication fromreservoirto well borewell is thenactivated by creating sufficientdifferentialpressure Ifwell did notbecomeactive, suitablestimulationjob is carried out If well produces, measurement are taken and then connected to GGS X Mas tree Conventional testingwith X-mas tree TubingAnnulus

Minimalformationdamagecausedbydrillingfluidinvasionsincetheobjectis opened for flow immediately after perforation. Suitable for testing tight as well as sand incursion prone formations because of the perforations with increased shot density @ 12 SPF, deeper penetration and double helix profile. Provisionforselective/controlleddraw-downforfasteractivationofsub-hydrostatic formations. Longperforationintervals(upto40m)inasinglerun,therebyreducingthe numberofrunsrequiredforconventionalperforationsandsavingcostlyrig time. Suitable for non expendable wells requiring re-entry at a later date due to ease ofcompletionaspermanentpackersneedtobemilledforproductionfrom lower objects. TypicalTCPassemblyconsistsofTCPguns,bardropactivatedaswellas hydraulicpressureactivatedfiringhead,debrissub,retrievablepacker,safety joint, hydraulic jar, reversing tool and radioactive marker. TESTING WITH TUBING CONVEYED PERFORATION -TCP SYSTEM:

TESTING WITH DRILL STEM TEST (DST) SYSTEM:

ADVANTAGES: Additional down hole safety for testing of high pressure (surface pressure up to 8000 psi) and high H2S (concentration > 40, 000 ppm) wells.

Useofdownholeelectronicpressureandtemperaturegaugesfor accurate recording of down hole data.

Fasterattainmentofreservoirparameterssincethewelliscloseddown hole,veryneartotheperforatedintervalsoftheformation,therebyreducing the testing time.

TheDSTtoolsconsistofretrievablepacker,downholeelectronic pressureandtemperaturegauges,safetyjoint,hydraulicjar,Hydrostatic ReferenceTool(HRT),PressureControlledTesterValve(PCTV),SingleBall SafetyValve(SBSV),MultiCycleCirculatingValve(MCCV),SingleHydraulically OperatedReversingTool(SHORT),radioactivemarkerandslipjoints.Allthe above tools are fullbore tools.

TESTING WITHTCP (SHOOT & PULL):

Clearing and scraping of the hole to the required depth usually 10 mts below the bottom most perforation of the object. Recording of CBL-VDL log to ensure proper cement bond / isolation above and below the object under test. Hermetical testing of the production casing / liner in water to the maximum expected surface pressure.& Changing over to mud of specific gravity used during drilling and its conditioning. Running in hole tubings single by single for tubing flex trip to check the pressure integrity of tubings and also to remove the debris, tubing scales from tubings. TESTING WITHTCP (SHOOT & PULL):

Running in of TCP string filled with requisite column of cushion fluid to provide required drawdown. In case, complete string is to be filled with cushion fluid, then the string can be displaced with cushion fluid prior to setting the retrievable packer instead of filling the string intermittently. Correlation with CCL-GR toolso as to ensure that the TCP guns are against desired depth. Spacing out based on correlation run. Rigging-up of surface equipments and lines and then pressure testing of the same. Setting of retrievable packer; testing of packer.

Dropping of TCP bar to fire the guns and perforate the object interval, Flowing back the well. Reservoir studies (Virgin pressure recording, 3 bean studies, build-up studies, gradient survey, PVT sampling) to be carried out in case the well becomes active. Stimulation job, if required, for skin removal. After conclusive testing of the object, killing of well by bulldozing the well fluid into the perforation interval of the object tested. Opening SHORT.

In case, well does not become active, then pressure surging and keeping the well under observation. Reversing out for bottom hole sample collection through SHORT.

Reverse circulation of one string volume. Unseating the retrievable packer.

Conditioning of the mud. Pulling out the production string. Isolation of the object by bridge plug / cement squeeze into object perforation.

TESTING WITHDST:

Clearing and scraping of the hole to the required depth usually 10 mts below the bottom most perforation of the object. Recording of CBL-VDL log to ensure proper cement bond / isolation above and below the object under test. Hermetical testing of the production casing / liner in water to the maximum expected surface pressure. Changing over to mud of specific gravity used during drilling and its conditioning.

TESTING WITHDST:

Runninginholetubingssinglebysinglefortubingflextriptocheckthe pressure integrityoftubingsandalsotoremovethedebris,tubing scales from tubings. Conventional perforation of the object through wire line of logging . RunninginofDSTstringfilledwithrequisitecolumnofcushionfluidto provide required drawdown. Rigging-up of surface equipments and lines and then pressure testing of the same.Settingofretrievablepacker.&.Pressurizingtheannulustoopen down hole PCT valve. Flowing back the well. Reservoirstudies(Virginpressurerecording,3beanstudies,build-up studies,gradientsurvey,PVTsampling)tobecarriedoutincasethewell becomes active. Stimulation job, if required, for skin removal.

In case, well does not become active, then pressure surging and keeping the well under observation. Reversing out for bottom hole sample collection through MCCV. After conclusive testing of the object, killing of well by bulldozing the well fluid into the perforation interval of the object tested. Opening SHORT. Reverse circulation of one string volume. Unseating the retrievable packer. Conditioning of the mud. Pulling out the production string. Isolation of the object by bridge plug / cement squeeze into object perforation. COMPARISON OF TESTING METHODOLOGY CONVENTIONAL VS TCP/DST/TCP & DST LIMITATIONS OF CONVENTIONALTESTING:

Formation damage due to mud filtrate invasion into formation after conventional perforation , Activity problems during running in hole of production string Inability to provide requisite drawdown, Longer time required for activation of sub-hydrostatic formations, Absence of additional down hole safety during testing of high pressure and H2S wells Inability to lower sand screens for testing of sand incursion prone objects and carrying out wire line jobs for bottom hole formation pressure recording and PVT sampling on floater rigs.WELL ACTIVATION Normallyperforations are carried out in over balanceRequireactivationVarioustypesof activation methods1.Displacement2.Compressor application 3.Nitrogenapplication 4.Swabbing CirculationofN2downtheannuluswithreturnsfromthetubingisthemosteffectivemethodofdisplacingfluidsfromthewell,as it leaves the least by-passedfluid on bottom. Maxsurfacepressureduringcirculationis reachedwhentheannulusiscompletely displaced to N2and theN2 turns the corner into the tubing. Nitrogenpumpingcanbediscontinuedatthis over balance point . The heavier the fluid, the more N2 isrequiredto circulate thewell. NITROGEN DOWN ANNULUS 50 NITROGEN DOWN ANNULUS Adj ChokeTesting with control head and packerCasing Tubing Return Tank Conventional packer-less testing with X-mas tree Conventionalpacker-lesstestingis carried out inLow pressure wells Christmasis installed and tested Activationperiodis longer thanDST test killfluidisconditionedandmadeavailable perforationsarecarriedoutto establishcommunicationfrom reservoir to well borewellisthenactivatedbycreating sufficient differentialpressure Ifwelldidnotbecomeactive, suitablestimulationjob is carried out. ifwellproduces,measurementare taken and then connected to GGS. TestingwithHydraulicpackerandX-mastreeisalsocarriedoutuptoa differential pressure of 7500 PSI. Conventionalperforationsarecarried out. Hydraulic packer along with tubing are lowered up to desired depth. N/D BOP and N/Up of X-mas treeDisplacementoftubingvolumeof liquidwith lighter fluids and setting of packer. Ifwelldidnotbecomeactive, furtherdrawdownandstimulationjob is carried outthrough CTU. Testing with X-mas tree and Hydraulic packerAdj ChokeTesting with control Head and Mech Packer TestingwithControlheadand mechanicalpacker is also carried out uptoadifferentialpressureof7500 PSI and3500F rating. Conventionalperforationsarecarried out.Mechanicalpackeralongwith tubing/Drillpipesareloweredupto desired depth. Displacement of tubing Volume of mud with lighter fluids. Setting of packer and flowing of well. Adj ChokeTesting with control Head and TCP-DST & RetrievablePacker TCP-DST with Control head andretrievablepacker is carried out uptoadifferential pressure of 10000 PSI and 3500F rating. Flex operation of string with BHA. RIHTCP-DST&BHAbyfillingstringwith water. Depthcorrelationforstringspaceoutfor gunsagainst perforations. Setting packer and confirmation. Perforation ofobject by hydraulic firing. Openwellandobserveforactivityand subsequent reservoir studies. Any further drawdown is required to be give only thru CTU. Adj ChokeHigh pressure Pumper Testing with control Head and TTV-J & Permanent packer 5,15K,4500F FlexoperationofstringwithBHAandtest up to desired pressure. Conventionalperforationinthedesired interval RIHHPHTpermanentpackerwithdepth correlation and setting at desired depth . RIH DST TTV-J& LTSA and string & carry out depth correlation. Stab into packer and land tubing hanger. N/ down of BOP and N/Up X-Mas tree. Displacementofmudinstringwith brine with CTU.(unconventional). Openwellandobserveforactivityand subsequent reservoir studies. Adj ChokeDST Testing with TTV-J& Control head15K,Offshore FlexoperationofstringwithBHAandtestupto desired pressure. RIHHPHTpermanentpackerwithdepth correlation and setting at desired depth . RIH TCP with TTV-J & LTSA . Space out the string so thatthe E-Z valve is placedagainst the BOP after stab-in of LTSA. Stab into packer and lock open TTV-J & stab-out. Displace tubing volume of liquid with lighter fluids. Stab LTSA inside the packer. confirm setting. Open well and observe for activity and subsequent reservoir studies.Any further activation or drawdown is possible only through CTU. Adj ChokeHigh pressure Pumper Testing with TTV-J&control Head and CTU FlexoperationofstringwithBHAandtestupto desired pressure. RIHHPHTpermanentpackerwithdepth correlation and setting at desired depth . RIH TCP & TTV-J with LTSA . Space out the string so thatthe E-Z valve is placedagainst the BOP after stab-in of LTSA. Stab into packer and lock open TTV-J & stab-out. Displace tubing volume of liquid with lighter fluids. Stab LTSA inside the packer. confirm setting. Open well and observe for activity and subsequent reservoir studies.Anyfurtheractivationoperationsiscarriedout throughCTU only. ( Unconventional)Adj ChokeTesting with DST Casing Tubing Return Tank Adj ChokeTesting with DST Casing Tubing Return Tank DSTconcepts Hydrostatic pressure PhCushionpressure PcFormation pressure Pf Packer to isolateformation Down-hole valve to control formation PTV Tubing or d/p to channel flow to surfacePFSV Reverse circulating valveSHRVDSTconcepts DST is used to carry out flow tests on prospectivehydrocarbon bearingzones.Thestringservesthepurposeofprovidingisolationofthree different pressures Hydrostatic pressure: Ph Formation pressure: Pf Cushion Pressure: PC During testing, hydrostatic pressure in the annulus must be isolated from formation and cushion pressure to allow the formation to flow. Packerprovidesisolationofthehydrostaticpressure(Ph)fromthe formationpressure(Pf)andthetestervalveisolatesthecushion pressure (Pc) from the formation pressure (Pf)Cushion Pressure (Pc)< Formation pressure (Pf)in order to flow to occur. It is doneby lighter density fluid filled in the string with tester valve closed.

LIMITATIONS OF CONVENTIONALTESTING:

Absence of any down hole safety during testing of high pressure wells. Absence of circulating mechanism Conventional TestingC/ Head & Mechanical packer Conventional perforations are carried out Tubings/Drill-pipes are lowered with Mechanical packer upto the desired depth. Control Head is hooked on to the Tubing/drill-pipe.Surface lines are connected to the control head and tested . Of OK Tubing volume of lighter fluids (water/Diesel/Nitrogen)are pumped through tubing . Packer is set by rotating and slackening the string with differential pressure in the string Well is openedand measurements are taken Ifwell did notbecomeactive, suitablestimulation jobis carried out if well produces, measurement are taken & then connected toGGSConventional TestingX-mas Tree & Hydrpacker Conventional perforations are carried out Tubingsare lowered with hydraulicpacker, POP,expansion joint &sliding sleeveupto the desired depth. N/Ddown of BOPand Install Christmas tree and test the flanges and valvesup to desired pressure. If OK.Surface lines are connected to the X-mas treeand tested . if OK Tubing volume of lighter fluids (water/Diesel/Nitrogen)are pumped through tubing .Packer is set by dropping the ball and pressurizing string to the desired pressures Well is opened thru suitable choke and measurements are taken Ifwell did notbecomeactive, suitablestimulation jobis carried outConstraints in conventional Testing X-mas Tree & Hydrpacker Slidingsleevesarenotworkinginthemudsystemproperly,hence not being usedin the mud .In the absence ofreverse circulating mechanism, killing is done by making puncture in the tubing. Sincemudisusedintheannulus,retrievalhasbecomeproblem and often landing in to fishing problem. Duetodeviationofthewells,torquenotbeingtransmittedtothe bottom and further being complicated. Highpressurehydraulicpackersarenotavailable.Maxd/pis7500 PSI only. Constraints in Testing with Control head & Mechanicalpacker

Thetopmostconnectionbelowcontrolheadandtubingis susceptible to leakage as no proper torque can be given In case of leaks at surface during flow,nodown hole safety valve is available to control the flow. HighpressureMechanicalpackersarenotavailable.Maxd/pis 7500 PSI only. Conventional Testing packer less Conventional perforations are carried out Tubings/Drill-pipes are lowered to the desired depth. N/Ddown of BOPand Install Christmas tree and test the flanges and valvesup to desired pressure. If OKwell is thenactivated by creating sufficient differentialpressure bydisplacing with lighter fluids like water, air/Nitrogen. Ifwell did notbecomeactive, suitablestimulation jobis carried out if well produces, measurement are taken and then connected to GGS DRILL STEM TEST(DST) Temporary completion to determine characteristics of a well control head is installed in stead of x-mas tree Cushionis maintained during running inafter lowering up to desired depth, tool is operated andwell is flowed for short durationto analyze the characteristicsWELL COMPLETIONWell completion should be aimed at safety, operability and simplicityInfluencing factorsreservoir parameters Operating requirementsoperating field conditions workover method/ stimulation method well intervention by CTU environmental problemsgovernment legislation SafetyTESTING EQUIPMENTDOWN HOLE EQUIPMENT1. TUBING 2.CIRCULATIONDEVICE 3.PACKER LOCATOR SEALS 4.PACKER5.SEATING NIPPLES 6.NO GO SEATING NIPPLE 7.PUP JOINT 8. WIRELINE ENTRY GUIDE SURFACEEQUIPMENT1. X-MAS TREE2.CHOKE MANIFOLD 3.SEPERATOR/HEATER A device that can be run into a wellbore with a smaller initial outside diameter that then expands externally to seal the wellbore. Packers employ flexible, elastomeric elements that expand. The two most common forms are the production or test packer and the inflatable packer. The expansion of the former may be accomplished by squeezing the elastomeric elements (somewhat doughnut shaped) between two plates, forcing the sides to bulge outward. The expansion of the latter is accomplished by pumping a fluid into a bladder, in much the same fashion as a balloon, but having more robust construction. Production or test packers may be set in cased holes and inflatablepackersareusedinopenorcasedholes.They may be run on wireline, pipe or coiled tubing. Some packers are designed to be removable, while others arepermanent.Permanentpackersareconstructedof materials that are easy to drill or mill out. They are used when tubing movement is expected because of temperature & pressure changes during the production phase or during the stimulation in a well. These are available with various stroke lengths. Opening & closing strokes are fixed as per the operating requirement in a particular well.EXPANSION JOINTSA seating nipple is a threaded length of pipe with a smooth, polished bore containing one or more specialized horizontal grooves, called locking grooves to receive the spring loaded locksofthewirelinetools.Thegroovesareofspecified sizestoaccommodatetheparticularwirelinetoolsofthe same size.Purpose of using Landing Nipples:1. The no go nipples prevent wire line tools larger than the no-go dimensions from being run below the tubing.2.Certainflowcontrolequipmentslikebottomholechoke, standingvalve,blankingplug,surgeplugetc.canbe installedinthelandingnippletocontrolthefloworisolate anyunwantedproducingzone(suchasinastraddle completion).LANDING NIPPLE/SEATING NIPPLE It is generally runatthe bottom ofthe tubing string & acts as tubing shoe.Ithasaseattoaccommodatetheball&theseatis lockedinpositionbyshearscrewsofspecifiedshear values.Theballdroppedforsettingthepackersitson thisseat&ensuresaleakproofsystem.When hydraulicallypressurizedfromthesurfacethepacker sets at a certain predetermined pressure. Then more & morepressureisappliedtoshearalltheshearscrews to allow the seat of the P.O.P to fall along with the ball in the sump.The P.O.P has generally a bevelled profile at the bottom toallowloggingtooltobelowered&pulledout smoothly.PUMP OUT PLUG (P.O.P) They are made on the tubing string at points where circulation between the tubing & annulus is needed. A shifting tool on wire line is used to slide the sleeve open or closed.They may be used above the packer for circulation or changing over of completion fluid or can be used between packers to produce the zones selectively. They can be used to install jet pumps, bottom hole chokes etc.SLIDING SLEEVE They have a polished receptacle/pocket at one side to receive down hole tools lowered by wire line or fitted at the surface.They are used for:1. Install a gas lift valve (GLV).2. Install a chemical injection valve.3. Install a down hole choke.4. Provide circulation between tubing & annulus when required.SIDE POCKET MANDRELS (MMGS & KBMGS)Subsurface controlled subsurface safety valve (scsssv) are used as a safety device to shut in the well in the event that surface systemsaredamagedorareremoved.Itisapartofthe completion hook up & may be of the following two types:1. Wire line retrievable 2. Tubing retrievable.Bothofthesevalvesarecontrolledfromthesurfacebythe hydraulicpressuresappliedthruexternalcontrollinewhich runsfromSCSSSVtowellheadalongsidetubingstring.When thecontrollinepressureisbledoff,valveclosuremechanism causes the SCSSSV to close.SAFETY VALVES (SCSSSV) Surface control units, which supply the hydraulic pressure, also monitoranyabnormalincreaseordecreaseintheflowline pressure.SCSSSVshouldshutdownwellwhenactivatedbyanFSD system,topreventuncontrolledwellflowintheeventof emergency situation.ADVANTAGES 1. Controlled from the surface & hence can be manipulated easily.2. Valves are designed to close regardless of tubing pressures.3. Most type has a large bore to permit high flow rate. Sub Sea Test tree (SSTT) is a mandatory safety equipment for use during testing on floater rigs which allows the subsurface closure of well, detaching of the string and moving away of the rig from location in case of any emergency such as blowout, adverse weather condition. Once the emergency is over, the testing can be resumed by moving the rig on location and latching the string.

SUB SEA TEST TREE (SSTT) EQUIPMENT: Periodic Production Tests Productivity or Deliverability Tests Transient Pressure Tests

Classification of WellProduction TestingDeterminationoftherelativequantitiesofoil, gas and water produced under normal producing conditions.Theyprovideperiodicphysicalevidenceofwell conditions.Unexpectedchanges,suchas extraneous wwater or gas production may signal wellorresrvoirproblem.Abnormalproduction declinemaymeanartificialliftproblems,sand fillupinthecasing,scalebuildupinthe perforations Periodic Production Tests Accuracyofmeasurementsandcareful recording of the conditions of which the test was run are of utmost importance. Choke size, Tubing pressure,casingpressure,everythingthatis affecting the ability of well to produce should be recorded. Periodic Production Tests Productvity or Deliverability Tests This test isperformed on initial testing or re-completion todeterminethecapabilityofthewellundervarious degrees of pressure drawdown. Results aid in selection of wellcompletionmethods,designofartificialliftsystems and production facilities. Theyinvolveaphysicalorempiricaldeterminationof producedflowversusbottomholepressuredrawdown. Withalimitednumberofmeasurementstheypermit productionofwhatthewellshouldproduceatother pressure drawdown. Productvity or Deliverability Tests This test isapplied to non darcy, below the bubble point flow conditions. Even though fluid properties and relative permabilitiesarenorconstantaroundthewellbore. Deliverabilitytestrepresentsstabilizedproducing conditions.Itinvolvethemeasurementofbottomhole and flowingpressures as well as fluid rates produced to the surface. Commonly used deliverability tests are:Productivity Index Inflow performance Flow after Flow Isochronal Productvity Index It is the simplest form of deliverability test. Involves the measurement of shut in bottom hole pressure and at one stabilizedproducingcondition,measurementofthe flowing bottom hole pressureand the corresponding rate ofliquids produced at the surface. PI: J= q/pi-pwf Productvity Index Productivity index declines during the life of a wellReservoir Pressure Composition and properties of produced fluids. Flow restriction Formation damage near well bore.Withawellproducingabovethebubblepoint,thePI maybeconstantoverwiderangeofpressure drawdown.Withaflowbelowbubblepointandgas occupyingaportionofporesystem,PIfallsoffwith increased drawdown. Productvity or Deliverability Tests Gaswelldeliverabilitytestsaredesignedtoestablish the absolute open flow potentialor the production rate if theflowingbottomholepressurecouldbereducedto zero.Thesearebackpressuretestsandcanbeclassifiedin to :Flow after flow IsochronalThesetestsrequirehighdegreeofsophisticationand areusedtodetermineformationdamageorstimulation related to an individual well or reservoir parameters such as permeability, pressure, volume and heterogeneities . Transient PressureTests Introduction Deep,HPHTwellsarebeingdrilledbyKGonland,KGoffshore, CauveryBasin, Mumbai offshore Basin , Western onland basin . Well heads and X-mas trees are procured by Basin. There is no standard procedure/ approved design forX-mas tree, Tubular / down-hole tools Well Services of each Asset/Basin making ad-hoc plans to testthese wells. EachAssetisprocuringmaterials/hiringtherequiredservicesdepending upon the work programmeofrespective basin. Testingbydifferentmethodsisfolloweddependinguponthe requirement and availability of equipment. One mega contract with M/S Schlumberger is available forDST services up to 2013 with logging Services . 94 Present practices in ONGC Conventional packer-less testing with X-mas tree Low pressures Mechanical packer with control head up to 7500 PSI DP & 3500F. Hydraulic packer with X-mas tree up to 7500 PSI DP & 3500F. PermanentpackerwitheitherX-mastreeorcontrol-headupto 10,000 PSI DP and 4000F. DST(Multi-cycle)withRetrievablepacker&controlheadorX-mas treeup to 3500F & 10K DST(singlestage)with10K,4000Fpermanentpacker&control head / X-mas tree. DST(single stage)withTTV-J, 15K,4500F permanentpacker,control head/X-mas tree. 20,133/8,9-5/8, 7 Water based mud systems(barite/Haematite) Prototype EKDS BasicLWD Limited bit selection Standard well control methodology Limited computational capabilities DExponent Drilling and well control procedures-early days Verylittledifferencefromnormalpressure/temperatureexplorationwell design 1991 HPHT 96 Challenges in HPHT well TestingOperationsclosertodesignlimits-load,stress,Pressureand temperature. Narrow PP-FG marginsrequiring manycasing strings SeriousConsequences- Emergency shutdown facilitiestobein place. Extreme component stress in hardware. Dealing with very high density well control fluids. Amplification of partial pressure of corrosiveconstituents. Material degradation at elevated temperature Higher thermal gradients and associated stresses . Material selection and environmental cracking. Trapped volumes and thermal expansion. 97 Challenges in HPHT well TestingProduct reliability. Seal Integrity. Metallurgy Electronics( circuit boards and Sensors) Packer to casing seal reliability due to highly variable casing quality. Design life, time, operation cycles, wear, corrosion, erosion rates Very high partial pressures of H2S & CO2. Higher thermal gradients and associated stresses . 98 Observation on practices followed by others Fit for purpose casing to facilitate production operations. Avoidanceof slim hole drilling due to non availability oftools. Resourcesandequipmentrequiredfordrillingandtestingare identified and made available before start of the project. ( M/S Cairn-JV) Additional safety factorduring design of casing. Use of metal to metal sealTubular. Use of NACE material tubular for BHP more than 15000 PSI. UsageofcomputercontrolledTorqueturnformakingup/breakupof tubing. Use of fresh wateras packer fluid(Elgin-Franklin) Use of Multi Cycle DST toolsforwell Testing( M/S GSPC) tested kept Use of Calcium Bromide as testing fluid (GSPC) Use of Packer & SCSSV for completion( Ras Gas, Elgin-franklin, Petronas)WELL COMPLETIONWellcompletionshouldbeaimedatsafety,operabilityand simplicityInfluencing factorsReservoir parameters Operating requirementsOperating field conditionsWorkover method/ stimulation methodWell intervention by CTU Environmental problemsGovernment legislation Safety100 Inventory of packersMechanical packers: 7500 PSI, 3500F . Hydraulicpackers: 7500 PSI, 3500F . Permanent Packers :10,000 PSI, 4000 F (BOTIL) Permanent Packers :15,000 PSI, 4500 F (Baker) Multi-cycleDSTwithretrievablepackerupto4250F10KDPofM/S Schlumberger is in the mega contract but being operated only up to 3500 F. SingleshotDSTwithTTV-Jupto4500F,15KDPofM/S Schlumbergerisinthemegacontractbutbeingoperatedonlyup to 3500 F. 101 Inputs requirements Well Testing & Completion Down-holeequipment's : Production tubing's of suitable size & rating Packers for isolation Expansion joints/sliding sleeves/D-Nipples Cross overs Pup joints 102 Inputs requirements Well Testing & Completion Surface equipment's : Well Control head Well choke manifold Heater/Glycol Injection system Test separator Treating iron, Co- flexible HP. Typical DST Thetypicaldrillstemtestwillbesplitintofourperiod,Pre flow.initial shut in period, a main flow period and a final shut in period. Times of for each test are dependent on conditions at the well site Drill stem tests may be run at any time during thedrillingoperationatthecurrentdepthormaybeusedto test any interval in the hole after TD has been reached. Using thesedataandbasedontheevaluationofengineersand geologists, management can base a decision to complete the holeforpotentialproductionofoilorgasorproceedwith abandonment. Pre-Flow Period isaproductionperiodtocleanupthewelland is used to remove any supercharge given to the formationduetomudinfiltratingintothe prospectiveformationduringthedrilling operation. Initial Shut In Thisperiodistoallowtheformationtorecover frompressuresurgescausedduringthepre flow. this is often referred to as "closed in for the pressure build up" this period will belonger. Main Flow a more lengthy production period designed to testtheformationsflowcharacteristicsmore rigorously.Samplesofanyfluidswillbe checkedforwatercontentGasbubblebust pressuretemperatureandmanyothernice surprises.Thiswillbedoneusingsetchoke or variable chokes. Samplereaching surface willbemeasuredastovolumeandgathered foranalysisinalaboratory.Samplesofany fluids in the drill string at the conclusion of the testwillbemeasuredastovolumeand gatheredforanalysis.Flowingpressuresand temperatures will be recorded. Final Shut-In formationpressureisrecordedoverthisperiod. The shape of the pressure build up curve will tell usthepermeabilityoftheformation,thedegree offormationdamage(likelycausedduringthe drillingoperation),Itwillalsotellusifwehave found a small reservoir but there is no telling if it a big one. 108 Thank You