Evaluation of Drilling Rig Performance Characteristics
CADE/CAODC 2009 Annual Drilling Conference
Evaluation of Drilling Rig Performance Characteristics Quinton T. Foulston, P.Eng. Precision Drilling
1
I will: 1. Explore some of the ambiguities around the traditional RIG DEPTH RATING 2. Describe four (4) ALTERNATE drilling rig performance CHARACTERISTICS 3. Conclude with a brief summary
2
Metrics commonly referred to when selecting a drilling rig in the US & International markets: ¾ Drawworks horsepower ¾ Mast size & hookload ¾ Rig depth rating (often based on max depth of depth range assigned by drawworks OEM)
3
Metrics commonly referred to when selecting a drilling rig in the US & International markets: ¾ Drawworks horsepower ¾ Mast size & hookload ¾ Rig depth rating (often based on max depth of depth range assigned by drawworks OEM) Metrics commonly referred to when selecting a drilling rig in the Canadian market: ¾ Rig depth rating ¾ Mast size & hookload 4
In order to assign a RIG DEPTH RATING, a Drilling Contractor must make AMBIGUOUS assumptions about the following: ¾ ¾ ¾ ¾ ¾
well profile mud weight drillstring design casing design condition of the hole
5
Four (4) ALTERNATE metrics: What can the rig PULL? 1. when stuck, or when running casing? 2. when POOH near TD? How much pipe can the rig RACK? 3. based on the geometry of the selected pipe? 4. based on the weight of the selected pipe?
6
Four (4) ALTERNATE metrics: What can the rig PULL? 1. when stuck, or when running casing? 2. when POOH near TD? How much pipe can the rig RACK? 3. based on geometry? 4. based on weight?
7
What the drilling rig* can PULL is determined by comparing: • Mast • Drilling line • Drawworks
8
Consideration of the MAST when determining what the rig can PULL
9
Typical MAST placard as per 3rd Edition of API 4F showing the maximum static hookload capacities
10
Consideration of the WIRE ROPE when determining what the rig can PULL
11
Minimum WIRE ROPE design factors (select values taken from API RP9B 12th Edition): Rotary drilling line Rotary drilling line when setting casing Pulling on stuck pipe
3 2 2
Typical 6X19 IWRC drill line construction 12
Consideration of the DRAWWORKS when determining what the rig can PULL
13
Example of DRAWWORKS placard maximum hookload capacities
14
Consider the ACTUAL DRAWWORKS PRIME MOVER when determining what the rig can PULL 15
Q1: What can the rig PULL when stuck, or running casing?
16
Stuck pipe or casing running operations typically require the HIGHEST HOOKLOADS of the planned well
17
1. What the rig can PULL when stuck or running casing, is the lesser of: ¾ Mast static hookload ¾ HL using 2:1 SF on fastline breaking strength ¾ drawworks OEM max HL or max SLP/HL calc from actual input torque
18
Q2: What can the rig PULL when tripping? At what speed? With what overpull?
19
Tripping operations typically require the HIGHEST HOISTING SPEEDS. The HORSEPOWER of the drawworks prime mover defines the relationship between hookload and hoisting speed. 20
* Percentages (%) of maximum capacities in Q1: Overpull
Wire Rope
Reduced ‘Drilling’ Capacity
33% (SF=2:1)
66% (SF=3:1)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are specified:
Mast Drawworks
specified OP specified OP
(100% less OP) (100% less OP)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are NOT specified, the Drilling Contractor can make reductions to the mast & drawworks capacities based on the size of the drilling rig:
Singles Doubles Triples
15% 85% 20% 80% 25% (up to 100kip) 75%
21
* Percentages (%) of maximum capacities in Q1: Overpull
Wire Rope
Reduced ‘Drilling’ Capacity
33% (SF=2:1)
66% (SF=3:1)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are specified:
Mast Drawworks
specified OP specified OP
(100% less OP) (100% less OP)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are NOT specified, the Drilling Contractor can make reductions to the mast & drawworks capacities based on the size of the drilling rig:
Singles Doubles Triples
15% 85% 20% 80% 25% (up to 100kip) 75%
22
* Percentages (%) of maximum capacities in Q1: Overpull
Wire Rope
Reduced ‘Drilling’ Capacity
33% (SF=2:1)
66% (SF=3:1)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are specified:
Mast Drawworks
specified OP specified OP
(100% less OP) (100% less OP)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are NOT specified, the Drilling Contractor could make reductions to the mast & drawworks capacities, for drilling, based on the size of the rig:
Singles Doubles Triples
15% 85% 20% 80% 25% (up to 100kip) 75%
23
1. What the rig can PULL when stuck or running casing, is the lesser of: ¾ Mast static hookload ¾ HL using 2:1 SF on fastline breaking strength ¾ drawworks OEM max HL or max SLP/HL calc from actual input torque 2. What the rig can POOH near TD at a desired block speed w/an overpull contingency, is the ¾lesser of: Mast static hookload less an overpull ¾ HL using 3:1 SF on fastline breaking strength ¾ calc HL from actual drwks HP & desired block speed, or drawworks max HL less an overpull 24
How much pipe can the rig RACK?
25
Clarification of term definitions – as they relate to this presentation: ‘RACKING CAPACITY – number of stands that can be stood on the floor based on the geometry of the monkeyboard and racking floor ‘SETBACK CAPACITY – maximum uniform weight of tubulars that can be supported by the racking floor
26
Four (4) ALTERNATE metrics: What can the rig PULL? 1. when stuck, or when running casing? 2. when POOH near TD? How much pipe can the rig RACK? 3. based on geometry? 4. based on weight?
27
How much pipe the rig can RACK geometrically is generally based on: ¾Size of the selected tubulars ¾Geometry of the MB ¾Footprint of the racking floor
28
Common drillpipe dimensions: ¾ ¾ ¾
4” 15.7# DP w/ new NC40 5.25” OD TJ 4 ½” 16.6# DP w/ new NC46 6.50” OD TJ 5” 19.5# DP w/ new NC50 6.625” OD TJ
29
RACKING CAPACITIES based on MB geometry: 126 triple stands w/4” DP/HWDP (3570m) 108 triple stands w/4 ½” or 5” DP/HWDP (3060m) 10 triple stands of 6 ½” collars (280m)
30
A space between the DS & ODS pipe is retained to: ¾ Lay‐down directional tools when tripping ¾ Create clear path for wireline when logging at TD ¾ Run long string of casing when on a multi‐well pad m31
Gatorbacks, commonly used in the Canadian drilling industry to prevent iceplugs, can limit the number of stands that can be RACKED ‐ regardless of pipe size 32
Distinct metrics that would more clearly define the geometrical RACKING capability of a drilling rig: ¾ ¾ ¾
RACKING CAPACITY (m) of 4” DP/HWDP RACKING CAPACITY (m) of 4 ½” or 5” DP/HWDP RACKING CAPACITY (m) of COLLARS 33
Four (4) ALTERNATE metrics: What can the rig PULL? 1. when stuck, or when running casing? 2. when POOH near TD? How much pipe can the rig RACK? 3. based on geometry? 4. based on weight?
34
Q4: How much pipe can the rig RACK – based on weight?
The SETBACK CAPACITY typically reflects a uniform loading assumption that may not consider the localized loading of HWDP. 35
No monkeyboard. No racking floor.
36
No RACKING or SETBACK limitations.
37
This presentation encourages the Operator and Drilling Contractor to collaboratively determine the loads that are specific to the planned well(s); and compare these estimated loads to a more transparent summary of DRILLING RIG CAPABILITIES – rather than rely on an ambiguous rig depth rating to evaluate the suitability of a particular rig for a particular well program. Doing so will refine the rig selection process; and may ultimately reduce the COST to drill the planned well(s). 38
Evaluation of Drilling Rig Performance Characteristics Quinton T. Foulston, P.Eng. Ph. 403‐716‐4642
Thank‐you for your interest in this presentation. Are there any questions? 39
Evaluation of Drilling Rig Performance Characteristics Quinton T. Foulston, P.Eng. Precision Drilling
1
I will: 1. Explore some of the ambiguities around the traditional RIG DEPTH RATING 2. Describe four (4) ALTERNATE drilling rig performance CHARACTERISTICS 3. Conclude with a brief summary
2
Metrics commonly referred to when selecting a drilling rig in the US & International markets: ¾ Drawworks horsepower ¾ Mast size & hookload ¾ Rig depth rating (often based on max depth of depth range assigned by drawworks OEM)
3
Metrics commonly referred to when selecting a drilling rig in the US & International markets: ¾ Drawworks horsepower ¾ Mast size & hookload ¾ Rig depth rating (often based on max depth of depth range assigned by drawworks OEM) Metrics commonly referred to when selecting a drilling rig in the Canadian market: ¾ Rig depth rating ¾ Mast size & hookload 4
In order to assign a RIG DEPTH RATING, a Drilling Contractor must make AMBIGUOUS assumptions about the following: ¾ ¾ ¾ ¾ ¾
well profile mud weight drillstring design casing design condition of the hole
5
Four (4) ALTERNATE metrics: What can the rig PULL? 1. when stuck, or when running casing? 2. when POOH near TD? How much pipe can the rig RACK? 3. based on the geometry of the selected pipe? 4. based on the weight of the selected pipe?
6
Four (4) ALTERNATE metrics: What can the rig PULL? 1. when stuck, or when running casing? 2. when POOH near TD? How much pipe can the rig RACK? 3. based on geometry? 4. based on weight?
7
What the drilling rig* can PULL is determined by comparing: • Mast • Drilling line • Drawworks
8
Consideration of the MAST when determining what the rig can PULL
9
Typical MAST placard as per 3rd Edition of API 4F showing the maximum static hookload capacities
10
Consideration of the WIRE ROPE when determining what the rig can PULL
11
Minimum WIRE ROPE design factors (select values taken from API RP9B 12th Edition): Rotary drilling line Rotary drilling line when setting casing Pulling on stuck pipe
3 2 2
Typical 6X19 IWRC drill line construction 12
Consideration of the DRAWWORKS when determining what the rig can PULL
13
Example of DRAWWORKS placard maximum hookload capacities
14
Consider the ACTUAL DRAWWORKS PRIME MOVER when determining what the rig can PULL 15
Q1: What can the rig PULL when stuck, or running casing?
16
Stuck pipe or casing running operations typically require the HIGHEST HOOKLOADS of the planned well
17
1. What the rig can PULL when stuck or running casing, is the lesser of: ¾ Mast static hookload ¾ HL using 2:1 SF on fastline breaking strength ¾ drawworks OEM max HL or max SLP/HL calc from actual input torque
18
Q2: What can the rig PULL when tripping? At what speed? With what overpull?
19
Tripping operations typically require the HIGHEST HOISTING SPEEDS. The HORSEPOWER of the drawworks prime mover defines the relationship between hookload and hoisting speed. 20
* Percentages (%) of maximum capacities in Q1: Overpull
Wire Rope
Reduced ‘Drilling’ Capacity
33% (SF=2:1)
66% (SF=3:1)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are specified:
Mast Drawworks
specified OP specified OP
(100% less OP) (100% less OP)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are NOT specified, the Drilling Contractor can make reductions to the mast & drawworks capacities based on the size of the drilling rig:
Singles Doubles Triples
15% 85% 20% 80% 25% (up to 100kip) 75%
21
* Percentages (%) of maximum capacities in Q1: Overpull
Wire Rope
Reduced ‘Drilling’ Capacity
33% (SF=2:1)
66% (SF=3:1)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are specified:
Mast Drawworks
specified OP specified OP
(100% less OP) (100% less OP)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are NOT specified, the Drilling Contractor can make reductions to the mast & drawworks capacities based on the size of the drilling rig:
Singles Doubles Triples
15% 85% 20% 80% 25% (up to 100kip) 75%
22
* Percentages (%) of maximum capacities in Q1: Overpull
Wire Rope
Reduced ‘Drilling’ Capacity
33% (SF=2:1)
66% (SF=3:1)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are specified:
Mast Drawworks
specified OP specified OP
(100% less OP) (100% less OP)
______________________________________________________________________________________________________________________________________________________________
When overpull requirements are NOT specified, the Drilling Contractor could make reductions to the mast & drawworks capacities, for drilling, based on the size of the rig:
Singles Doubles Triples
15% 85% 20% 80% 25% (up to 100kip) 75%
23
1. What the rig can PULL when stuck or running casing, is the lesser of: ¾ Mast static hookload ¾ HL using 2:1 SF on fastline breaking strength ¾ drawworks OEM max HL or max SLP/HL calc from actual input torque 2. What the rig can POOH near TD at a desired block speed w/an overpull contingency, is the ¾lesser of: Mast static hookload less an overpull ¾ HL using 3:1 SF on fastline breaking strength ¾ calc HL from actual drwks HP & desired block speed, or drawworks max HL less an overpull 24
How much pipe can the rig RACK?
25
Clarification of term definitions – as they relate to this presentation: ‘RACKING CAPACITY – number of stands that can be stood on the floor based on the geometry of the monkeyboard and racking floor ‘SETBACK CAPACITY – maximum uniform weight of tubulars that can be supported by the racking floor
26
Four (4) ALTERNATE metrics: What can the rig PULL? 1. when stuck, or when running casing? 2. when POOH near TD? How much pipe can the rig RACK? 3. based on geometry? 4. based on weight?
27
How much pipe the rig can RACK geometrically is generally based on: ¾Size of the selected tubulars ¾Geometry of the MB ¾Footprint of the racking floor
28
Common drillpipe dimensions: ¾ ¾ ¾
4” 15.7# DP w/ new NC40 5.25” OD TJ 4 ½” 16.6# DP w/ new NC46 6.50” OD TJ 5” 19.5# DP w/ new NC50 6.625” OD TJ
29
RACKING CAPACITIES based on MB geometry: 126 triple stands w/4” DP/HWDP (3570m) 108 triple stands w/4 ½” or 5” DP/HWDP (3060m) 10 triple stands of 6 ½” collars (280m)
30
A space between the DS & ODS pipe is retained to: ¾ Lay‐down directional tools when tripping ¾ Create clear path for wireline when logging at TD ¾ Run long string of casing when on a multi‐well pad m31
Gatorbacks, commonly used in the Canadian drilling industry to prevent iceplugs, can limit the number of stands that can be RACKED ‐ regardless of pipe size 32
Distinct metrics that would more clearly define the geometrical RACKING capability of a drilling rig: ¾ ¾ ¾
RACKING CAPACITY (m) of 4” DP/HWDP RACKING CAPACITY (m) of 4 ½” or 5” DP/HWDP RACKING CAPACITY (m) of COLLARS 33
Four (4) ALTERNATE metrics: What can the rig PULL? 1. when stuck, or when running casing? 2. when POOH near TD? How much pipe can the rig RACK? 3. based on geometry? 4. based on weight?
34
Q4: How much pipe can the rig RACK – based on weight?
The SETBACK CAPACITY typically reflects a uniform loading assumption that may not consider the localized loading of HWDP. 35
No monkeyboard. No racking floor.
36
No RACKING or SETBACK limitations.
37
This presentation encourages the Operator and Drilling Contractor to collaboratively determine the loads that are specific to the planned well(s); and compare these estimated loads to a more transparent summary of DRILLING RIG CAPABILITIES – rather than rely on an ambiguous rig depth rating to evaluate the suitability of a particular rig for a particular well program. Doing so will refine the rig selection process; and may ultimately reduce the COST to drill the planned well(s). 38
Evaluation of Drilling Rig Performance Characteristics Quinton T. Foulston, P.Eng. Ph. 403‐716‐4642
Thank‐you for your interest in this presentation. Are there any questions? 39
