Narrow Pressure Margin

DeepAssurance™ Cementing Solution SuiteThe margin between pore pressure and fracture gradient can be as low as 0.2 in offshore wells, particularly deep water wells.  Slim-hole and tight-annulus wells can create or compound the challenges of already narrow pressure margins. Formations with low fracture gradients can break down under the hydrostatic pressure of the drilling fluid or cement column and can result in lost circulation.  The probability of maintaining circulation throughout cement placement operations can be higher when employing options such as lightweight systems and/or alternative placement methods. 

Filter By  
Show     results per page
  Title Date
Summary Permanent Plug Back - Setting a Plug through the BHA - New Zealand Offshore Aug 2014
Summary WellLock Resin provides well integrity to withstand forty-two fracturings stages Aug 2014
Showing 1 - 2 of 2 Records

Solutions for Narrow Pressure Margin

Cement and Resin

ChannelSeal® Process
Latex 2000™ Cement Additive
Latex 3000™ Cement Additive
LockCem™ and LockSeal™ Cement Systems
SentinelCem™ Cement
Tuned® Light Cement
WellLock® Resin
ZoneSeal® Isolation Process

Lost Circulation Materials

BridgeMaker™ LCM Spacer Fluid
FlexPlug® Lost Circulation Service
FLO-CHEK® System
PhenoSeal™ Lost Circulation Material
SentinelCem™ Cement
STEELSEAL® Lost Circulation Material
Thermatek® Fluids
WellLife® 734 Additive
WellLife® 708 Additive

Casing Equipment  
Commander™ 1000 Top-Drive Cementing Head
Fidelis Stage Cementer
Isolizer™ Centralizer
SuperFill™ Auto-Fill Equipment
The Protech™ Centralizer Family of Products
VersaFlex® Low ECD System

Narrow Pressure Margin Challenges

Narrow Pressure Margin Challenges If Unaddressed
Achieve successful zonal isolation with sub-optimum wellbore conditions and/or operational constraints (i.e. no pipe rotation or reciprocation; low pump rates for mud conditioning and cement placement; lost circulation/thief zones; low cement tops; high friction pressure during pumping).

Resulting issues may include formation damage, lost circulation, low top of cement, inter-zonal communication that may require remediation.

Efficient mud removal and water-wetting of surfaces. Fluid contamination, fluid swap or channeling can result in annular pressure buildup or loss of production due to inadequate zonal isolation.  Compromised zonal isolation, potentially compromising completion operations and producing life of the well.
Under-reamed holes.

Poor centralization with insufficient standoff once past the narrow section; poor mud removal. 

Formation breaking down under the hydrostatic and friction pressure of the fluid column and/or surge and swab – or – gas or fluid influx including gas channeling to surface.

Partial or complete loss of circulation; difficulty achieving top of cement; compromised well integrity; excessive rig time to run casing to depth.

Slurry design for optimized rheology, density, and compressive strength. Compromised well integrity at any point during the life of the well.
Pressure fluctuations when darts or plugs are released. Interruptions in pumping so that darts or plugs can be released, creating potentially damaging surge pressures.
Related Information

Related Information

Follow Us:
Job Openings
Halliburton. All Rights Reserved. | Terms of Use | Privacy Statement | Garnishment | Site Map
Halliburton. All Rights Reserved.