1887

Abstract

Summary

This paper describes a successful program of lab and pilot-scale studies qualifying a new shear-resistant, high-injectivity, reservoir-triggered polymer (Polymer) for field trial. The Polymer mitigates two of the major operational and economic challenges facing polymer flooding applications for mobility control, namely, shear degradation during injection and reduced fluid injectivity.

Shear degradation of conventional HPAM polymers through injection facilities can result in dramatic losses of up to 70% of viscosity yield. However, this can be eliminated using the new Polymer. This is particularly important in an offshore environment where highly-shearing subsea chokes are required for flow distribution control.

The Polymer formulation uses a novel yet inexpensive chemical approach enabling it to inject with near-water viscosity in a shear-resistant form. The Polymer has been engineered such that it does not viscosify the injection fluid until it is triggered in the reservoir away from the near wellbore region. Higher injection rates and viscosities can therefore be attained than would otherwise be possible with a conventional polymer flood.

Methods:

The Polymer’s triggering performance in porous media under both static and dynamic conditions has been demonstrated. The un-triggered Polymer has been subjected to extremes of shear at both lab and pilot-scale to test shear resistance. Injectivity of the Polymer has been assessed through an extensive suite of sand pack and coreflood experiments. Tests have also been conducted to verify the Polymer’s suitability for field deployment including surface storage, inversion, and long-term reservoir stability.

Results:

The Polymer is completely shear-resistant during injection, demonstrated by flowing through a scaled choke with pressure drops exceeding those expected during deployment. The viscosity of the un-triggered Polymer solution has been shown to be almost independent of the Polymer concentration, injecting with a viscosity close to that of sea water and giving excellent injectivity into sand packs and cores. In addition, the Polymer has been demonstrated to inject, propagate and trigger to deliver a pre-determined viscosity in a temperature-controlled 40ft sand pack experiment. The Polymer solution is easily and reliably prepared, out-performing a conventional HPAM in a pilot-scale inversion study, and demonstrates storage characteristics above the industry standard. A 15 month-long stability test performed at reservoir temperature with reservoir fluids showed minimal loss of viscosity.

Testing will now proceed to field trial. If successful, this new technology offers a route to overcoming some of the key obstacles to large scale polymer EOR deployment, particularly in the offshore environment.

Loading

Article metrics loading...

/content/papers/10.3997/2214-4609.201700287
2017-04-24
2024-03-29
Loading full text...

Full text loading...

References

  1. API Recommended Practice 63
    [19901 Recommended Practices for evaluation of polymers used in enhanced oil recovery operations, First edition, June 1, 1990, American Petroleum Institute, 1220 L Street, Washington DC 20005.
    [Google Scholar]
  2. Caulfield, M.J., Oiao, G.G., and Solomon, D.H.
    [2002] Some Aspects of the Properties and Degradation of Polyacrylamides. Chem. Rev. 102 (9): 3067–3084.
    [Google Scholar]
  3. Gogarty, W. B.
    [1967] Mobility Control with Polymer Solutions. SPE J. 23 (3): 475–485.
    [Google Scholar]
  4. Maerker, J.M.
    [19751 Shear Degradation of Partially Hydrolyzed Polyacrylamide Solutions. SPE J. 15 (4): 311–322. SPE-5101-PA
    [Google Scholar]
  5. Sorbie, KS.
    [1991] Mechanical stability of polymers. In Polymer-Improved Oil Recovery, ed. Chap. 4.4, 114–124. Glasgow, Scotland: Blackie &Sons/CRC Press.
    [Google Scholar]
  6. Seright, R.S., Adamski, R.P., Roffall, J.C., and Liauh, W.W.
    [1983] Rheology and mechanical degradation of EOR polymers. Presented at the SPEI British Society of Rheology Conference on Rheology in Crude Oil Production, Imperial College, London, 13–15 April.
    [Google Scholar]
  7. Seright, R.S.
    [1983] The Effects of Mechanical Degradation and Viscoelastic Behavior on Injectivity of Polyacrylamide Solutions. SPE J. 23 (3): 475–485.
    [Google Scholar]
  8. Willhite, G., and Green, D.
    [1998]. Enhanced Oil Recovery. Society of Petroleum Engineers.
    [Google Scholar]
http://instance.metastore.ingenta.com/content/papers/10.3997/2214-4609.201700287
Loading
/content/papers/10.3997/2214-4609.201700287
Loading

Data & Media loading...

This is a required field
Please enter a valid email address
Approval was a Success
Invalid data
An Error Occurred
Approval was partially successful, following selected items could not be processed due to error