Presentation

Transcription

Presentation

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
Sucker Rod Pumping Workshop; ©DAL/NWH
2
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
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
4
)
St
re
ss
...
(lb
od
L
Diff. A
Diff. B
Diff. C
Diff D
Diff. E
M
ax
R
M
PR
PP
R
L
(lb
)
TV
L
L
SV
rf
=
W
(lb
)
120.00%
110.00%
100.00%
90.00%
80.00%
(lb
)
Accuracy
Fig. 5. Well #1 Accuracy Comparison
Sept. 16-19, 2014
5
Fig. 8. Well #3b Accuracy Comparison
Accuracy
250.00%
Diff. A
Diff. B
Diff. C
Diff. D
Diff. E
200.00%
150.00%
100.00%
50.00%
i)
)
(p
s
ss
R
M
ax
R
od
S
tre
M
P
PR
L
L
(lb
(lb
)
)
(lb
TV
L
P
W
rf
=
SV
L
(lb
)
0.00%
Sept. 16-19, 2014
6
Results
• Comparison showed not all the required loads and nondimensional 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
7
Sandia well &
operating data
Sept. 16-19, 2014
8
Well No. Depth
PBD (ft)
1
2780
Casing
(in)
5.5
Tubing
(in)
2.875
Seat Nipple TAC Depth Rod No.
Depth (ft)
(ft)
& grade
2710
2647
66/C
Coupling Guides
Size
Installed
FS
2/rod
2
7799
7
2.875
7655
6168
3
9270
5.5
2.875
9220
8968
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
1.25" FRP
SHSM to 4362'; FRP; FSSM 1.0" D to
D
7564'
87/D
SHSM - 1";
w 408'
FSSM 7/8"
1.0" D SB
0
0
9
Well No.
Pump
Dia
Pump
Length
1
(in)
1.5
2
Unit Size
Motor
(Ft)
12
1.5
3
4
5a
5b
6
Sept. 16-19, 2014
Produced
Fluid
228-213-86
(HP)
20
Tubing
Pressure
(psi)
60
Casing
Press
(psi)
0
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
G
0.995
10
N
(spm)
11
S
(in)
86
8.2
144
428'
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'
5a
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'
5b
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)
6
7.1
143.5
1054
Well No.
1
Fluid Level
Tool
FAP (ft)
Depths (ft)
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'
2
3
4
Sept. 16-19, 2014
#1 - below pump;
#2 - above pump @7566';
#3 - 7489' (75' above pump) - NW;
#4 - 4362' (FG to Stl x);
#5 - 4285' (75' above x)
#1 - below pump;
#2 - above pump @2860';
#3 - 2783' (in SB);
Sucker Rod Pumping Workshop;
©DAL/NWH
#4 - 2356'
(SB to 7 x);
#5 - below PR @2'
11
Rod Design Software Evaluated
• 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
Sept. 16-19, 2014
12
Sandia load translation using
DHLC
Sept. 16-19, 2014
13
SANDIA Test AHC SSAU 4115 08/04/96 10:00 AM
Sept. 17 - 20, 2014
14
From L. Rowlan:
“Update on Sandia Downhole
Dynamometer Testing,”
SRL WS, OKC, 09/18/2014
Sept. 16-19, 2014
15
Well 1
Sept. 17 - 20, 2014
2014 Sucker Rod Pumping Workshop
16
Well 2
Sept. 17 - 20, 2014
17
Well 3
Sept. 17 - 20, 2014
18
Well 4
Sept. 17 - 20, 2014
19
Well 5A
Sept. 17 - 20, 2014
20
Well 6
Sept. 17 - 20, 2014
21
Summary –
Programs’ versus actual load
Sept. 16-19, 2014
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
23
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
24
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
25
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
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
27
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
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
Conclusions & Recommendations - cont
• Prog 1 had consistently the worse accuracy
and dramatically over-estimated MPL
• Prog 1 & 3 have provided all the load and nondimensional 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
Copyright
Rights to this presentation are owned by the company(ies)
and/or author(s) listed on the title page. By submitting this
presentation to the Sucker Rod Pumping Workshop, they
grant to the Workshop, the Artificial Lift Research and
Development Council (ALRDC), and the Southwestern
Petroleum Short Course (SWPSC), rights to:
– Display the presentation at the Workshop.
– Place it on the www.alrdc.com web site, with access to the site to be
as directed by the Workshop Steering Committee.
– Place it on a CD for distribution and/or sale as directed by the
Workshop Steering Committee.
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
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.
The views, opinions, and conclusions expressed in these presentations and/or training
materials are those of the author and not necessarily those of the Sponsoring
Organizations. The author is solely responsible for the content of the materials.
The Sponsoring Organizations cannot and do not warrant the accuracy of these
documents beyond the source documents, although we do make every attempt to work
from authoritative sources. The Sponsoring Organizations provide these presentations
and/or training materials as a service. The Sponsoring Organizations make no
representations or warranties, express or implied, with respect to the presentations
and/or training materials, or any part thereof, including any warrantees of title, noninfringement of copyright or patent rights of others, merchantability, or fitness or
suitability for any purpose.
Sept. 16-19, 2014
32
Sept. 16-19, 2014
33

Presentation

Transcription

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