This document discusses a proposal to perforate an additional interval in the B3 Upper reservoir of the RDT-1P well in Block 11-2 offshore Vietnam. The objectives are to increase gas and condensate production rates and recovery from the RD/RDT gas field. Reservoir modeling and production forecasting under two scenarios, with and without a barrier between the B3 Upper and Lower intervals, indicate the additional perforation could increase gas rates by 0.85-1.15 MMscfd and condensate rates by 29.6-35.2 bbl/d. Simple economics estimates a payback period of 1-3 months and over $7 million in net cash flow. The proposal is recommended for approval

1. RDT-1P B3 Upper Reservoir Perforation
KNOC Operating Office in HCMC, Vietnam

2. Block Overview
2
Block 11-2
• Location: 320km from Vung Tau
• Basin: Nam Con Son
• Operator: KNOC
• KC (75%), PVEP (25%)
• First Gas : 25th Dec., 2006

3. Production Enhancement
3
Objectives • To increase gas flow rate and recovery of RD/RDT gas field
• To make decision for additional perforation interval
• To evaluate post perforation job
Terms • January ~ September 2022
Budget • In-house
Work Scope • Petrophysical review
• GWC review
• Review previous PLT and perforation effects
• RDT water production history matching
• Forecasting the perforation effects
• Depth matching of B-3 Upper zone
• Post job evaluation for additional RDT perforation
2022 Work Program
Budget (K USD)
Firm Contingent
Production Enhancement - -
• RDT additional perforation - -

4. Depth Structure Map of B3
4

5. IOI Properties
5
RDT-2P
RDT-1RX
RDT-1P
• Net Pay : 2.48 mTVD
• Av. Phie : 14.8%
• Av. Sw : 49.8%
• Av. Vcl : 24.9%
• Av. Klog-Core : 20.2 mD
B-3 Top Depth Structure Map
6.75 in
RDT-1P
Additional Perforation Interval
1.27 MMscfd
42 stbd

6. IOI (Interval Of Interesting, B-3 Upper)
6
Perforated
Perforated

7. IOI (Interval Of Interesting, B-3 Upper)
7
RDT-1P
RDT-2P

8. IOI (Interval Of Interesting, B-3 Upper)
8
Perforated

9. Sw Intersections of B3 Reservoir
9
N S
W E
RDT-1P
RDT-1P
RDT-1X
RDT-2P
RDT-1X
RDT-2P

10. GWC and B3 Perforation Intervals
10
<B3 Depth Map>
GWC
GWC
W E
NW SE
Perf. Perf.
Perf.
Perf.
RDT-1P
RDT-2P
RDT-1P
RDT-2P

11. Seal Capability btw B3 Up. & Lw.
11
B3
C1
C2
Max. 0.51 Vcl
Max. 0.94 Vcl
Max. 0.70 Vcl
?

12. 2 Scenarios of Production Forecast
12
#1 : Barrier Case (Forecast)
#2 : No Barrier Case (Forecast)
Perforated
Seal
U
U
L
C
- Effective Porosity : < <
- Permeability : < <
C L
U
C L
Seal No Seal
?
No Seal
5% 7%
2%
Water
Conning
Initial
GWC

13. Producing Zone of RDT Wells
13
Well RDT-2P RDT-1P
Well Test Date November, 2021
Gas MMscfd 1.77 3.87
Producing
Zones
(PLT)
PLT
Date
Mar 2017 May 2018
Contribution
Gas
(MMscf/d)
Contribution
Gas
(MMscf/d)
A0 84% 1.49
A1 13% 0.23
A1.5 2% 0.04
A2
A3 1% 0.02 17% 0.66
B2 13% 0.50
B3 44% (2015 PLT) 3.53 (2015 PLT) 33% 1.28
C1 1% 0.04
C2 36% 1.39
RDT-1P
RDT-2P
144% 100%
A0
A0.5
A1
A1-5
A2
A3
B1
B3
C1 upper
C1 lower
C2
D1a
A 3
B 2
B 3
C 1
C 2U
C 2L
D 1b
D 3
D 4
D 5U
D 5L
Dec 2015
Mar 2017
Mar 2016
Mar 2015
Dec 2015
Mar 2015
Jun 2012
Jun 2012
Jun 2012
Jun 2012
Mar 2016
Dec 2018
Mar 2015
Mar 2016
Mar 2015
Jul 2009
May 2011

14. Production History Of RDT Wells
14
4
130
0
500
1,000
1,500
2,000
2,500
3,000
3,500
0
10
20
30
40
50
60
70
BBL/D
MMSCF/D
RDT-1P Production
Gas Condensate
2
12 0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
4,500
0
10
20
30
40
50
60
70
80
90
BBL/D
MMSCF/D
RDT-2P Production
Gas Condensate
C1+D1+D3+D4+D5 C1+C2+D1+D3+D4+D5 C1+C2UP A3+B3+C1+C2UP A3+B2+B3+C1+C2UP
B1+B3+C1+C2+D1 B1+B3 A1.5+A3+B1+B3 A0+A1+A1.5+A2+A3 A0+A1+A1.5+A2+A3+B1+B3

15. B3 Production History (RDT-2P)
15
PLT (12 Mar 2013)
52%
PLT(04 Mar 2015)
96%
PLT(01 Dec 2015)
※ (Total Production of RDT-2P) × (Contribution Ratio of B3 by PLT) = B3 Production
B3
Perforation
Push down HEX Plug
to below B3 (Dec, 2018)
A0
A0.5
A1
A1-5
A2
A3
B1
B3
C1 upper
C1 lower
C2
D1a
E1
F1
0.56 MMSCF/D
3.69 BBL/D
30.5% (=44%/144%)
PLT (07 Mar 2017)
44%
(B3/RDT-2P Ratio)
HEX Plug Set
@ above B1
(due to 1,425 bblw/d)

16. B3 Production History (RDT-1P)
16
PLT(01 Dec 2015) PLT(23 Mar 2016)
PLT(04 Mar 2017)
PLT(24 May 2018)
1.27 MMSCF/D
42 BBL/D
40% 39% 34% 32%
(B3/RDT-1P Ratio)
※ (Total Production of RDT-1P) × (Contribution Ratio of B3 by PLT) = B3 Production
B3
Perforation
A 3
B 2
B 3
C 1
C 2U
C 2L
D 1b
D 3
D 4
D 5U
D 5L

17. #1 : Barrier Case
#2 : No Barrier Case
2 Scenarios of Production Forecast
17
Perforated
Artificial barrier
B3
Simulation grid
B3
Simulation grid
Proposed perf.
B3 Up.

18. B3 Upper interval Selection
18
GWC@2869mTVDss
Proposed B3 Up
Proposed Perf. Interval
3921.03-3925.30 mMD
Dec 2015
Simulation Grid Fine Grid

19. B3 Production Recovery Review
19
RDT-1P Perforation
Zone
2021 Model
GIIP, Bcf
Top Perf.
mTVDSS/
mMD
Bottom perf.
mTVDSS/
mMD
Perf. Length,
mMD
RFDP Cumulative B3
production by
Simulation
(Bcf)
Cumulative B3
production by PLT
allocation
(Bcf)
Recovery
(%)
GWC,
mTVDss
B-3 41.46
(B3 Upper)
2837.29/
3921.03
(B3 Upper)
2839.81/
3925.30
4.27
2869 20.06 26.68 48.38 (Sim.)/ 64.35 (PLT)
(B3 Lower)
2848.02/
3939.80
(B3 Lower)
2852.56/
3947.80
8.0

20. RD/RDT Reservoir Model Update (2021)
20

21. RDT-1P History Matching
21
Gas Rate Cond. Rate BHP
Water Rate Water Cut THP

22. RDT-2P History Matching
22
Gas Rate Cond. Rate BHP
Water Rate Water Cut THP

23. Remaining Potential (B-3 Upper)
23
#1 : Barrier Case
B3
Artificial barrier
Simulation grid
Proposed perf.
B3 Up.
B-3 Gas Production Rate • No B-3 Upper perf
• With B-3 Upper perf
B-3 Condensate Production Rate
• No B-3 Upper perf
• With B-3 Upper perf
Av. 29.60 bbld increased
Production Forecasting
Av. 0.85 mmscfd increased
YEAR 2022 2023 2024 2025 2026 2027 2028 Total
Gas
(bcf/yr)
0.19 0.43 0.31 0.23 0.17 0.14 0.11 1.57
Condy
(mbbl/yr)
6.84 15.31 10.60 7.92 5.51 4.36 3.34 53.88

24. Remaining Potential (B-3 Upper)
24
#2 : No Barrier Case
Simulation grid
B3
Proposed perf.
B3 Up.
B-3 Gas Production Rate • No B-3 Upper perf
• With B-3 Upper perf
B-3 Condensate Production Rate
• No B-3 Upper perf
• With B-3 Upper perf
Av. 5.23 bbld increased
Production Forecasting
Av. 0.16 mmscfd increased
YEAR 2022 2023 2024 2025 2026 2027 2028 Total
Gas
(bcf/yr)
0.07 0.07 0.04 0.03 0.03 0.03 0.02 0.31
Condy
(mbbl/yr)
2.36 2.38 1.34 1.08 1.01 0.93 0.72 9.80

25. Simple Economics (Barrier Case)
25
• Cost
- During PLT work
- 79,689 $US (2017)
- No additional OPEX
• Pay back : 1 Month
• NCF : 7.64 $MM
B-3 Gas Production Rate • No B-3 Upper perf
• With B-3 Upper perf
B-3 Condensate Production Rate
• No B-3 Upper perf
• With B-3 Upper perf
Av. 29.60 bbld increased
Production Forecasting
Av. 0.85 mmscfd increased

26. Simple Economics (No Barrier Case)
26
B-3 Gas Production Rate • No B-3 Upper perf
• With B-3 Upper perf
B-3 Condensate Production Rate
• No B-3 Upper perf
• With B-3 Upper perf
Av. 5.23 bbld increased
Av. 0.16 mmscfd increased
• Cost
- During PLT work
- 79,689 $US (2017)
- No additional OPEX
• Pay back : 3 Months
• NCF : 1.34 $MM

27. RD/RDT RFPD-2012 Model Update
27

28. RDT-1P History Matching
28
Gas Rate
BHP
Water Rate
THP

29. RDT-2P History Matching
29
Gas Rate
BHP
Water Rate
THP

30. Remaining Potential (B-3 Upper)
30
#2 : No Barrier Case
Simulation grid
RFDP 2012
B3
Proposed perf.
B3 Up.
B-3 Gas Production Rate • No B-3 Upper perf
• With B-3 Upper perf
B-3 Condensate Production Rate
• No B-3 Upper perf
• With B-3 Upper perf
Av. 35.17 bbld increased
Production Forecasting
Av. 1.15 mmscfd increased
YEAR 2022 2023 2024 2025 2026 2027 2028 Total
Gas
(bcf/yr)
0.18 0.44 0.41 0.39 0.36 0.34 0.29 2.42
Condy
(mbbl/yr)
5.71 13.81 12.71 11.78 10.85 9.93 8.64 73.43

31. 2022 2023 2024 2025 2026 2027 2028 TOTAL
Gas (bcf/yr) 0.18 0.44 0.41 0.39 0.36 0.34 0.29 2.42
Cond (mbbl/yr) 5.71 13.81 12.71 11.78 10.85 9.93 8.64 73.43
Netback Gas
(80% applied, $/mcf)
2.25 2.30 2.34 2.39 2.44 2.48 2.53
Cond ($/bbl) 102.88 89.71 82.64 53.10 54.16 55.25 56.35
CAPEX ($MM) 0.16 - - - - - -
OPEX ($MM) - - - - - - -
Gas ($MM) 0.40 1.02 0.97 0.93 0.88 0.83 0.75 5.78
Cond ($MM) 0.59 1.24 1.05 0.63 0.59 0.55 0.49 5.13
Gas ($MM) 0.16 - - - - - - 0.16
Cond ($MM) - - - - - - - -
NCF $MM 0.83 2.25 2.02 1.55 1.47 1.38 1.23 10.75
Cash-Out
Year
Production
Unit Price
COST
Cash-In
Simple Economics (No Barrier Case)
31
• Cost
- During PLT work
- 79,689 $US (2017)
- No additional OPEX
• Pay back : 1 Months
• NCF : 10.75 $MM
B-3 Gas Production Rate • No B-3 Upper perf
• With B-3 Upper perf
B-3 Condensate Production Rate
• No B-3 Upper perf
• With B-3 Upper perf
Av. 35.17 bbld increased
Av. 1.15 mmscfd increased

32. Remaining Potential (B-3 Upper)
32
#1 : Barrier Case
B3
Artificial barrier
Simulation grid
RFDP 2012
Proposed perf.
B3 Up.
Production Forecasting
B-3 Gas Production Rate
• No B-3 Upper perf
• With B-3 Upper perf
B-3 Condensate Production Rate
• No B-3 Upper perf
• With B-3 Upper perf
Very minor effect
Very minor effect

33. 감사합니다

34. Rf) Process, Utility Diagram
34

35. B3 Upper interval Selection (RFDP2012)
35

36. RFPD-2012 Model Update (Barrier case in B3)
RDT wells History Matching Effect
36

37. RDT-1P History Matching
37
Gas Rate
BHP
Water Rate
THP

38. RDT-2P History Matching
38
Gas Rate
BHP
Water Rate
THP

39. 39
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
A3 (Mar 2015) 7,818.6 283.5 - 4,121.4
- - - 4,725.2 128.6 1,769.5 2,413.1 98.8 790.5 1,083.9 11.6 3,836.8 681.6 4.7 1,652.5 1,189.6 - 3,855.1 467.2 50.7 1,149.5
B2 (Mar 2016) 803.4 8.0 15.2 202.6 2.5 5.3 353.3 - 19.1 162.5 - 2.6
B3 (Mar 2015) 10,158.2 366.7 - 8,850.6 - - 9,199.6 173.8 96.2 6,983.5 170.9 41.8 2,194.7 14.1 98.7 2,058.2 6.6 75.1 2,083.4 - - 1,164.3 68.3 -
C1 (July 2009) 33,393.3 270 - 6,690.0 74.7 - 5,350.0 60.8 - 920.0 - - 1,121.0 18.2 - 14,470.8 391.1 67.6 8,877.5 233.0 57.7 5,799.1 204.9 - 4,566.1 - - 8,408.4 177.5 145.0 4,404.8 98.5 48.9 79.4 2.5 29.1 - - - 128.6 - - - - -
C2UP (May 2011) 4,250.0 74.7 - 3,370.0 60.8 - - - - 5,430.8 73.7 - 2,372.7 102.5 29.0 1,611.2 66.3 28.9 1,824.2 64.8 - 1,320.1 - - 1,026.9 19.5 240.1 358.7 10.5 118.4 2,313.7 11.6 294.3 2,227.4 7.2 259.9 2,809.9 34.0 1,216.7 2,064.5 - 510.0
C2BTM (May 2011) 31,760.0 485.0 - 29,640.0 394.7 - 28,130.0 515.5 - 12,829.0 190.9 3,354.6
D1 (Feb 2009) 888.7 12.4 1,306.0 1,400.0 367.1 - 1,590.0 93.2 - 780.0 74.6 - 94.6 - -
D3 (May 2007) - 0 - - - - - - - - - - 19.3 - -
D4 (May 2007) - 0 - 120.0 128.5 - 300.0 84.8 - 68.0 56.7 - 96.8 - -
D5 (May 2007) - 0 1,306.0
- 830.0 - 399.9 240.0 149.1 201.5 131.0 59.7 127.5 265.1 - 4.8
Total 34,282.0 282.4 - 45,050.0 1,130.0 399.9 40,490.0 843.4 201.5 30,029.0 706.5 127.5 19,856.6 282.8 3,359.4 16,843.6 493.6 96.5 10,488.7 299.3 86.7 25,600.0 919.8 - 10,615.3 - - 23,360.1 499.4 2,250.7 14,160.2 378.7 999.6 6,475.2 47.7 4,274.2 5,169.8 21.0 1,992.7 6,564.6 34.0 5,091.0 3,858.5 119.0 1,662.1
01 Dec 2015 (SLB)
Flowing#2: 10.3mmscfd
WSO Oct 2013
04-05 Mar 2017 (SLB)
Flowing#2: 5.16mmscfd
24 May 2018 (SLB)
Flowing#1: 6.56mmscfd
04-05 Mar 2017 (SLB)
Flowing#1: 6.46mmscfd
24 May 2018 (SLB)
Flowing#1: 3.85mmscfd
RDT-1P PLT
Zones
02 Feb 2011 (Halliburton)
Flowing#1: 36.17mmscfd
15 Jun 2012 (SLB)
Flowing#3: 29.86mmscfd
08-10 Mar 2013 (SLB)
Flowing#: mmscfd
11 Mar 2015 (SLB)
Flowing#2: 9.81mmscfd
01 Dec 2015 (SLB)
Flowing#1: 24.6mmscfd
23-24 Mar 2016 (SLB)
Flowing#1: 22mmscfd
15 Jun 2012 (SLB)
Flowing#1: 45mmscfd
15 Jun 2012 (SLB)
Flowing#2: 41.8mmscfd
11 Mar 2015 (SLB)
Flowing#1: 18.7mmscfd
23-24 Mar 2016 (SLB)
Flowing#2: 14.87mmscfd
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
Gas
[Mscfd]
Condy.
[STBD]
Water
[STBD]
A0 (Dec 2015) 47.5 - 2,944.6 0.1 - 4,636.0 135.4 - 4,744.5 Minor 1,544.8 Minor 931.7
A0.5 (Mar 2017)
A1 (Mar 2016) 5,437.4 37.9 22.3 5.3 59.0 38.7 7,642.8 158.8 48.9 1,006.1 732.4
A1.5 (Mar 2015) 1,537.3 - 574.0 111.8 - 212.7 0.1 - 531.3 157.3 - 565.8 483.3 388.0
A2 (Dec 2015) N/A - - - - - - - - - - -
A3 (Mar 2015) 2,413.9 - 289.2 - - 96.6 0.7 - 214.5 1,036.3 - 290.5 114.2 193.7
-
B1 (June 2012) 10,510.4 371.7 - 7.2 332.8 - 4.6 104.5 - 564.1 - 645.1 844.6 - 115.4 497.7 - 835.5
B3 (June 2012) 28,111.7 1,058.9 - 20.7 564.5 - 17.0 538.4 - 14,518.4 594.5 1,170.0 9,392.8 335.0 596.0 3,527.2 318.6 1,425.3
C1 (June 2012) 15,118.0 641.6 1,055.1 9.0 561.3 450.6 7.1 563.0 383.3
C2 (June 2012) 5.0 1.0 95.5 0.2 - 14.3 0.1 - 9.6
D1 (May 2011) 204.1 10.4 - 0.5 37.8 15.2 0.3 15.3 9.5
Total 53,949.2 2,083.6 1,150.6 37.6 1,496.4 480.1 29.1 1,221.2 402.4 15,082.5 594.5 1,815.1 10,237.3 335.0 711.3 7,976.1 318.6 3,124.0 5,596.7 37.9 3,276.2 6.3 59.0 5,420.5 8,971.8 158.8 5,649.8 - - 3,148.3 - - 1,858.3
WSO Mar 2016
07 Mar 2017 (SLB)
Flowing#2: 0.71mmscfd
WSO Oct 2013
07 Mar 2017 (SLB)
Flowing#2: 0.5mmscfd
RDT-2P PLT
04 Apr 2016 (SLB)
Flowing#1: 5.66mmscfd
04 Apr 2016 (SLB)
Flowing#2: 6.22mmscfd
04 Apr 2016 (SLB)
Flowing#3: 8.89mmscfd
Zone
12-15 Mar 2013 (SLB)
Flowing#2: 39mmscfd
12-15 Mar 2013 (SLB)
Flowing#3: 28.66mmscfd
04 Mar 2015 (SLB)
Flowing#1: 15mmscfd
04 Mar 2015 (SLB)
Flowing#2: 10.7mmscfd
12-15 Mar 2013 (SLB)
Flowing#1: 50.08mmscfd
01 Dec 2015 (SLB)
Flowing#: 7.944mmscfd