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![Page 1: Don$Robinson,$PE$$ VPDrilling$ Canonsburg,$PA$ 1on$iron$roughneck,$kelly$ hose$and$top$drive.$ * 0.0 10.0 20.0 30.0 ... 1st$Iden]fy$the$Cri] ... vity$Improvementfrom$2010$to$2012$=$](https://reader031.dokumen.tips/reader031/viewer/2022021822/5b1f9b407f8b9ab9748b6056/html5/thumbnails/1.jpg)
Don Robinson, PE VP Drilling Canonsburg, PA 1
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Take Away Points: 1. Advantages of air rigs and/or top hole rigs. 2. You don’t need the Ferrari Rig 3. GeIng beJer requires consistent measuring of performance 4. Modify your team to establish the proper aItude to achieve your goals.
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TOTAL HORIZONTAL MARCELLUS WELLS DRILLED FROM FIRST WELL
IN 2005 THROUGH 2012 = 469
From 2010-‐ 2012 =375 3
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BACKGROUND
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Air Rig Opera]ons
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Horizontal Rig Opera]ons
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Revised Horizontal Rig Opera]ons
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SeIng The Conductor
Fresh Water Zone
Coal Seam Mine – Coal Removed
Marcellus Shale
Onondaga
26” @ 40’
Surface
30” Hole
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SeIng The Water String
Fresh Water Zone
Coal Seam Mine – Coal Removed
Onondaga
26” @ 40’
Surface
20” @ 250’ 24” Hole
30” Hole
Marcellus Shale
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SeIng The Mining String
Fresh Water Zone
Coal Seam
Onondaga
26” @ 40’
Surface
20” @ 250’ 24” Hole
13-‐3/8” @ 400’ 17-‐1/2” Hole
Marcellus Shale
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SeIng The Mining String
Fresh Water Zone
Coal Seam
Onondaga
26” @ 40’
Surface
20” @ 200’ 24” Hole
17-‐1/2” Hole 13-‐3/8” @ 400’
2 Cement Baskets above mine
Balanced Cement Job For Shoe
Marcellus Shale
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SeIng the Intermediate String
Fresh Water Zone
Coal Seam
Onondaga
26” @ 40’
Surface
20” @ 200’ 24” Hole
17-‐1/2” Hole 13-‐3/8” @ 400’
9-‐5/8” @ 2000’ 12-‐1/4” Hole
Marcellus Shale
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SeIng Produc]on String
Fresh Water Zone
Coal Seam
Onondaga
26” @ 40’
Surface
20” @ 250’ 24” Hole
17-‐1/2” Hole 13-‐3/8” @ 400’
9-‐5/8” @ 2000’ 12-‐1/4” Hole
Marcellus Shale
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SeIng Produc]on String
Fresh Water Zone
Coal Seam
Onondaga
26” @ 40’
Surface
20” @ 250’ 24” Hole
17-‐1/2” Hole 13-‐3/8” @ 400’
9-‐5/8” @ 2000’ 12-‐1/4” Hole
Marcellus Shale
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Why Air Rigs?
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1) Daily opera]ons $avings
2) Faster Performance 3) Reduced Collision Risk
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On August 6, 2012 Range’s
New Marcellus Record for Footage Drilled
In 24 Hour period (22.5 hrs Drlg) With Falcon Rig #26
3619’ at Avg ROP of 161 fph
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Is Your Drilling Rig Ford or Ferrari?
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Ferrari Walking Triple
Ford Super Single
1000 HP Draw works 650 HP Draw works
2-‐ 1600 HP Pumps 2 – 1000 HP Pumps
250 Ton Top Drive 150 Ton Top Drive 45, 000 l lbs 30,000 l-‐lbs
3 – 1625 KW Generators 2 – 450 KW Generators
5” Drill Pipe 4-‐1/2” Drill Pipe
500, 000 lbs mast 300,000 lbs mast
Lateral Max -‐ 9000’ Lateral Max – 6000’
PA Mobiliza]on Cost -‐ $500 M PA Mobiliza]on Cost $150 M
Expected Faster Tripping Expected Slower Tripping
Expensive Day Rate 30 % Reduced Day Rate
Walking Ability Skidding Ability
Emission Opportunity PermiJed Loads Reduc]on
90 Loads to Move 50 Loads to Move 19
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HISTORICAL ANNUAL
PERFORMANCE 20
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0.0
10.0
20.0
30.0
40.0
50.0
60.0
70.0
80.0
90.0
100.0 Horizontal Wells Drilled in 2006
Big Rig Days
100% > 20 Days Fastest Well = 35 Days Combined Avg. = 49.3 Days
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0.0
10.0
20.0
30.0
40.0
50.0
60.0
70.0
80.0
90.0
100.0 Horizontal Wells Drilled in 2007
Big Rig Days
Avg. Lateral Length = 2377' 89% > 20 Days * Fastest Well = 18.1 Days (2469' LL) Combined Avg. = 27.4 Days
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0
10
20
30
40
50
60
70
80
90
100 Horizontal Wells Drilled in 2008
Big Rig Days
Air Rig Days
Avg. Lateral Length = 2545'
96% > 20 Days * Fastest Well = 19.0 Days (2235' LL) Combined Avg. = 33.2 Days
3 Sidetracks due to fishing and ]ght hole.
*
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0
10
20
30
40
50
60
70
80
90
100 Horizontal Wells Drilled in 2009
Big Rig Days
Air Rig Days
Avg. Lateral Length = 2891'
76% > 20 Days * Fastest Well = 15.8 Days (2559' LL) Combined Avg. = 26.9 Days
2 Sidetracks due to fishing and ]ght hole.
Big Rig drilled from 1900'. Rig repair on iron roughneck, kelly hose and top drive.
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0.0
10.0
20.0
30.0
40.0
50.0
60.0
70.0
80.0
90.0
100.0 Horizontal Wells Drilled in 2010
Big Rig Days
Air Rig Days
Avg. Lateral Length = 3183' 78% > 20 Days * Fastest Well = 14.1 Days (2334' LL) Combined Avg. = 24.9 Days
Sidetrack due to stuck pipe.
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0
10
20
30
40
50
60
70
80
90
100 Horizontal Wells Drilled in 2011
Big Rig Days
Air Rig Days
Avg. Lateral Length = 2718' 38% > 20 Days * Fastest Well = 11.1 Days (2702' LL) Combined Avg. = 19.5 Days
Fishing during 8 3/4" hole. 2 Sidetracks due to lost motor and collapsed hole.
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0.0
10.0
20.0
30.0
40.0
50.0
60.0
70.0
80.0
90.0
100.0 Horizontal Wells Drilled in 2012
Big Rig Days
Air Rig Days
Avg. Lateral Length = 3123' 13% > 20 Days * Fastest Well = 9.7 Days (3296' LL) Combined Avg. = 16.3 Days
Columbia Storage Field well. An]-‐collision, P&A.
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ANNUAL PERFORMANCE COMPARED
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8.9 10.5 10.4 10.9 8.4
49.3
27.4
24.3
16.4 14.5
8.6
7.9
49.3
27.4
33.2
26.9 24.9
19.5
16.3
0.0
10.0
20.0
30.0
40.0
50.0
60.0
2006 -‐ 3 Wells 2007 -‐ 9 Wells 2008 -‐ 26 Wells 2009 -‐ 54 Wells 2010 -‐ 99 Wells 2011 -‐ 149 Wells 2012 -‐ 127 Wells
Horizontal Wells Drilled 2006 -‐ 2012
Big Rig Days
Air Rig Days
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Summary 2010 Days 2011 Days 2010 to 2011
% ReducWon 2012 Days 2011 to 2012
% ReducWon
Air Rig 10.4 10.9 +5% 8.4 -‐23%
Horizontal 14.5 8.6 -‐41% 7.9 -‐8%
OVERALL 24.9 19.5 -‐22% 16.3 -‐16%
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From 2010 to 2012 Reduced Drilling Days From 24.9 day to 16.3 days (35% Reduc]on)
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HOW WE DID IT
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Keys To Success
• Con]nuous Drilling Program • Stability of Personnel • Focus On Key Performance Indicators (KPI’s) • Incen]ves • Create and Maintain Team Atmosphere • Constant Communica]on • Con]nuous Improvement Focus
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CONTINUOUS DRILLING PROGRAM
• 3 Year Contract • Dependable Drilling Rigs • Working Closely With Drilling Contractor to Improve Opera]ons
• Con]nuity with Key Service Providers
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STABILITY OF PERSONNEL
– Drilling Superintendents – Drilling Supervisors – Drilling Engineers – Drillers – Toolpushers – Direc]onal Drillers
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FOCUS ON KPI’s
• Days per Phase (Air & Horizontal) • Cost per Phase • ROP Slide and Rotate and % • Flat Time analysis • Rig Mobiliza]on Time and Cost
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Eliminate The Train Wrecks
• Wellbore Collisions • Stuck Pipe Leading to Side Tracks • Comple]ons Fracing In To Drilling Well • Stuck Casing • Well Control Issues • Rubble Zones • Geological/Targe]ng Side Tracks
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INCENTIVES: 1st Iden]fy the Cri]cal Performers
• Drilling Superintendents • Drilling Supervisors • Drilling Engineers • Rig Crews – Toolpushers – Drillers
• Direc]onal Drillers • Mud Engineers
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CREATE TEAM ATMOSPHERE
• Establish Clear Responsibili]es • Maintain Accountability • Share Success • Review Failures Without Punishment • Encourage Par]cipa]on at Every Level • Provide Individual Recogni]on When Earned • Work Closely With Service Providers in Non Adversarial Respectul Rela]onships
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C0NSTANT COMMUNICATION • Monthly Mee]ng With Drilling Contractor • Pad Spud Mee]ngs • Daily Conference Calls With Rigs and Office • Superintendents visi]ng rig on near daily basis • Open Door Policy • No BIG ME, liJle YOU AItudes • Par]cipa]on at Every Level • Useful Drilling Programs • Consistent Approach With All Rigs • NO Micro-‐Managing From Office
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CONTINUOUS IMPROVEMENT FOCUS
• All Brine/Polymer Systems • Low Solids Mud • Conven]onal Direc]onal Assemblies • Casing flota]on • Shorter bit to bend motors • Performance Based Bit Selec]ons
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Future Savings Opportuni]es
• Reducing Rig Mobiliza]on Costs • Reducing Loca]on Costs • Reducing Waste Disposal Costs • Reducing Number of Casing Strings
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ANOTHER WAY TO LOOK AT IT…
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Southern Marcellus Shale Division Comparison of 2010 vs. 2011 Wells Drilled Output
2010 Well Count: 122 top holes with 6.4 air rigs/yr avg = 19.1 wells/rig/year 99 horizontal holes with 5.4 H rigs/yr avg = 18.3 wells/rig/year 2011 Well Count: 104 top holes with 3.8 air rigs/yr avg = 27.4 wells/rig/year 149 horizontal holes with 4.9 H rigs/yr avg = 30.4 wells/rig/year Air Rig Improvement = 44% Big Rig Improvement = 66%
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Southern Marcellus Shale Division Comparison of 2011 vs. 2012 Wells Drilled Output
2011 Well Count: 104 top holes with 3.8 air rigs/yr avg = 27.4 wells/rig/year 149 horizontal holes with 4.9 H rigs/yr avg = 30.4 wells/rig/year 2012 Well Count: 126 top holes with 3.3 air rigs/yr avg = 38.2 wells/rig/year 127 horizontal holes with 3.8 H rigs/yr avg = 33.4 wells/rig/year Air Rig Improvement = 39% Big Rig Improvement = 10%
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Summary 2010 Wells/Rig/Year
2011 Wells/Rig/Year
2010 to 2011
% Improve
2012 Wells/Rig/Year
2011 to 2012
% Improve
Air Rig 19.1 27.4 43% 38.2 39%
Horizontal 18.3 30.4 66% 33.4 10%
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Air Rig Produc]vity Improvement from 2010 to 2012 = 100% Big Rig Produc]vity Improvement from 2010 to 2012 = 83%
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Take Away Points: 1. Advantages of air rigs and/or top hole rigs. 2. You don’t need the Ferrari Rig 3. GeIng beJer requires consistent measuring of performance 4. Modify your team to establish the proper aItude to achieve your goals.
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