Design, Qualification, QAQC and Operational Performance of Completion Fluid, Reservoir Drill-in Fluid and Breaker - Tamar, Offshore Israel

Healy, John; Sanford, J.; Hopper, Tim; Dufrene, Kerby; Fink, Josh; Balderrama, Christian; Steve, Vickers; Mackenzie, Grant

doi:10.2118/173060-ms

SPE/IADC Drilling Conference and Exhibition 2015

DOI: 10.2118/173060-ms

|View full text |Cite

Design, Qualification, QAQC and Operational Performance of Completion Fluid, Reservoir Drill-in Fluid and Breaker - Tamar, Offshore Israel

John Healy¹,

J. Sanford

Tim Hopper

et al.

Abstract: A case history from Offshore Israel is presented that describes the successful delivery of five (5) ultra-high rate gas wells (ϩ250 MMscf/D) completed in a significant (10 TCF) gas field with 7 in. production tubing and an Open-Hole Gravel Pack (OHGP). Maximizing gas off-take rates from a gas reservoir with high flow capacity (kh) requires large internal diameter (ID) tubing coupled with efficient sand face completions. When sand control is required, the OHGP offers the most efficient as well as the most relia… Show more

Help me understand this report

Search citation statements

Order By: Relevance

Paper Sections

Select...

Citation Types

Supporting

Mentioning

Contrasting

Year Published

2016

2023

Publication Types

Select...

Other5

Relationship

Self Cite0

Independent5

Authors

Journals

Cited by 5 publications

References 24 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

Would You Like Good Lab Results or a Productive Well? Getting Wellbore Cleanup Testing Right!

Fischer¹,

Vining²,

Constien³

2016

SPE International Conference and Exhibition on Formation Damage Control

View full text Add to dashboard Cite

Soft sand wells are typically more expensive completions due to the need for sand control. The sheer cost of the wells makes the completions more high risk and increases the need for laboratory testing to validate the screen or gravel pack sizing as well as drill-in fluid selection and filtercake cleanup. Laboratory simulations of actual wellbore conditions to determine the effectiveness of wellbore cleanup treatments is quite complex. When the formation is unconsolidated and requires sand control such as screen only or gravel pack, the complexity increases further. Typical core flood equipment does not adequately confine the formation material to allow drilling and cleanup fluids to be circulated at representative shear rates and pressures over the formation face. The paper summarizes over 15 years of work to develop procedures for dynamic drill-in fluid flow testing in a screen-only or gravel pack scenario. The suite of tests has been successfully used for multiple operators in order to determine the effects of drill-in fluids with unconsolidated and consolidated formation as well as to optimize clean-up treatment and gravel pack performance. This results in selection of least damaging drill-in fluids and better filtercake removal. Dynamic flow cells have been designed to enable laboratory testing to be performed under matching wellbore conditions. This dynamic flow test method is unique because it has true slot flow that enables the filtercake to be deposited on the face of an unconsolidated formation pack. The well conditions are received from the client and the shear rate at the formation face is calculated and matched in the laboratory. Another unique aspect of the design is the ability to form the drill-in fluid filtercake on multiple test cells simultaneously. Once the drill-in fluid filtercake is established, it is equally important to be able to simulate filtercake clean up treatments under laboratory conditions. The test method allows for multiple flushes across the filtercake to simulate the entire clean-up system. The flushes may include solids-free mud, push pill, clean oil or brine, and a reactive clean-up treatment, depending upon the drill-in fluid being tested. Multiple cleanup treatments can be applied to the filtercake, again matching the shear rate and temperature as indicated by the client well conditions. When a gravel pack is present, the cell design allows the gravel pack to be placed after the filtercake is built on the formation sand. Then, the clean-up treatment is circulated to the back side of the screen. The test method also allows for extended treatment soak times, up to 10 days.

show abstract

Would You Like Good Lab Results or a Productive Well? Getting Wellbore Cleanup Testing Right!

Fischer¹,

Vining²,

Constien³

2016

SPE International Conference and Exhibition on Formation Damage Control

View full text Add to dashboard Cite

show abstract

The Real World isn't Perfect: An Investigation into Wellbore Clean-Up with Non-Uniform Filtercake Exposure

Fischer¹

2018

SPE International Conference and Exhibition on Formation Damage Control

View full text Add to dashboard Cite

Soft sand wells are typically more expensive completions due to the need for sand control. The cost of the wells makes the completions more high-risk and increases the need for laboratory testing to validate the screen or gravel pack sizing as well as drill-in fluid selection and filtercake cleanup. Dynamic drill-in fluid clean-up testing provides a state of the art methodology for determining the least damaging drill-in fluid and / or the most effective clean-up treatment for the filtercake. However, the test method to date, referenced in SPE 112497 and SPE 179024 has used a 100% uniform clean-up treatment approach. This approach has assumed that all of the clean-up treatment uniformly contacts and treats the filtercake. In the actual well, it is unlikely that 100% uniform clean-up exists. It is possible in the wellbore to encounter selective clean-up treatment leakoff due to permeability differences or variable filtercake thickness. This paper investigates the results when a less uniform clean-up environment is encountered. The dynamic drill-in fluid testing utilizes designed-for-purpose slot flow cells which allow soft sand formations to be confined and tested while still exposing the face of the formation directly to the drill-in fluid or clean-up treatment during the test. The well conditions are received from the client and the shear rate at the formation face is calculated and matched in the laboratory. The test simulates wellbore conditions as closely as possible including annular shear rate during filtercake deposition, overbalance pressure, temperature and multiple clean-up flushes. In this study, the amount of filtercake clean-up treatment fluid loss was modified to simulate multiple effective clean-up scenarios. Additionally, testing was completed on aloxite discs in a standard HPHT fluid loss cell in order to provide a comparison between the dynamic and static tests. The dynamic fluid loss testing has been designed to match treatment volumes and conditions in the actual wellbore as closely as possible. The assumption that 100% uniform application of the clean-up treatment contacting the filtercake has always been the basis for the testing. However, changing the previous assumptions to allow for non-uniform application of the clean-up treatment during the testing provides another opportunity to challenge our perceptions and simulate the actual well more completely. The modification of the standard test procedure to allow the simulation of non-uniform clean-up of the filtercake in the wellbore adds further to our understanding of the actual wellbore clean-up. The relationship of the results between the static and dynamic fluid loss provides an opportunity for pre-screening work to be conducted and related to the final results achieved in the dynamic fluid loss test.

show abstract

Optimizing the Deepwater Completion Process: Case History of the Tamar 8 Completion Design, Execution and Initial Performance - Offshore Israel

Healy

Waggoner

Magin

et al. 2018

IADC/SPE Drilling Conference and Exhibition

View full text Add to dashboard Cite

A case history from Offshore Israel is presented that describes the successful delivery of one (1) ultra-high rate gas well (+250 MMscf/D) completed in a significant (11.5 TCF) gas field with 7 in. production tubing and an Open Hole Gravel Pack (OHGP). The well described, Tamar 8, was completed approximately 4 years after the start of initial production from the Tamar development. Several operational innovations and process improvements were implemented that resulted in a significant reduction in rig time. A novel multi-purpose integrated tool string design enabled the sequential drilling of the pilot hole, underreaming of the reservoir section, several fluid displacements and casing cleaning in a single trip. The completions were installed with minimal operational issues (completion Non-Productive Time, NPT = 2.6%). Production commenced in April 2017. The initial completion productivity of this new well exceeded the five wells completed in 2012. Peak production rate to date is 281 MMscf/D.

show abstract

scite is a Brooklyn-based organization that helps researchers better discover and understand research articles through Smart Citations–citations that display the context of the citation and describe whether the article provides supporting or contrasting evidence. scite is used by students and researchers from around the world and is funded in part by the National Science Foundation and the National Institute on Drug Abuse of the National Institutes of Health.

Contact Info

customersupport@researchsolutions.com

10624 S. Eastern Ave., Ste. A-614

Henderson, NV 89052, USA

This site is protected by reCAPTCHA and the Google Privacy Policy and Terms of Service apply.

Blog Terms and Conditions API Terms Privacy Policy Contact Cookie Preferences Do Not Sell or Share My Personal Information

Made with 💙 for researchers

Part of the Research Solutions Family.

Design, Qualification, QAQC and Operational Performance of Completion Fluid, Reservoir Drill-in Fluid and Breaker - Tamar, Offshore Israel

Cited by 5 publications

References 24 publications

Would You Like Good Lab Results or a Productive Well? Getting Wellbore Cleanup Testing Right!

Would You Like Good Lab Results or a Productive Well? Getting Wellbore Cleanup Testing Right!

The Real World isn't Perfect: An Investigation into Wellbore Clean-Up with Non-Uniform Filtercake Exposure

Optimizing the Deepwater Completion Process: Case History of the Tamar 8 Completion Design, Execution and Initial Performance - Offshore Israel

Contact Info

Product

Resources

About