This document provides information about cesium formate brine, including its uses, benefits, and the company that produces it. Specifically:
- Cesium formate brine is a high-density, non-toxic brine used for drilling, completing, and suspending deep gas wells. It can have densities up to 143 pcf.
- Using cesium formate brine improves economics by allowing faster drilling and completions while improving well safety. It also maximizes reservoir production and definition.
- Cabot Corporation produces cesium formate brine from pollucite ore in Canada. It has been used in over 250 deep gas wells worldwide since 1999.
Drill and complete wells faster with clear formate brines John Downs
Clear formate brines drill and complete oil wells and gas wells much faster than conventional drilling muds and completion fluids. Formate brines reduce HPHT well drilling and completion times by weeks.
Drill and complete wells faster with clear formate brines John Downs
Clear formate brines drill and complete oil wells and gas wells much faster than conventional drilling muds and completion fluids. Formate brines reduce HPHT well drilling and completion times by weeks.
The slide-pack covers a large variety of artificial lift methods. Explanations are supported by breakdown of pros and cons, calculations and questions. Questions will shed light of roughly how to decide which method(s) to use in a specific case.
Reservoir engineers cannot capture full value from waterflood projects on their own. Cross-functional participation from earth sciences, production, drilling, completions, and facility engineering, and operational groups is required to get full value from waterfloods. Waterflood design and operational case histories of cross-functional collaboration are provided that have improved life cycle costs and increased recovery for onshore and offshore waterfloods. The role that water quality, surveillance, reservoir processing rates, and layered reservoir management has on waterflood oil recovery and life cycle costs will be clarified. Techniques to get better performance out of your waterflood will be shared.
DRILLING FLUIDS FOR THE HPHT ENVIRONMENTMohan Doshi
A BRIEF REVIEW OF THE DRILLING FLUIDS FOR DRILLING HPHT WELLS. HPHT WELLS ARE NOT BUSINESS AS USUAL AND THE SAME APPLIES TO HPHT DRILLING FLUIDS. THE FLUID CHEMISTRY AND THE FLUID COMPOSITION HAVE TO BE TAILORED TO MEET THE RIGORS OF THE HIGH TEMPERATURE ENVIRONMENT
Complete Casing Design with types of casing, casing properties, casing functions, design criteria and properties used for designing and one numerical problem
The slide-pack covers a large variety of artificial lift methods. Explanations are supported by breakdown of pros and cons, calculations and questions. Questions will shed light of roughly how to decide which method(s) to use in a specific case.
Reservoir engineers cannot capture full value from waterflood projects on their own. Cross-functional participation from earth sciences, production, drilling, completions, and facility engineering, and operational groups is required to get full value from waterfloods. Waterflood design and operational case histories of cross-functional collaboration are provided that have improved life cycle costs and increased recovery for onshore and offshore waterfloods. The role that water quality, surveillance, reservoir processing rates, and layered reservoir management has on waterflood oil recovery and life cycle costs will be clarified. Techniques to get better performance out of your waterflood will be shared.
DRILLING FLUIDS FOR THE HPHT ENVIRONMENTMohan Doshi
A BRIEF REVIEW OF THE DRILLING FLUIDS FOR DRILLING HPHT WELLS. HPHT WELLS ARE NOT BUSINESS AS USUAL AND THE SAME APPLIES TO HPHT DRILLING FLUIDS. THE FLUID CHEMISTRY AND THE FLUID COMPOSITION HAVE TO BE TAILORED TO MEET THE RIGORS OF THE HIGH TEMPERATURE ENVIRONMENT
Complete Casing Design with types of casing, casing properties, casing functions, design criteria and properties used for designing and one numerical problem
SPE 145562 - Life Without Barite: Ten Years of Drilling Deep HPHT Gas Wells ...John Downs
The tradition of using barite to increase the weight of drilling fluids dates back to the early-1920’s and, while it has been of great benefit to the oil industry over the past 90 years, it has also caused some chronic and persistent well construction problems along the way. These problems, which are very familiar to drillers, include well control difficulties, stuck pipe incidents and formation damage.
The oil industry has known since the 1970’s that replacing barite with suitable non-damaging solutes in reservoir drill-in fluids is an effective way of reducing formation damage, simplifying operations and eliminating the need for expensive formation damage by-pass operations. The development of brine-based drill-in fluids opened up the opportunity to connect more effectively with hydrocarbon reserves by allowing the construction of long high-angle reservoir sections completed in open hole. Despite the advantages on offer, the industry was unable to exploit this novel technology in deep HPHT gas field developments until the mid- to late-1990’s when drill-in fluids based on potassium and cesium formate brine became available in commercial volumes.
Cesium formate brine was first used as a reservoir drilling fluid in the Huldra gas/condensate field in the North Sea in January 2001, and has now been used to drill a total of 29 deep HPHT gas wells. The information presented and reviewed in this paper confirms that the use of potassium and cesium formates as the sole weighting agents in reservoir drill-in fluids has enabled operators to enjoy the full economic benefits of creating low-skin open-hole completions in deep high-angle HPHT gas wells. The review also concludes that the use of these heavy formate brines as drill-in fluids over the past 10 years has facilitated the safe and efficient development of deep HPHT gas reserves by:
• Virtually eliminating well control and stuck pipe incidents
• Enabling the drilling of long high-angle HPHT wells with narrow drilling windows
• Typically reducing offshore HPHT well completion times by 30 days or more
• Improving the definition and visualization of the reservoirs
• Eliminating the need for clean-ups, stimulation treatments or any other form of post-drilling well intervention to remove formation damage caused by the drilling fluid
This has all been made possible by the operators’ acceptance and adoption of the award-winning Chemical Leasing (ChL) and fluid management programmes that form the basis of their contracts with the sole producer of cesium formate brine. The use of the ChL model has played an important role in reducing the unnecessary consumption of what is a very rare and valuable chemical resource
SPE 165151 - The Long-term Production Performance of Deep HPHT Gas Condensat...John Downs
Formate brines have been in use since 1995 as non-damaging drill-in and completion fluids for deep HPHT gas condensate field developments. The number of HPHT fields developed using formate brines now totals more than 40, and includes some of the deepest, hottest and highly-pressured reservoirs in the North Sea. The well completions have been both open-hole and cased-hole.
An expectation from using formate brines as reservoir drill-in and completion fluids is that they will cause minimal damage to the reservoir and help wells to deliver their full productive potential over the life-time of the field. The validity of this expectation has been tested by examining the long-term hydrocarbon production profiles of eight HPHT gas condensate fields in the North Sea where only formate brines have been used as the well completion fluids. In five of these fields the wells were drilled with oil-based muds and completed by perforating in cased hole with high-density formate brines. In another two of the fields the wells were drilled with formate brines and completed with screens entirely in open hole using the same brines. The last of the eight fields was drilled with formate brine and the wells were then completed with same fluid in either open hole or cased hole.
The results of the production analysis provide a unique insight into the impact of a single type of specialist drill-in and completion fluid on the rate of recovery of hydrocarbon reserves from deeply-buried reservoirs in the North Sea
SPE 165151 The Long-Term Production Performance of Deep HPHT Gas Condensate ...jdowns
Maps and analyses the long-term production of eight HPHT gas and condensate fields in which formate brines were the last well construction fluids to contact the producing reservoirs
A review of the use of potassium formate brine weighted with Micromax as a high-density well drilling and completion fluid for HPHT wells. Advantages include improved production and improved well logging.
Innovative engineering design in circulating fluid bed technologyIgor Sidorenko
Sneyd, S., Sidorenko, I., Orth, A., & Laumann, M.-D. (2007) Innovative engineering design in circulating fluid bed technology. Paper presented at CHEMECA conference, Melbourne.
Breaking Paradigms in old Fields. Finding “the reservoir key” for Mature Fiel...Juan Diego Suarez Fromm
Two field examples will be presented, where after 50 years of development; fresh oil and gas were produced by changing some reservoir paradigms.
Upsides could be overlooked due to paradigms on field development. The successful one in terms of reserves and cost effective capital expenditure could be visualized as “finding the key for the field”. But as development takes place over many years (decades), the “key” should be a dynamic concept over time, correlated with technology availability, enabling us a better understanding of petroleum resources size, quality and distribution.
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Scanned copies of the original 35 mm slides used in the presentation of SPE paper 24973 by John Downs of Shell at the European Petroleum Conference held in Cannes, France, 16-18 November 1992
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Day 6 of an 8-day walk through Devon. An 8-mile walk from Morchard Bishop to Five Crosses on a route that could be used by Lands End to John O'Groats long distance walkers passing through the county
A Walk through Devon - Day 5 - Bondleigh Bridge to Morchard Bishop John Downs
Day 5 of an 8-day walk through Devon. An 8-mile walk from Bondleigh Bridge to Morchard Bishop on a route that could be used by Lands End to John O'Groats long distance walkers passing through the county
A Walk through Devon - Day 4 - Stockley Hamlet (Okehampton) to Bondleigh BridgeJohn Downs
Day 4 of an 8-day walk through Devon. An 8-mile walk from Stockley Hamlet to Bondleigh Bridge on a route that could be used by Lands End to John O'Groats long distance walkers passing through the county
Day 2 of a walk through Devon - From Lewdown to Bridestowe. The entire set of " A Walk through ..." walks currently covering the south-west of England from Lands End up into the Cotswolds could be used as a route guide by Lands End-John O'Groats (LEJOG) walkers
Day 1 of a walk through Devon - From Launceston on the Cornwall /Devon border to Lewdown in Devon. The entire set of " A Walk through ..." walks currently covering the south-west of England from Lands End up into the Cotswolds could be used as a guide by Lands End-John O'Groats (LEJOG) walkers
A Ramble through Cornwall - Day 8 - Bodmin to St Neot John Downs
A short (7 mile) walk from the outskirts of Bodmin east to St Neot, skirting the southern border of Bodmin Moor. Mostly walking in fog on this particular day
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Presented by Vladimir Iglovikov:
- https://www.linkedin.com/in/iglovikov/
- https://x.com/viglovikov
- https://www.instagram.com/ternaus/
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This case study covers various aspects, including:
People: The contributors and community that have supported Albumentations.
Metrics: The success indicators such as downloads, daily active users, GitHub stars, and financial contributions.
Challenges: The hurdles in monetizing open-source projects and measuring user engagement.
Development Practices: Best practices for creating, maintaining, and scaling open-source libraries, including code hygiene, CI/CD, and fast iteration.
Community Building: Strategies for making adoption easy, iterating quickly, and fostering a vibrant, engaged community.
Marketing: Both online and offline marketing tactics, focusing on real, impactful interactions and collaborations.
Mental Health: Maintaining balance and not feeling pressured by user demands.
Key insights include the importance of automation, making the adoption process seamless, and leveraging offline interactions for marketing. The presentation also emphasizes the need for continuous small improvements and building a friendly, inclusive community that contributes to the project's growth.
Vladimir Iglovikov brings his extensive experience as a Kaggle Grandmaster, ex-Staff ML Engineer at Lyft, sharing valuable lessons and practical advice for anyone looking to enhance the adoption of their open-source projects.
Explore more about Albumentations and join the community at:
GitHub: https://github.com/albumentations-team/albumentations
Website: https://albumentations.ai/
LinkedIn: https://www.linkedin.com/company/100504475
Twitter: https://x.com/albumentations
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UiPath integration with generative AI
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In this work, we equipped AFL, a popular fuzzer, with DIAR and examined two critical Linux libraries -- Libxml's xmllint, a tool for parsing xml documents, and Binutil's readelf, an essential debugging and security analysis command-line tool used to display detailed information about ELF (Executable and Linkable Format). Our preliminary results show that AFL+DIAR does not only discover new paths more quickly but also achieves higher coverage overall. This work thus showcases how starting with lean and optimized seeds can lead to faster, more comprehensive fuzzing campaigns -- and DIAR helps you find such seeds.
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4. Formate brine applications
Low-solids fluids for deep gas well constructions
• Reservoir drilling
• Completions
• Workovers
• Packer and long-term well suspensions
A mature field proven technology used in deep gas fields since
1995
5. Deep and/or HPHT gas fields developed using
formate brines, 1995-2009
Published information on 35 fields
Some deep and/or HPHT gas fields developed using formate brines
Country Fields Reservoir Description
Matrix
type
Depth, TVD
(metres)
Permeability
(mD)
Temperature
(oC)
Germany Walsrode,Sohlingen
Voelkersen,Idsingen
Sandstone 4,450-6,500 0.1-150 150-165
Hungary Mako Sandstone 5,692 - 235
Kazakhstan Kashagan Carbonate 4,595-5,088 - 100
Norway Huldra ,Njord
Kristin,Kvitebjoern
Tune, Valemon
Victoria
Sandstone 4,090-7,380 50-1,000 121-200
Pakistan Miano, Sawan Sandstone 3,400 10-5,000 175
Saudi Arabia Andar,Shedgum
Uthmaniyah
Hawiyah,Haradh
Tinat, Midrikah
Sandstone
and
carbonate
3,963-4,572 0.1-40 132-154
UK Braemar,Devenick
Dunbar,Elgin
Franklin,Glenelg
Judy, Jura, Kessog
Rhum, Shearwater
West Franklin
Sandstone 4,500-7,353 0.01-1,000 123-207
USA High Island Sandstone 4,833 - 177
6. Why oil companies like formate brines
They improve the profitability of HPHT gas field
developments
• Drill and complete faster and easier
• Improve well safety and reduce risk
• Maximise well performance
• Reduce the need for future well interventions
All simply from using a low-solids non-corrosive fluid
7. Low-solids fluids cut the costs of deep gas well
constructions by speeding up drilling operations
Cesium formate brine increases ROP by >100% in deep hard
rock drilling
Data from DOE Deep Trek project , see SPE 112731
Effect of Mud on Rate of Penetration
Carthage Marble with 7 Blade PDC Bit
0
10
20
30
40
50
0 5,000 10,000 15,000 20,000 25,000 30,000
Weight on Bit (lbf)
RateofPenetration(ft/hr)
Water
16ppg OBM
16ppg CsFm
16ppg OBM + Mn
8. Cesium formate brine
• Cesium formate dissolved in water
• Density up to 19.2 ppg/143 pcf
• Non-toxic
• Safe to handle, pH 9-10
• Little or no risk to the environment
• Non-corrosive
• Minimizes formation damage
Cesium formate
2.3 s.g.
9. • Cabot founded in 1882
• Headquarters in Boston, USA
• Operates 39 plants in 20 countries
• Approximately 4,200 employees
• 2008 sales of $ 3.2 billion
Cesium formate brine manufactured by a
division of Cabot Corporation
11. Cabot produces cesium formate brine at
Lake Bernic in Canada from pollucite ore
Pollucite ore
Cs0.7Na0.2Rb0.04Al0.9Si2.1O6·(H20)
• Mined at Bernic Lake, Manitoba
• Processed on site to Cs formate brine
• Cs formate brine production 700 bbl/month
• Brine stocks > 30,000 bbl
12. Cesium formate brines used in 253 deep HPHT
gas wells since 1999
Drilling, completion, workover and suspension fluids
• At densities up to SG 2.25 (18.7 ppg or 140.2 pcf)
• At BHST up to 235oC (450oF)
• For periods of up 2 years dowhole (well suspensions)
• In sandstone and carbonate reservoirs, 0.01 mD up to 4 Darcy
• Wide variety of completions – barefoot open hole, cased and
perforated, with sand screens and gravel packs
13. Cesium formate applications
253 jobs in 34 deep HPHT gas fields (see website for list)
• Drill-in - 35
• Completions - 130
- as a brine and in LSOBM formulations (98 pcf)
- outstanding as HPHT perforating kill pill (Visund, Braemar, Judy, Rhum)
• Workovers and miscellaneous – 88
Includes diverse uses:
- Long-term well suspension
- Well testing
- Stuck-pipe release pill (OBM drilling)
- Melting hydrate plugs
14. Cesium formate brine was first used in the world’s
largest HPHT gas field development – Elgin/Franklin
Also the deepest HPHT gas field in North Sea
B
Cesium formate brine used by TOTAL in
34 well construction operations in 8
deep gas fields in period 1999-2010
15. Use of cesium formate by TOTAL in the
Elgin/Franklin field November 1999 - present
18.2 ppg/136 pcf completion fluid in 8 wells
• UK North Sea
• World’s largest HPHT field
• Gas condensate reservoir
• 16,000 psi @ 20,000ft
• BHST 400oF
• 140,000 bbl/day of condensate
• 13 million m3 gas /day
• Brine left in wells for up to 24 months (well suspension)
16. Cost of renting 136 pcf Cs formate brine in
Elgin workovers
Elgin well
Total brine costs*
($, ’000)
G3 913
G4 830
G5 602
G6 879
G7 807
* Includes all brine rental, losses and reconditioning charges
17. Huldra field, HP/HT gas condensate
-BHST: 297oF
-TVD : 3,900 metres/12,795 ft
- Fluid density: 15.75 ppg/118 pcf
- 6 wells – 600 ft reservoir sections 5-7/8” at 45-55o
- 1–2,000 mD sandstone
-Open hole, wire wrapped screens
Justification for using formate
- Improve well control !
- Lower ECD
- Run completion in same fluid
- Low risk of screen plugging
- Shale stabilisation
- Lubricating
- Safe for crews
- Environmentally benign
2001 - Cesium formate brine first used by Statoil to drill
and complete 6 deep HPHT gas wells, offshore Norway
Operator had experienced kicks when using barite-weighted fluids
18. Economic benefits from the use of cesium formate
brine in deep gas field developments
“ a remarkable record of zero well control incidents in all 15
HPHT drilling operations and 20 HPHT completion operations”
Speed and safety
Better/safer drilling environment saves rig-time costs
- Stable hole: see LWD vs. WL calipers in shale
- Elimination of well control and stuck pipe incidents
- Good hydraulics, low ECD
- Good ROP in hard abrasive rocks
19. Economic benefits from use of cesium formate brine in
deep gas field developments
Speed and simplicity
Allowing faster and easier movements of tubulars and fluids
- Pipe and casing running speeds are faster
- Mud conditioning and flow-check times shorter
- Displacements simplified, and sometimes eliminated
(i.e. formate drilling fluid = formate completion fluid)
Quote by operator : “ Improved well economics by increasing trip speed”
20. Economic benefits from use of cesium formate brine in
deep gas field developments
Speed and simplicity. Getting it right first time
Faster completions
- Drill-in and completing with cesium
formate allows open hole completion
with screens
- Clean well bores mean no tool/seal
failures or blocked screens
- Completion time 50% lower than wells
drilled with OBM
Quote by operator : “ fastest HPHT completion operation ever performed in North Sea (12.7 days)”
21. Maximises well production - providing efficient delivery
of gas reserves (revenues)
Tune and Huldra fields – drilled and completed with formate brines
90% recovery of gas reserves (16-18 billion m3) produced in 7 to 8 years
0
10
20
30
40
50
60
70
80
90
100
0 5 10 15
RecoveryofGasReserves(%)
Time since start-up (years)
Huldra
Tune
Source : Norwegian Petroleum Directorate- Fact Pages - November 2009
22. Maximises well production - providing efficient delivery
of condensate reserves (revenues)
Tune and Huldra fields – drilled and completed with formate brines
90% recovery of condensate reserves (3-5 million m3) produced in 4 to 6 years
Source : Norwegian Petroleum Directorate- Fact Pages - November 2009
0
20
40
60
80
100
120
0 5 10
RecoveryofCondensateReserves
(%)
Time since start-up (years)
Huldra
Tune
23. Economic benefits from the use of cesium formate
brine in deep gas field developments
“Using photoelectric factor and bulk density data, combined with resistivity measurements from both
the LWD drill pass and the ream pass, produces a very reliable and consistent net reservoir
definition.”
Good reservoir definition in cesium formate brine
24. Economic benefits from the use of cesium formate
brine in deep gas field developments
“Applying a conductive drilling fluid in all production wells drilled in a field also provides the possibility of running
high quality resistivity image logs (FMI). Extensive use of such logs provides the geo-modelers with detailed
information regarding structural dip, depositional environment, sedimentary features, facies, and geological
correlations.”
Good reservoir definition in cesium formate brine
25. Why oil companies like cesium formate brine
Cesium formate brine improves the profitability of HPHT
gas field developments
• Drill and complete faster and easier
• Improve well safety and reduce risk
• Maximise well performance
• Reduce the need for future well interventions
• Precise definition of reservoir and fractures
26. Key information about cesium formate brine in
one slide ......
• High-density clear brine – 98 to 143 pcf
• Advanced drilling,completion and workover fluid for
deep gas wells – available though all mud companies
• Improves economics of deep gas field developments
- Faster, simpler and safer well constructions
- Accelerated production of recoverable reserves
- Enhanced reservoir definition and imaging
27. BRINEWISE
A Tool for Pricing the Full Operational Costs,
Waste and HSE Risk of Completion Fluids
Formate presentation to LUKSAR – December 2009
28. BrineWise calculates the full cost of owning and using
high-density completion fluids
Prices the full operational costs, waste costs and the cost of “incidents”
29. How BrineWise compares the true cost of
completion fluid options
Cost of using fluid
(waste, time,
handover to
production etc.)
Fluid costs
(price per bbl)
+ =
Operational
Costs related
to fluid choice
Operational
Costs
+
HSE related
costs
=
Overall
fluid related
cost for well
HSE costs
Consent &
Transport +
Cost of HSE risk
(scenario based)
=
HSE related
costs related
to fluid
choice
Cost of using fluid
(waste, time,
handover to
production etc.)
Fluid costs
(price per bbl)
+ =
Operational
Costs related
to fluid choice
Cost of using fluid
(waste, time,
handover to
production etc.)
Fluid costs
(price per bbl)
+ =
Operational
Costs related
to fluid choice
Operational
Costs
+
HSE related
costs
=
Overall
fluid related
cost for well
HSE costs
Consent &
Transport +
Cost of HSE risk
(scenario based)
=
HSE related
costs related
to fluid
choice
HSE costs
Consent &
Transport +
Cost of HSE risk
(scenario based)
=
HSE related
costs related
to fluid
choice
30. COMPARATIVE
NORMAL
OPERATIONAL
COSTS COST OF HSE
RELATED RISK
COMPARATIVE
AVERAGE COST
PER WELL (taking
into account the
HSE risk)
COSTS AT RISK
FOR THE
ALTERNATIVES
COMPARATIVE
FLUID COSTS
31. BrineWise calculates four cost scenarios
0
1 000 000
2 000 000
3 000 000
4 000 000
5 000 000
6 000 000
Fluid costs only Normal operation
costs
Costs of an
incident w ith
small to average
consequences
Costs of an
incident w ith
larger than
average
consequences
US$
Cesium Formate Zinc Bromide
32. BrineWise – Key management benefits
BrineWise allows systematic cost comparison of the
consequences of using particular completion fluids
• Systematic fluid evaluation and costing incorporating :
- Fluid cost
- Operational costs
- HSE costs
- Incident-related costs
• Shows costs for all operational departments - including cost
consequences for production
Best overall value (lowest cost) fluid option is clearly identified