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10th Annual Sucker Rod
Pumping Workshop Renaissance Hotel
Oklahoma City, Oklahoma
September 16 - 19, 2014
Rod String Design Software Simulation of Sandia Downhole
Load Cell Wells by
Norman W. Hein, Jr., P.E. – Norris/AOT & DAL
Lynn Rowlan – Echometer
Scott Malone – Norris | DAL
Content
• Background & prior software simulation
comparison
• Sandia well & operating information
• Rod string software & results
• Comparison with actual loads
• Summary & Conclusions
Sept. 16-19, 2014 2 Sucker Rod Pumping Workshop; ©DAL/NWH
Background
“A Current Comparison of Sucker Rod String
Design Programs”
By
Norman W. Hein, Jr., P.E.
Oil & Gas Optimization Specialists, Ltd.
&
Russell Stevens,
Norris
Paper #7 - Presented at Southwestern Petroleum
Short Course (SWPSC) , April 21/22, 2004
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 3
Purpose
• Compared “predictive” steel, “vertical”
rod string design results to actual
dynamometer cards using:
– Q Rod
– Rod Star
– S Rod
– Lufkin LoadCalB (API)
– Conoco Modified API (no sinker bars)
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 4
Fig. 5. Well #1 Accuracy Comparison
80.00%
90.00%
100.00%
110.00%
120.00%
Wrf
=SVL
(lb)
TVL
(lb)
PPR
L (lb)
MPRL
(lb)
Max
Rod
Stre
ss...
Accu
racy
Diff. A
Diff. B
Diff. C
Diff D
Diff. E
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 5
Fig. 8. Well #3b Accuracy Comparison
0.00%
50.00%
100.00%
150.00%
200.00%
250.00%
Wrf
=SVL (lb
)
TVL (lb
)
PPRL
(lb)
MPR
L (lb
)
Max
Rod
Stre
ss (p
si)
Ac
cu
rac
y
Diff. A
Diff. B
Diff. C
Diff. D
Diff. E
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 6
Results
• Comparison showed not all the required loads and non-
dimensional operating parameters that are required for
optimization and troubleshooting were provided by all
the programs
• Inaccuracies may be within 10 to 15% for simple string
• When sinker bars installed and comparison made,
inaccuracies may be from -40% to +25% of actual
measurements
• Maintained belief that programs cannot accurately
predict dynamic effects of sinker bars
• Some programs were changed over time plus new
capabilities of designing effect of well bore deviations
included
Sept. 16-19, 2014
Sucker Rod Pumping Workshop; ©DAL/NWH 7
Sandia well & operating data
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Well No. Depth Casing Tubing Seat Nipple TAC Depth Rod No. Coupling Guides
PBD (ft) (in) (in) Depth (ft) (ft) & grade Size Installed 1 2780 5.5 2.875 2710 2647 66/C FS 2/rod
2 7799 7 2.875 7655 6168 1.25" FRP
to 4362';
1.0" D to
7564'
SHSM -
FRP; FSSM -
D
0
3 9270 5.5 2.875 9220 8968 87/D
w 408'
1.0" D SB
SHSM - 1";
FSSM 7/8"
0
4 3090 5.5 2.875 3061 3058 76/D
w 300'
1.25" SB
FS 0
5a 5278 5.5 2.875 5060 4970 86/D
w 250'
1.5" SB
SH - 1";
FS - rest
2/rod on
3/4"
5b 5278 5.5 2.875 5060 4970 86/D
w 250'
1.5" SB
SH - 1";
FS - rest
2/rod on
3/4"
6 2975 5.5 2.875 2909 2603 77/N-97
w 500'
1.5" SB
FSSM 0
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 10
Well No.
1
2
3
4
5a
5b
6
Pump
Dia Pump
Length Unit Size Motor Tubing Casing Produced
Fluid
(in) (Ft) (HP) Pressure
(psi) Press
(psi) G 1.5 12 228-213-86 20 60 0 0.995
1.5 30 M640-305-144 75 45 76 1.027
2.25 35 Rotoflex
1100-500-306
100 40 40 1.019
1.5 26 M640-305-168 40 20 0 1
2 24 M640-305-168 60 205 180 0.982
2 24 M640-305-168 60 205 180 0.982
2.25 24 456-305-144 72 43 vacuum 1.015
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 11
Well No.
1
2
3
4
5a
5b
6
N S Fluid Level Tool
(spm) (in) FAP (ft) Depths (ft) 11 86 2710 #1- below pump - Not Work (NW);
#2 - above pump @2689';
#3 - 2462' (in 3/4");
#4 - 1010' (in 3/4");
#5 - Below PR @2'
8.2 144 428' #1 - below pump;
#2 - above pump @7566';
#3 - 7489' (75' above pump) - NW;
#4 - 4362' (FG to Stl x);
#5 - 4285' (75' above x)
3.9 306 86 #1 - above pump 9229';
#2 - 9087' (in 1" SB);
#3 - 8785' (in 1" SB);
#4 - 7658' (SB to 7 x);
#5 - 7506' (in 7/8")
4.58 168 243 #1 - below pump;
#2 - above pump @3010';
#3 - 2708' (SB to 6 x);
#4 - 1006' (6 to 7 x);
#5 - below PR @2'
9.1 168 4767 #1 - below pump;
#2 - above pump @4993';
#3 - 4741' (SB to 7 x);
#4 - 4714' (25' above x);
#5 - below PR @2'
6.5 168 4767 #1 - below pump;
#2 - above pump @4993';
#3 - 4741' (SB to 6 x);
#4 - 3114' (6 to 7 x);
#5 - 1512 (7 to 8 x)
7.1 143.5 1054 #1 - below pump;
#2 - above pump @2860';
#3 - 2783' (in SB);
#4 - 2356' (SB to 7 x);
#5 - below PR @2'
Rod Design Software Evaluated
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 12
• Programs considered:
– QRod
– RodStar
– Srod
• Program defaults used
• Assumption for pump/plunger friction = -200 pounds
While some wells reported with guides, deviation surveys
not available so assumption all wells vertical
• Assumed friction coefficient = 0.2 no guides; 0.3 w/guides
• One program did not have the Rotoflex geometry in
analysis capabilities; so CW Conventional unit used
Sandia load translation using DHLC
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 13
Sept. 17 - 20, 2014 14
SANDIA Test AHC SSAU 4115 08/04/96 10:00 AM
From L. Rowlan:
“Update on Sandia Downhole Dynamometer Testing,”
SRL WS, OKC, 09/18/2014
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Well 1
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Well 2
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Well 3
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Well 4
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Well 5A
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Well 6
Summary – Programs’ versus actual load
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 22
Tabular Comparison – Well 1
Load Sandia Prog 1 % Prog 2 % Prog 3 %
PPRL 8815 8661 -1.7 8746 -0.7 8736 -0.9
MPRL 1979 1600 -19.1 1797 -9.2 2167 -0.9
MPL -58 -744 +138 0 1 -200 +245
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 23
Tabular Comparison – Well 2
Load Sandia Prog 1 % Prog 2 % Prog 3 %
PPRL 18.613 21,221 +14 20,484 +10.0 20,669 -+11.0
MPRL 5932 6074 +2.4 6224 +4.9 5547 -6.5
MPL +217 -2838 -1208 0 1 -200 -7.8
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 24
Tabular Comparison – Well 3
Load Sandia Prog 1 % Prog 2 % Prog 3 %
PPRL 39,972 52,459 +31.2 42,639 +10.6 40,799 +2.1
MPRL 16.148 21,457 +32.9 14,134 -11.5 14298 -11.5
MPL +230 -3367 -2710 0 1 -200 -13.2
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 25
Tabular Comparison – Well 4
Load Sandia Prog 1 % Prog 2 % Prog 3 %
PPRL 8,656 8.946 +3.3 10,280 +18.7 8,462 -2.2
MPRL 1,977 3,673 +85.8 2,201 +11.3 2,470 +24.9
MPL -93 -2,613 -2710 0 1 -200 +115
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 26
Tabular Comparison – Well 5A
Load Sandia Prog 1 % Prog 2 % Prog 3 %
PPRL 15,507 16,389 +5.68 15,701 +1.25 16.926 +9.1
MPRL 6651 7161 +7.7 7054 +6.1 6980 +4.9
MPL -34 -4403 -4502 0 1 -254 -647
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 27
Tabular Comparison – Well 6
Load Sandia Prog 1 % Prog 2 % Prog 3 %
PPRL 13,344 15,276 14.5 12,743 -4.5 10,582 -20.7
MPRL 7040 4485 -36.3 4295 -39.9 2793 -60.3
MPL +804 -2788 -2467 0 1 -200 -75.1
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 28
Conclusions & Recommendations
• Currently program 2 &3 are very close to the
same accuracy
• Program 3 had a consistent -200 pound
minimum pump load (MPL) which was related
to the 200 pound of assumed pump friction
• If this friction was removed, then MPL would
be very close
Sept. 16-19, 2014 29 Sucker Rod Pumping Workshop; ©DAL/NWH
Conclusions & Recommendations - cont
• Prog 1 had consistently the worse accuracy
and dramatically over-estimated MPL
• Prog 1 & 3 have provided all the load and non-
dimensional pumping parameters while prog 2
still is missing N/No’
• While there were instances where there was a
negative MPL, these loads did not increase
nor stay applied over the plunger stroke
length
Sept. 16-19, 2014
30 Sucker Rod Pumping Workshop; ©DAL/NWH
Copyright
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Other use of this presentation is prohibited without the expressed written permission of the author(s). The owner company(ies) and/or author(s) may publish this material in other journals or magazines if they refer to the Sucker Rod Pumping Workshop where it was first presented.
Sept. 16-19, 2014 Sucker Rod Pumping Workshop; ©DAL/NWH 31
Disclaimer
The following disclaimer shall be included as the last page of a Technical Presentation or Continuing Education Course. A similar disclaimer is included on the front page of the Sucker Rod Pumping Web Site.
The Artificial Lift Research and Development Council and its officers and trustees, and the Sucker Rod Pumping Workshop Steering Committee members, and their supporting organizations and companies (here-in-after referred to as the Sponsoring Organizations), and the author(s) of this Technical Presentation or Continuing Education Training Course and their company(ies), provide this presentation and/or training material at the Sucker Rod Pumping Workshop "as is" without any warranty of any kind, express or implied, as to the accuracy of the information or the products or services referred to by any presenter (in so far as such warranties may be excluded under any relevant law) and these members and their companies will not be liable for unlawful actions and any losses or damage that may result from use of any presentation as a consequence of any inaccuracies in, or any omission from, the information which therein may be contained.
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Sept. 16-19, 2014
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