Presentation on theme: "Under-balanced well bore cleanout and production evaluation technology."— Presentation transcript:
Under-balanced well bore cleanout and production evaluation technology.
Presentation Overview Why This Technology is Required How It Works Applications Benefits Case Histories & Successes
Under-pressured reservoirs Horizontal and extended reach well designs Velocities in liners allow for solids settling Hz section is not 100% utilized Liquid loading of shallow to medium depth well bores Cleanout damage is becoming more of a problem each and every day Why is This Technology Required
Why This Technology is Required Alternative processes such as fluid circulation, swabbing, gas cleanouts and bailing or pump to surface technology have limitations and can no longer be generally applied. –Adds pressure to formation (over-balanced) –Does not work in Hz –Costly to deploy –Slow process --- › expensive
How it Works This systems utilizes two unique technologies to revolutionize the well bore cleanout operations. Our JetPak™ system utilizes FlatPak™ coiled tubing technology as well as specifically engineered jet pump to remove solids and liquids from well bores. The primary function of this technology is to create a low pressure environment in the well bore to pump the fluid and/or solids to surface.
Applications Class I and II vertical, deviated, slant or horizontal well bore cleanouts Produced or frac sand cleanouts Acid frac/stimulation cleanup Drilling fluid recovery Production testing/evaluation
Conventional Cleanout Event Conventional Cleanout Event Typical Well Response From Conventional CT Cleanout: Text Book “Cleanout Damage” Conventional Cleanout Damage
Benefits Production Testing - This is an excellent system to evaluate wells that are sub-pressured in nature and do not flow. The subject well may be a candidate for Artificial Lift or an abandonment candidate. None the less, the JetPak™ will remove the fluid so accurate well data can be collected.
Vertical heavy oil (10 API) well production test BH recorder data Well is pumped off, pressure changes are from moving the FlatPak and BH pump
BHA Pressure & Temperature Job Data: Tool at Wellhead: 135 kPa / 20 psi Run To TD 1,000 kPa / 145 psi Gas Column while RIH: 165 kPa / 24 psi Tool at Wellhead: 160 kPa / 23 psi Pull Out of Hole On Bottom Run In Hole
Pull Out of Hole On Bottom Run In Hole 0.7 m3 in ½ Hour ∆P : 13 kPa (2 psi) BHA Pressure & Temperature Job Data:
JetPak versus JetVak? JetPak system alternates between Jetting and vakking (shiftable while down hole) JetVak system facilitates simultaneous jetting and vakking operations, a “clean as you go approach. The FlatPak coiled tubing string is bonded and contains dual 1¼” or1½” carbon steel coils. The length of the string ranges from 900 to 3100 meters, and is deployed by Technicoil’s rig 2006 based out of Red Deer, supported by Quantum. Areas of Application Lower Amaranth SW Manitoba Viking Manville and Colorado group CHOPS Vertical & Hz Lloyd. Slave Lk. And Wabasca Shaunovan, Bakken and Cardium Banff Dina Quantum JetVak video final.wmv
Case Histories & Successes Husky CHOPS Hz under pressure well cleanout with JetPak 0.8m3 sand Up to 30% sand - avg. 6% through job 3.5m3 of fluid 740TVD 1550MD 114mm guide string in 137mm liner This well was 1yr old and did not produce, unknown problem. The well is now producing at 10m3/day yielding Husky a daily cash flow of over $3000.00
PennWest Denzil Hz CO, BH rec data 3.2m3 of 2350kg/m3 of fine sand 21% of liner volume. BHP increases as we move into slotted liner
Shell Canada CSS perf. Liner CO, BH rec data Solids bridges indicated on either side of Low pressure zone. Mid point of lateral
CHOPS polymer flood CO We call this guy Bituman
Case Histories & Successes Husky Hz Viking under-pressure well cleanout with JetVak 1.1m3 sand Up to 45% sand - avg. 2-3% through job 685TVD, 2216m TD 114 mm guide string ran to 1 jt. Above 114mm multi-frac liner Pump TD @2008M -6000daN At mid point of the Hz section, many bridges were encountered. Frac gel, sand, oil with gas was evident in the returns. High oil cuts were observed while POOH on this well.
E&P Company Husky EnergyDateSept. 03, 2010 Well Location surface CT companyTechnicoil Well Location Bottom Hole name of individual filling out report Pressure Truck press. 18.6Mpa Steve Winkler Pressure Truck fluid rate 88lpm open frac port RIH #1 corrected or uncorrected timedepthSand%Oil %Water %tank level comments or notes 88402080 minimal gas 9820 2% frac jell 11250.5396.5 wax in returns 12000892 foamy with gas 12600.251089.25 big gas kick in returns 10:3313150.52574.516 10:4513551.51088.5 small amounts of gas 10:50 22078 10:5414003207732 88lpm returns 11:2014460.22079.8 quite gassy returns 11:4015040.753 62 gas rate dropping 86lpm returns 12:0715351396 2% frac jelloil is jelling when sun in the centrifuge 12:5015615194 "sand bridge 12:55158415184 1% frac jellsand bridge 1:1215901099 1% frac jell 1:15159518081 1% frac Jell 1:3016171098 1% frac Jell 1:55165511089 1% frac Jellsand bridge 2:2517081990 sand bridgeincrease in gas in returns gren frac fluid 2:501702451045 2:55 301060 3:0016921.5098.5 trace of frac jell 3:15171621880 sand bridge 3:381713102070 trace of frac jell 3:4817562.51285.5 from bridge at 1706 4:3018502.51285.5 4:50 0.5099.5 clear returns in cellar 5:3017000.51881.5 POOH 6:0512800.252079.75 POOH 6:3010050.51881.5 POOH 7:450 on surface blow coil dry rig out
Husky Lloydminster 4.5m3 sand Up to 35% sand - avg. 7-8% through job 660TVD, 1785m TD 114 mm guide string ran 1jt into 139mm liner Pump TD @1530M -6000daN. 10 year old well with production issues 635 TVD 1635 TD 114mm guide string landed into 139mm liner 600 meters of drilling fluid encountered Well is on prod. with 40% increase in volume
With high viscosity oils we are mixing a water based polymer called JetFlux into our power fluid. The high pressure jets blast the heavy oil, the result is a uniform non-viscous water like return fluid. The chemical has a sand suspension component to it add a safety margin into the operation. The mixing rate is 75 l/m3 of water. CHOPS
Alberta Research Counsel study on “tight Oil” Moving Solids? Rule of thumb: Vertical well: 1 ft/s Hz well: 3 ft/s Durand Equation (with Wasp correction for particle size)
Alberta Research Counsel study on “tight Oil” Moving Solids?
Questions Surrounding Horizontal Well designs How long should the lateral section be in a given formation? Is drainage making it to the toe of the lateral? Stimulation type, Ball frac vs. mono bore and liner diameter choice Optimize fracture size and type What is the PBHP and inflow characteristics at specific intervals or stages? How does this correlate with frac type / volume and stip log. Fluid and solids viscosity and velocity in the lateral Drainage Area
Conclusions In the mid 1990s, the SPE did a world wide study on the production from Hz wells of all types. They found that, on average, 30% of the lateral sections did not produce. Our findings reaffirms the out come of this study. During our tests the majority of the Hz wells we have entered have offered the best production from the mid point to the toe of the lateral section. Alternately the liner has proof of non production since new, drilling fluid, drilling enzymes or the liner entirely full of sand. We are running BH recorders on each and every cleanout. This is another diagnosis tool we can use to identify issues or potential upside. To make a horizontal well economically successful, it has to yield at minimum 4 times what an offset vertical produces. Thus, we are still in our infancy when it comes to completion and production of Hz wells. This information may help E&P companies design wells that will optimize recovery of the given formation. Geology- Longer may not always be better.
Hz well information? How do we gather it? High water cut gas inflow High oil cut $$
Commonly Asked Questions 400+ successful operations with, no safety incidents or stuck pipe or plugged coil. Velocity on the return conduit of the FlatPak is 2m/sec. well above hz sand settling velocity. Maximum amount of sand out of one well, 8.0m3 or 20,000 Kilograms Minimum tubing size the system can run through is 114mm Velocity string not required Clients, Husky, Shell, Devon, Statoil, Cenovus, Nexen, PennWest, Paramount, ARC Res., Provident, CNRL, Westfire, Harvest, Enerplus, Progress Energy, Fairborne, Anderson, Suncor/Petro-Canada, Baytex Energy, Pengrowth, LonePine Res.
Thank you for your time. I invite any questions. Have a great day! Presented by: Steven Winkler Adding Value through Technology