Upload
others
View
4
Download
0
Embed Size (px)
Citation preview
Productivity Improvement Case Studies Session V:
Extended Lateral Solutions for an Extremely Difficult
Well Trajectory2019-NAPS-5.2AUTHORS: Larry Albert, Jason Booher and Anthony Wilson, Allied-Horizontal Wireline Services; Fraser Hamilton and Jason Hradecky, Impact Selector International; Dustin Dunning and Vadim Protasov, WireCo WorldGroup
DALLAS - FORT WORTH. AUGUST 5-6, 2019.
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Zones Above Reservoir Target Cause Drilling Problems
• An E&P operator planned a horizontal well in an area where zones above target cause drilling problems when trying to build angle and land lateral
• Offset Wells proved difficult; therefore, new drilling plan was devised
• New plan required drilling through target reservoir
• After reaching base at 14,000 ft., drill up at maximum of 114⁰ until reentry of target reservoir
• Maximum Dogleg Severity (DLS) 24.6o/100 ft.
• Due to faulting in area and required well direction, target reservoir was dipping up at ~10⁰ laterally toward horizontal drilling target
• The well had to be drilled at ~100⁰ deviation to 21,100 ft.
The Problem – Extremely Difficult Well Trajectory
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
The Problem – Extremely Difficult Well Trajectory
Well Plan
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
• High frictions on the wireline due to well trajectory
• Wireline tools would slide down inclined casing during and after operations
• If tool position not maintained, wireline could be entangled and result in stuck tool
• If overrun occurred next to perforating guns when detonated, wireline could be severed
Challenges for Wireline Plug & Perforating
Normal wireline plug and perforating completion operations could prove extremely difficult
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Alternatives if Wireline P&P Cannot be Executed Could Be Expensive (estimated $millions)
• Abandon acreage
• Continue drilling attempts building angle above target
• Reposition surface location and drill down dip
• Reduce angle and shorten lateral in target
• Coiled tubing conveyed plug and perforating completion
Alternatives Expensive
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Extended Lateral Technology
• Jacketed wireline
• Addressable separation tool
• Downhole tension tool
• Advanced risk deployment modeling
Meeting the Challenges
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Challenge: Increased Friction with Standard Wireline
• Guns and plug assemblies are gravity deployed, pumped down and pulled out of hole
• Friction created by steel armor increases with changes in hole direction/deviation
• Wirelines have defined breaking strength and a maximum safe pull of 50% of breaking strength
• Wireline friction, plus vertical weight causes high surface tension
• Severe doglegs and long laterals can cause surface tensions to exceed safe working limits
• High potential for drum crush on long laterals when tools are pumped down at low surface tension and pulled out at much higher tension
Inner Conductor
Insulation
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
When POOH Tools Can Overrun Wireline
• Tools slide down inclined casing
• Wireline can be perforated and severed
• Assembly potentially stuck in borehole
• Complex fishing operation may result
Challenge: Wireline Overrun
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Meeting the Challenge – Jacketed Wireline
• Specially formulated polymer jacket
• Eliminates grease injection
• Reduces Friction, lowers surface tension & allows higher tension to cable head
• Prevents drum crush
• Fully torque balanced
• Higher safety margins & faster running speeds
• Eliminates difference between fixed and free ends breaking strength
• Eliminates bird-caging, high stands, broken armors and crossed armors
• Stiffness helps eliminate wireline overrun
Jacketed Wireline
Insulation
Inner Conductor
PolymerJacket
Steel Armors
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Modeled Jacketed vs. Standard Wireline
• Modeled surface tension • Standard: 3,000 lbs• Jacketed: 2,250 lbs.
(-25%)
Comparing Friction of Jacketed vs. Standard Wireline
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Challenge – How to Release Wireline if Stuck in Well
Cable Head Weak-Point
• A method to separate the wireline from the tools is required
• If wireline is not recovered, fishing operations are substantially more complicated
• Traditional methods involve building a cable head weak-point
• Tension must be applied at, or above weak-point rating• Straight-forward for vertical wells, but becomes more
challenging as borehole deviation increases
• Surface tensions are high in long laterals with high dogleg severity, making it impossible to pull enough tension at surface to break cable head weak-point
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Addressable Separation Tool
• Developed specifically for plug and perf in longer laterals
• Ballistic release and an addressable switch that can be selected and fired on command
• Can run stronger weak-point, reducing the risk for unintentional pump-offs.
Meeting the Challenge – Addressable Separation Tool
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Challenge – Monitor Cable Head Tension
Prevent Pump-Offs and Stuck Tools
• Typically, wireline tension measured at surface and downhole cable head tension estimated based on depth and wireline specifications
• Works well in vertical wells, but suffers as deviation increases
• Very inefficient in horizontal wells, especially long laterals with high dogleg severity
• In long laterals, only small percentage of surface tension applied to cable head
• Difficult to position downhole tools because of lag between wireline movement at surface and tool movement downhole
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Meeting the Challenge – Monitor Tension Downhole
Downhole Tension Tool
• Direct measurement of the cable head tension
• Increase RIH and POOH speed
• Mitigate risk in toe-up wells
• Downhole indication of plug set
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Pre-Job Planning is Critical
• Pump down plug and perf, pumps are kicked on at kick-off point
• Tools are pumped below plug setting depth and pumps are shutdown
• Tools are pulled uphole to set plug and to shoot guns
• Long Laterals with high DLS, can be difficult to pull off bottom due to high tension
• At wellbore angles > 100°the tools will slide down the casing, potentially overrunning wireline
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Meeting the Challenge – Risk Deployment Modeling
Risk Deployment Models
• For highly deviated and extended wells pre-job planning is a necessity
• Model with wireline friction coefficients• Estimates surface & downhole tensions• Determines if completion can be safely
achieved without damage to wireline• Models fluid effect & pump-rates on
tool assembly• Estimates required pump-rates to:
• Deploy tools• Maintain toe-up tool position
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Meeting the Challenge – Risk Deployment
Estimating Pump-Rates
• An average of 6 bpm pump down rate required to maintain tool-string position while pulling out of the hole throughout uphill lateral
• A minimum of 2.2 bpm pump rate was calculated to maintain a balanced cable head tension, i.e. to keep the tools stationary at 114 degrees
• Should pump rate drop out, a negative cable head tension of ~100 lbs. was confirmed, enough to initiate backward movement of the tools
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Meeting the Challenge – Risk Deployment Modeling
After careful analysis of wellbore modeling it was decided that job could proceed at proposed drilling trajectory and could be completed with wireline plug and perforating
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Meeting the Challenge – Job Execution
Job Execution• Five cluster (3.125 in. 660) 36 holes
perforating and composite frac plug tool assembly
• Toe stages were pumped down at 12 bpm, 2100 psi and 260 fpm line speed.
• Surface tension coming off bottom to position to set plug was 2250 lbs. and downhole tension 500 lbs.
• Pump rate 6 bpm while POOH to plug set depth
• Monitored downhole tension to insure it remained above 0 lbs.
• Tools did not slide down inclined casing overrunning cable
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Meeting the Challenge – Job Execution
• After the plug was set, the outside diameter of the tool assembly was reduced. To counter downward tool motion, pump rate immediately increased from 6 to 12 bpm while monitoring downhole tension
• Tools were pulled up at a constant speed while pumping 12 bpm and 5 guns were perforated at appropriate well depths
• After the last guns were shot the line speed was increased as pump rates were lowered
• Once the tools were back to depth where borehole deviation changed from toe-up (~14,000 ft.), pumps were shut down and wireline tools retrieved to surface
• Well was completed with zero failures and no issues with wireline overrun in the inclined casing
2019-NAPS-5.2 Extended Lateral Solutions for an Extremely Difficult Well Trajectory
Summary and Conclusions
• Proper pre-job planning and application of Extended Lateral technology proved to be key to success on a very difficult well with an extreme trajectory
• With advanced well modeling, the pump rates for tool deployment and positioning can be determined
• Jacketed wireline with a downhole tension tool allowed a precise deployment of the tool string while pumping tools uphole at deviations as high as 114°
• Pump rates were adjusted during plug setting and perforating to keep tool-string from sliding down the inclined casing and overrunning wireline
• The use of addressable separation tool allowed running full-strength cable head weak-point, providing wireline engineer additional tension during pump-down operations without fear of pumping tools off wireline
• The ability to successfully complete this well at proposed trajectory with wireline plug and perforating operations allowed well to be drilled as planned and significantly reduced costs for the E&P operator
DALLAS - FORT WORTH. AUGUST 5-6, 2019. QUESTIONS? THANK YOU
2019-NAPS-5.2AUTHORS: Larry Albert, Jason Booher and Anthony Wilson, Allied-Horizontal Wireline Services; Fraser Hamilton and Jason Hradecky, Impact Selector International; Dustin Dunning and Vadim Protasov, WireCo WorldGroup