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Advanced Applications of Wireline ppCased-Hole Formation Testers
Adriaan Gisolf, Vladislav Achourov, Mario Ardila, Schlumberger g
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Agenda
Introduction to Cased Hole Formation testerIntroduction to Cased Hole Formation testerTool specificationsA li tiApplicationsZonal Isolation examples Cement Integrity Formation Integrity A l i ti ti Annulus investigation
Conclusions
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Cased Hole Dynamics Tester (CHDT)
Designed to drillDesigned to drill through casing through cement into the formation into the formation
To measurei reservoir pressure
take fluid samples downhole fluid properties
And to plug the hole10K i bi di ti l l 10Kpsi bi-directional seal
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Specifications
Casing 5 1/2” to 9-5/8” (tool OD = 4 1/4”). Telemetryg ( ) Up to 6 holes drilled & plugged Hole diameter = 0.28”, penetration = 6”
M t 175 d C / 1375 b P S l7.9’
Optional GR or CCL
Max. temp. 175 degC / pressure 1375 bar. Plug pressure rating = 700 bar bi-directional Overbalanced or underbalanced operation (275 bar)
Power Supply7.9189 lbs
Overbalanced or underbalanced operation (275 bar) Pretest volume = 100cc (re- cyclable) Low-shock PVT sampling*
Drilling Controller
9’232 lbs
Downhole realtime fluid properties*Probe Module
13.3’370 lbs370 lbs
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Advanced design
Plug in Casing Revolver Packer Flexshaft
6 holes per run Packers to cover 6 holes per run
Max. 2 modules*
Packers to cover casing range (5 1/2” to 9 5/8” OD)
375 bar bi-directional metal-metal seal
Radial expansion of cup as pin is inserted
Consists of several layers of spring wire wound around a central mandrel
Highly flexible in bending - torsionally stiffS ll di t 3/16”cup as pin is inserted Small diameter: 3/16”
Tungsten carbide bit
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Applications
Conventional applicationsConventional applications Bypassed hydrocarbons Multi-Layer reservoir pressure monitoring Multi-Layer reservoir pressure monitoring New wells with difficult conditions
Advanced applications Zonal isolation studies Zonal isolation studies Stress testing Annulus pressure investigation Annulus pressure investigation
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Case 1 –Testing isolation between zones
Seawater injected to support productionj pp p Tripling current injection rate will eliminate
need for additional injection wells or workovers
CHDT High K Layer
workovers Poor cement coverage across injected
formation and high permeability neighboring formation
Poor CementConditions
7” casing
formation Several attempt to squeeze proppant and gel
into the annulus unsuccessful
QwInjection
Layer Under 62
Tool conveyed with Tractor (62 deg)
Increase injection feared propagate and frac the cap rock Perforations
injection62
Tool conveyed with Tractor (62 deg)
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Results CHDT showed communication between formations Maximum safely achievable injection rate was estimated Maximum safely achievable injection-rate was estimated Injection rate tripling not possible
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Case 2 –Testing communication between zones
Deviated reservoir section completed Water Upper FormationWater pwith 7 inch liner
Injection through A - formation Unknown connectivity between B and
InjectionUpper Formation
A - Formation Low Permeability
Injection
yoverlying A formation
B formation potentially pressurized Future drilling plans through the B
CHDT
Barrier
Upper B Future drilling plans through the B formation planned with equipment of limited pressure rating
Max. deviation 81 deg, 45 deg at B
Lower Formation 1
Lower Formation 2
Upper B Formation
Lower B Formationg, g
formation. Tool conveyed with tractor Good cement identified through
ultrasonic logultrasonic log
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Case 2 - Testing lower B formation
ObjectivesObjectives Identify communication between reservoir under injection and lower intervals. Determine representative reservoir pressuresp p
Lower B formation operational sequence A hole was drilled though the casing cement and formation A hole was drilled though the casing, cement and formation CHDT pressures monitored in real-time to allow injection sequences optimization Formation pressure observed after the drill bit penetrated casing, cement & formation
P t t t k t fi th f ti f 291 b Pretest taken to confirm the formation pressure of 291 bars Seawater injected at four different rates into the upper A formation Drilled hole was plugged and tested to 170 bar differential pressure
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Case 2 - Testing lower B formation
No pressure response observed on the CHDT during injection, indicating that the lower B formation was not in communication with the A formationlower B formation was not in communication with the A formation
CHDT P = 303 bar
BHP cal = 309 bar
Max tubing BHP 535 bar, constant 291 bar at CHDT
CHDT P = 291 barAfter drilling
BHP cal = 309 bar
230 m3/hrInjection rate
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Case 2 - Testing upper B formation
Upper B formation operational sequenceUpper B formation operational sequence After drilling casing, cement and formation the pressure stabilized
quickly at 317.5 bars, then slowly decreasedTh f ll ff b d th f The same pressure fall-off was observed on the surface gauge
Two hours of injection into the upper A formation followedTwo hours of injection into the upper A formation followed The CHDT gauges reacted directly and consistently to the injection
Drilled hole successfully plugged off and tested Upper B formation definitively in pressure communication with A
formation
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Case 2 – Testing upper B formation
CHDT P = 323 bar BHP cal = 324 bar
Quartz gauge swapped to measure inside wellbore Match with BHP cal
Fall off inside llb dwellbore and
CHDT
Start injection, immediately pressure response
After drilling, CHDT P = 317,5 bar BHP cal = 320 bar
2 hr Injection test @ 48 m3/hr
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Case 2 - Testing communication between zones
Maximum formation Maximum formation pressure in both upper and Lower B formation meas red
WaterInjection
Upper Formation
A - Formation Low Permeability
Water Injection
measured
Barriers between lower B Upper B Barriers between lower B, Upper B and A formation redefined
Upper B Formation
Lower B Formation
BarrierUpper B Formation
Lower B Formation
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Case 3, CHDT shale integrity testing
Poor isolation due to bad cement job could result in plugging back and j p gg gside tracking of this well
Overburden shales are relatively weak and prone to collapse in this Overburden shales are relatively weak and prone to collapse in this field.
If th k b d h l h d ll d d th i d if it If the weak overburden shale had collapsed around the casing and if it could be tested for integrity then it may be classified as a well integrity barrier, saving a sidetrack.
Isolation Scanner used to identify collapsed shale. Then shale was “stress tested” with use of CHDT tool, confirming shale integrity and it’s average stress.
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Case 3, CHDT Shale Integrity Testing
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Case 3, CHDT Shale Integrity Testing
pressure propagation
CHDT Gauge pressure
Flowline resistivityMotor speed
Volume
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Case 3, CHDT Shale Integrity Testing
Linear fit
Fracture closesFracture closes Linear fit
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Case 3, CHDT Shale Integrity Testing
The stress-testing results confirmed over two cycles The stress testing results, confirmed over two cycles, suggested that: there is no communication through the annulusg the collapsed shale provided zonal isolation. The results of
the job satisfied the annular barrier regulations.
The operator did not have to side track the well.
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Example 4 - ProblemProblem Wellbore annulus pressurized due to leaky cementWellbore annulus pressurized due to leaky cement Annulus production rate 2,7l/min crude oil Unknown pressure behind 9 5/8” casing
P ibl t hi h f i illi – Possibly to high for casing milling – Annulus fluid type unknown without pressure – Origin of the leak required fluid type
CHDT SET DEPTH
– Bottoms up circulation, required for accurate fluid identification, would require over 1 year.
Solution CHDT on TLC to measure annulus pressure
F d th & P th l fl id t d From depth & Pressure the annulus fluid type and origin can be determined
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Example 4 - CHDT station data
Seal test Formation penetration
drilling
p
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Example 4 - zoomed CHDT data
Stable annulus pressure, 269.3 barPressure communication to surface established
Start Bleeding annulus pressure at surface
to surface established
Annulus fluid was determined to be crude oil from the Brent reservoir
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Conclusions
Cased hole formation testers have been successfully used for Cased hole formation testers have been successfully used for many formation testing and sampling applications.
The following Zonal Isolation examples were discussed:C t I t it Cement Integrity
Formation Integrity Annulus investigation