Development and Field Testing of a Unique High-Temperature/High-Pressure 
(HTHP) Oil-Based Drilling Fluid With Minimum Rheology and Maximum Sag Stability

Taugbøl, Knut; Gunnar, Fimreite; Prebensen, Ole; Svanes, Kåre; Omland, Tor Henry; Svela, Per; Breivik, Dag

doi:10.2523/96285-ms

Cited by 9 publications

(10 citation statements)

References 0 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The sag stability of the TMB OBM system, which is a high density and stable liquid suspension of micronized weight material 4,5,6 was tested in the laboratory with promising results after 16 and 160 hr (Table 6). To prepare the liquid suspension of micronized weight material, barite is milled to a D 50 of ±1 micron and when the milling process is complete, the barite is no longer in a dry state as liquid chemicals are added to turn this into slurry.…”

Section: Drilling Fluid Evaluationmentioning

confidence: 99%

Improve Drilling Performance by Controlling Risk and Reducing Non-Productive Time in a Challenging High-Temperature, High-Pressure Well

Prebensen

Vidvei

Nesheim

et al. 2009

SPE/IADC Drilling Conference and Exhibition

View full text Add to dashboard Cite

To complete a very challenging high-temperature, high-pressure (HTHP) well in the North Sea, several engineering issues needed to be resolved before commencing drilling. One of the requirements of the well was to drill without replacing the existing drill pipe on location. Changing the drillpipe specification would result in extra tripping time and a high increase in cost. As the hydraulic window was narrow, maintaining the configuration of the drill pipe limited the equivalent circulating density (ECD). At the same time, the temperature regime was high; a specific oil-based drilling fluid (OBM) with treated micronized barite (TMB) was chosen as the only solution to resolve these challenges. In combination with this specific drilling fluid, the operator decided to utilize simulation software that enabled real-time hydraulic values to be displayed during the entire HTHP operation.The drilling fluid with micronized barite provided several benefits compared to conventional OBMs. A more conventional drilling fluid meant a significantly higher viscosity to maintain the weight material in suspension, thereby increasing the circulating pressures and ECD. As the micronized barite viscosity profile is low, even at high densities, tripping speeds were dramatically increased as compared to offset wells. This includes tripping in and out with drilling assembly and during running of casing. Furthermore, the viscosity of such a fluid enables any flow checks to be completed much faster, thereby reducing time spent. Additional benefits such as zero barite sag, low maintenance of the system and the elimination of expected circulating time to condition the fluid after a 10-day long static period were all part of this successful well completion.

show abstract

Section: Drilling Fluid Evaluationmentioning

confidence: 99%

Improve Drilling Performance by Controlling Risk and Reducing Non-Productive Time in a Challenging High-Temperature, High-Pressure Well

Prebensen

Vidvei

Nesheim

et al. 2009

SPE/IADC Drilling Conference and Exhibition

View full text Add to dashboard Cite

show abstract

“…4,5 The barite is ground down to micron size (D50 of 2 micrometer) and coated to prevent particle/particle interactions. The difference in particle size distribution (PSD) between MBS and normal API-ground barite is illustrated in the PSD curves shown in Figure 1.…”

Section: Invert Emulsion Hp/ht Obm With Micronized Barite Slurries (Mbs)mentioning

confidence: 99%

Drilling Fluids in an HP/HT Reservoir: Experiences With Three Different Systems on the Kristin Field Development

Hansen¹,

Breivik²,

Gjonnes³

et al. 2006

Proceedings of SPE Annual Technical Conference and Exhibition

Self Cite

View full text Add to dashboard Cite

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractKristin is a HP/HT field developed on Haltenbanken offshore mid-Norway. The Kristin development consists of 4 templates with a total of 12 subsea wells. The inclination through the reservoir ranges from 28 to 85 degrees. The reservoir at approx. 4600mTVD (15092 ft) has an initial pore pressure corresponding to 1.96sg EMW (16,36 ppg) and a temperature of 172°C (342°F). With a water depth of approx. 360m (1181 ft), a MW of 2.05sg (17,11 ppg) is needed to be able to maintain a riser margin. Three different drilling fluid systems have been used in the reservoir section: 1) Cs/K-COOH clear brine system. 2) Invert emulsion HP/HT OBM. 3) Invert emulsion HP/HT OBM with ultra fine weight particles. Challenges such as ECD management, hole stability, formation damage, weight material sag and operating on subsea HP/HT wells during harsh winter conditions had to be addressed both in the planning and the operational phase. In this paper the background for selection of the drilling fluid is briefly described and especially the rationale behind using three different systems. The paper highlights operational experiences to illustrate how the drilling fluid systems influenced and coped with the challenges of drilling subsea, high angle HP/HT wells. The paper provides a discussion of the pros and cons of the different fluids systems. Finally the paper identifies some of the challenges that lie ahead as the production has started and the reservoir starts to deplete.

show abstract

“…But it needs nonionic dispersant to prevent its agglomeration 4,5 . Treated micronized barite has been reported to reduce risk of barite sag and settlement in low-rheology non-aqueous fluids 6 , and to increase signal strength to MWD tool when using in oil-based drilling fluid 7 . However, its erosive and magnetic effects in a high density WBM haven't been reported.…”

Section: Introductionmentioning

confidence: 99%

Study on Erosive and Magnetic Effects of Weighting Agent in a High Density Water-Based Drilling Fluid

Yan

Wang

et al. 2014

All Days

View full text Add to dashboard Cite

Erosive and abrasive wear effect of water-based drilling fluid (WBM) on down-hole tools may reduce the service life of down-hole tools, and its magnetic contamination on Measurement-While-Drilling (MWD) directional tools may cause azimuth errors and reduce the wellbore trajectory accuracy. The erosive and magnetic effects would be worse when a high density WBM densified with a high content weighting agent was employed. One of the main reasons of the erosive and magnetic effect is related to the weighting agent used. To reduce the erosive effect and magnetic interference of weighting agent, a micronized barite as a new weighting material was prepared in this paper, and then characterized by scanning electron microscope (SEM) and laser particle size analyzer.In our experiments, two conventionally weighting agents, barite and hematite were chosen as the comparing samples. The erosive effects, magnetic contaminate tests, lubricity and rheological properties of high density WBM weighting with micronized barite, barite and hematite were evaluated on erosion instrument, a fluxgate magnetometer, an EP lubricity tester and a rotational viscosimeter, respectively. It was found that the high density WBM weighted with micronized barite showed less erosion, lower magnetic susceptibility, better rheological properties, and smaller lubricating coefficient than that weighted with hematite or barite.Comparing with hematite or barite, the micronized barite could effectively reduce erosive wear on down-hole tools, reduce magnetic contamination on MWD directional tools, and control the rheological property of high density WBM, which would significantly contribute to the service life of down-hole tools, the wellbore position accuracy and the safety of drilling operations.The prepared micronized barite, as a new weighting agent of high density WBM, has a great promise of application in reducing the drag, erosion and magnetic interference along the horizontal section of large extended-reach wells and horizontal wells. It can also be used in high pressure high temperature (HPHT) wells and coiled tubing drilling technology.

show abstract

Development and Field Testing of a Unique High-Temperature/High-Pressure (HTHP) Oil-Based Drilling Fluid With Minimum Rheology and Maximum Sag Stability

Cited by 9 publications

References 0 publications

Improve Drilling Performance by Controlling Risk and Reducing Non-Productive Time in a Challenging High-Temperature, High-Pressure Well

Improve Drilling Performance by Controlling Risk and Reducing Non-Productive Time in a Challenging High-Temperature, High-Pressure Well

Drilling Fluids in an HP/HT Reservoir: Experiences With Three Different Systems on the Kristin Field Development

Study on Erosive and Magnetic Effects of Weighting Agent in a High Density Water-Based Drilling Fluid

Contact Info

Product

Resources

About