Bakken Artificial Lift Production Congress 2013 · Bakken Artificial Lift & Production Congress...
Transcript of Bakken Artificial Lift Production Congress 2013 · Bakken Artificial Lift & Production Congress...
Bakken Artificial Lift & Production Congress 2013
Artificial Lift and Production OptimizationHydraulic Pumping Units
Jess Babbitt, Engineering Advisor, Linn Energy
Hydraulic Pumping Units
2.00 Examine HPU’s in Production Operations• HPU’s have proven to reduce downhole failures in other
area’s• HPU’s offer numerous advantages over BPU’s• HPU’s can replace higher volume PU’s for the long term• HPU’s offer greater operating flexibility for the long term
North Dakota’s Production Now Exceeds Alaska
Stephen Sonnenberg, “Interest, Activity Continue in the Bakken,” The 2013 Playbook Bakken/Exshaw, Hart Energy, June 2013, pp 13
Production curve for the Bakken Petroleum System (Bakken and Three Forks). Several cycles are noted on the plot: Antelope field development, Billings Nose horizontal wells, and the middle Bakken development cycle (includes Elm Coulee, Parshall, Sanish, and many other new fields). (Source: Stephen A. Sonneberg; production data from HIS)
Bakken/Three Forks Production
Maggie Salamon, “Bakken: Both Sides of the Border,” The 2013 Playbook Bakken/Exshaw, Hart Energy, June 2013, pp 96
Bakken/Three Forks production forecast includes a selection of publically traded companies. (Source: North American Shale Quarterly [NASD], 1Q 2013)
1.2 m b/day Projected
Alberta Bakken Production
Maggie Salamon, “Bakken: Both Sides of the Border,” The 2013 Playbook Bakken/Exshaw, Hart Energy, June 2013, pp 98
Alberta Bakken production forecast includes a selection of publically traded companies and private companies from Hart Energy. (Source: North American Shale Quarterly [NASD], 1Q 2013)
60 k boe/day
Bakken/Three Forks Cross‐Section
Darren Barbee, “The Bakken Get A Let Up,” Oil and Gas Investor, Hart Energy, May 2013, pp 68
Typical Artificial Lift
BPU C1280, C912
Darren Barbee, “The Bakken Get A Let Up,” Oil and Gas Investor, Hart Energy, May 2013, pp 69
BAKKENPLAY
RotaFlex PU’s BAKKENPLAY
Common Wellbore Diagram BAKKENPLAY
Common Failures BAKKENPLAY
Common Failures BAKKENPLAY
Lost Produ
ction
Lost Produ
ction
Lost Produ
ction
Common Failure Frequencies BAKKENPLAY
Potential w/oFailures
Avg. Productionwith Failures
Lost Produ
ction
Lost Produ
ction
Lost Produ
ction
High Failure Frequency912 PU
Another Operator’s Perspective
Operators CommentsRod pump system too large Tried reduced pump sizesDifficult to obtain correct sizingSpeed x stroke length changes dangerous and expensivePulling units and crews – long lead timeNeed a change of surface equipment to obtain slower stroke speed and stroke length – over pumping is a problem
A SolutionHydraulic PU’s vs. Conventional PU’s
• Safety• No rotating counter weights• No pinch points• No need for fencing around the PU
• Reduced rod and pump wear• Easy to tag bottom• Easy to change SPM• Smaller foot print• Reduced down hole failures
• Fewer workovers• Adapts easily to dual casing wells
Operator’s Perspective
Operator’s Perspective Hydraulic PU’s vs. Conventional PU’s
• Requires no foundationNo foundation leveling following freeze and thaw
• Reduced trucking costsOne truck load vs. three+
• Fast rig up ‐ ~3 hours• Reduced Installation Costs
$6K – vs. ~$20K x 3days• No stuffing boxes• No guy wires
Direct Mount Unit
Operator’s Perspective
HPU Delivery vs. BPU Delivery
Conventional Units Hydraulic PU912, 192” stroke, 4.5 SPM1280, 192” stroke, 4.5 SPM 300” stroke unit, 2.5SPM
Rod x Pump reversals– 2.4 M times/year
Rod x Pump Reversals– 1.3 M million times per year
44.5% Reduction Over all benefit or reduced strokes• Less rod failures ‐ reduced rod reversals• Less rod wear – slower travel, less friction, less stacking at
the btm• Lower pump intake rate may reduce sand issues• Pump ware is spread out over a longer distance
Less Rod Wear and Longer Pump LifeFewer Pulling Jobs and Less Down Time
Conventional BPU Well Performance
Tubing Failures and Rod WearNear the Bottom of the Hole
Add 6‐10 jts. EndurAlloy tbg.(4x Harder than J‐55) above SN
Cotton Valley Well on HPUfollowing Minor Tubing Repair
0
100
200
300
400
500
600
700
9 8 7 6 5 4 3 2.25 1.75 1.25 .75
Barrels Fluid Pe
r Day
Strokes Per Minute
1280Beam Unit
912Beam Unit
400Hydraulic Unit
CyclesPer Day
12,960
11,520
10,080
8,640
7,200
5,760
4,320
3,600
2,520
1,800
1,080
2.5
Production by Unit Type
Summary
HPU• Alternative to conventional• Possible secondary rod lift method• Reduced down hole failures• Easy operations• Reduced cost
– Trucking– Install– Time
• Eliminates foundation failures