High Angle HPHT Wells

Gjonnes, Morten; Myhre, Inge G.

doi:10.2118/95478-ms

Cited by 8 publications

(2 citation statements)

References 0 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…In addition, a low pumping rate requires a slurry design with longer thickening times which needs more chemicals as retarders at high temperature conditions as high temperature accelerates the hydration process. As a rule of thumb, the more retarders used the more side effects on properties of the cement [38,39]. So, HPHT wells require special consideration during abandonment design.…”

Section: High-pressure High-temperature Wellsmentioning

confidence: 99%

General Principles of Well Barriers

Khalifeh¹,

Saasen²

2020

Ocean Engineering &Amp; Oceanography

View full text Add to dashboard Cite

Section: High-pressure High-temperature Wellsmentioning

confidence: 99%

General Principles of Well Barriers

Khalifeh¹,

Saasen²

2020

Ocean Engineering &Amp; Oceanography

View full text Add to dashboard Cite

“…The subsea template structure is designed so that the well structure is independent from the template and therefore will not cause any damage for the template structure itself. The movement of the well structure will be taken up by the flexible connection between the x-mas three and the production manifold (Gjonnes and Myhre 2005).…”

Section: Well Growth Due To High Temperaturementioning

confidence: 99%

HPHT 101 - What Every Engineer or Geoscientist Should Know about High Pressure High Temperature Wells

Shadravan

Amani

2012

All Days

View full text Add to dashboard Cite

The high-profile blowout at Macondo well in the US Gulf of Mexico, brought the challenges and the risks of drilling into high-pressure, high-temperature (HPHT) fields increasingly into focus. Technology, HSE, new standards, such as new API procedures, and educating the crew seem to be vital in developing HPHT resources. High-pressure high-temperature fields broadly exist in Gulf of Mexico, North Sea, South East Asia, Africa, China and Middle East. Almost a quarter of HPHT operations worldwide is expected to happen in American continent and the majority of that solely in North America. Oil major companies have identified key challenges in HPHT development and production, and service providers have offered insights regarding current or planned technologies to meet these challenges. Drilling into some shale plays such as Haynesville or deep formations and producing oil and gas at HPHT condition, have been crucially challenging. Therefore, companies are compelled to meet or exceed a vast array of environmental, health and safety standards. This paper, as a simplified summary of the current status of HPHT global market, clarifies the existing technological gaps in the field of HPHT drilling, cementing and completion. It also contains the necessary knowledge that every engineer or geoscientist might need to know about high pressure high temperature wells. This study, not only reviews the reports from the Bureau of Ocean Energy Management, Regulation and Enforcement (BOEMRE) and important case studies of HPHT operations around the globe but also compiles the technical solutions to better maneuver in the HPHT market. Finally, the HPHT related priorities of National Energy Technology Laboratories (NETL), operated by the US Department of Energy (DOE), and DeepStar, as a strong mix of large and mid-size operators are investigated. Introduction:

show abstract

Reduced Solids Oil-Based Completion Fluid for Horizontal HPHT Openhole Completions

et al. 2011

View full text Add to dashboard Cite

A 1.9 SG oil-based fluid for suspending open-hole pre-perforated liner completions in 1100 m long, horizontal openhole sections, under HPHT conditions (162°C, +800 bar reservoir pressure) has been engineered for the Morvin field development. The main challenge was to provide this fluid with sufficient stability so that it still was mobile when wells were backproduced after up to 4 weeks of subsequent well completion activities. The main drivers for the development were the constraints that alternative fluid concepts pose under such conditions. Standard oil-based fluids weighted with barite, under the prevailing conditions up to 1.4 tons per cubic-meter of fluid, showed to be highly instable under simulated reservoir conditions. Barite settled out and deposited thick immobile mud bodies that were potentially completion damaging. Other fluid alternatives such as Cesium-formate weighted water-based suspension fluids were suspected to be incompatible with the selected oil-based reservoir drilling fluid. Based on previous experiences with low solids (barite free) oil-based completion fluids (screen running and perforation fluids), a so-called "reduced solids oil-based completion fluid" was engineered in cooperation with the fluids contractor. The main features of the fluid were a close-to 50/50 oil-to-brine ratio, a Cesium-formate internal brine phase and fine barite to weigh up the fluid to approach the required weight. Several variations of this fluid were rigorously tested to evaluate stability and mobility of fluid sample samples. The fluid has so far successfully been used on three completions. This paper reports in detail on the fluid development process, operational experiences and well-clean-up observations.

show abstract

High Angle HPHT Wells

Cited by 8 publications

References 0 publications

General Principles of Well Barriers

General Principles of Well Barriers

HPHT 101 - What Every Engineer or Geoscientist Should Know about High Pressure High Temperature Wells

Reduced Solids Oil-Based Completion Fluid for Horizontal HPHT Openhole Completions

Contact Info

Product

Resources

About