Progress and Outlook of Yanchang Integrated CCUS ... · 1 6 360,000 t/a CO 2 Capture Project in...
Transcript of Progress and Outlook of Yanchang Integrated CCUS ... · 1 6 360,000 t/a CO 2 Capture Project in...
Progress and Outlook of Yanchang Integrated CCUS
Demonstration Project
Shaanxi Yanchang Petroleum (Group) Co., Ltd,China
2018.6.27
Shaanxi Yanchang Petroleum (Group) Co., Ltd is one of four qualified enterprises for oil and gas exploration and production in
China, and also a large integrated energy chemical company aiming at the high–efficiency use of coal, oil and gas. In 2015,
Yanchang became No.380 of Fortune Globe top 500 companies.
Oil & Gas Production Oil Refining Oil & Gas Transportation
Oil & Chemicals Trading
Oil & Gas Exploration
Chemical Engineering Equipment Manufacturing
Engineering Construction Research Development
Coal Mining
Solar Photovoltaic Financial Service
Business of Yanchang Petroleum
Yanchang Petroluem
Part 1 Part 2 Part 3 Part 4
3
PROJECT BACKGROUD
Carbon Emission Reduction is a global Issue
In 2014, China released “China’s National Plan on Climate Change (2014-2020)” ,has pledged to
reduce carbon emission by 45% for per unit GDP
by 2020 from the 2005 level.
In 2015, China signed “U.S.-China Joint Presidential Statement on Climate Change”
In 2016, China signed the “Paris Agreement on Climate Change”
Part 1 Part 2 Part 3 Part 4
4
PROJECT BACKGROUD
CO2 “Near Zero Emission”in Coal Chemical Industry
Water Shortage during
Water Flooding
Development
Low Permeability
Oilfield Development
PROBLEMS
Yanchang Petroleum is the largest provincialstate-owned enterprises in north-west China. It’sour responsibility to fight against climate change.
Social Responsibility Development Need
Part 1 Part 2 Part 3 Part 4
5
Advantages
Abundant CO2 Source
Coal Chemical Industry
Good Geological Conditions for Safety Storage
Huge storage capacity in oil reservoir and saline aquifer
CO2-EOR and Storage
CO2-EOR
Source-Sink
Matching
Advantages of Yanchang CCUS Project
Low Cost, High Purity CO2
Part 1 Part 2 Part 3 Part 4
6
1、Abundant Carbon Dioxide Sources and Huge Storage Space in Ordos Basin
(1)Abundent CO2 Emission Source
More than 100 mtpa CO2 emission in Ordos Basin
(2)Storage Capacity
1.2 billion tonnes of oil reserve is suitable for CO2-EOR,
0.4 billion tonnes of CO2 can be safely sequestrated.
(3)Saline Aquifer
Huge Storage capacity in Saline Aquifer (>1 billion tonnes)
Advantages
Part 1 Part 2 Part 3 Part 4
7
2、Yanchang’s Unique Source-Sink Advantages
Oilfield DevelopmentOil & Gas Exploration
Coal Chemical PlantsCoal Mining
Advantages
陕北油区、煤化工、燃煤电厂分布图
Yanchang’s business is including multiple coal chemical plants and oil & gas fields,
which is unique source-sink conditions for CCUS project.t
Part 1 Part 2 Part 3 Part 4
8
1. Low Cost CO2 Capture Technology in Coal Chemical Industry
Project Highlights
CO2 Source: Coal Gasification Process
High Purity: CO2 = 99.6%
Low Capture Cost: <120 Yuan ($19)
Low Transportation Cost
Rectisol Process Location of CO2 Capture and Injection Sites
PROGRESS
T1621
E1621
V1621
P1621
T1601
T1603 T1604
T1605
E1605
E1623
E1622
V1601
E1601E1606
E1604
E1603 P-102
V1603
V1602
E1617C1601E108
非变换气
P1601 P1603/A/B
E1608
S1601
E1610
V1604
P1604
E1618
E1609
E1619
P1605
S1602
E1615A
E1615B
E1620
T1606
P1607
E1617
E1612
V1606
P1606
E1613
V1605
E1614
E1624
去膜分离
P-145
变换气
去甲醇
合成
E1621
非变换气冷却器
E1622
1#甲醇深冷气
V1621
2#水分离器
E1623
3#甲醇深冷气
E1624
4#甲醇深冷气
P1621
甲醇加压泵
E1601
变换气冷却器
T1621
非变换气洗涤塔
T1603
H2S浓缩塔
E1614
H2S馏分换热器
V1606
回流罐
P1606
甲醇深冷气再生回流泵
T1604
甲醇再生塔
E1612
再生塔回流深冷器
V1605
酸性气分离器
E1613
H2S深冷器
E1612
醇水分离器进料换热器
T1605
醇水分离塔
T1606
尾气吸收塔
E1617
醇水分离塔再沸器
V1601
1#水分离器
T1601
变换气洗涤塔
E1606
循环甲醇冷却器
E1603
1#甲醇冷却器
V1602
1#甲醇闪蒸罐
V1603
2#甲醇闪蒸罐
E108
循环气预热器
C1601
循环气压缩机
E1617
N2预冷换热器
E1608/A/B/C
3#贫甲醇冷却器
P1601/A/B
H2S浓缩塔甲醇泵
E1619
贫甲醇冷却器
P1603/A/B
甲醇再生塔给料泵
S1601
富甲醇过滤器
P1604/A/B
贫甲醇泵
P1605/A/B
醇水分离塔给料泵
S1602
富甲醇过滤器
P1607/A/B
尾气洗涤水泵
E1620
废水冷却器
E1618
贫甲醇冷却器
E1609
2#贫甲醇冷却器
V1604
贫甲醇储罐
E1604
1#甲醇深冷器
E1605
非变换气冷却器
去硫回收
脱盐水
碱液
去污水
补甲醇
去甲醇灌区
补甲醇
E1615/A/B
醇水分离器进料换热器
E1610/A/B/C/D
1#贫甲醇冷却器
E1607
P-1542
E-439
V1607
P-1545
P-1546
E1607
甲醇换热器
V1607
甲醇闪蒸罐
Part 1 Part 2 Part 3 Part 4
9
In November 2012, a 50,000 t/a CO2 capture facility has been built at Yulin Coal-chemical
Plant. 99.6% purity of CO2 is captured using a Rectisol process, then delivered to injection
sites for CO2-EOR and storage.
50,000 t/a CO2 Capture Project Operated by Yulin Coal Chemical Company
1. Low Cost CO2 Capture Technology in Coal Chemical Industry
PROGRESS
Part 1 Part 2 Part 3 Part 4
10
2. CO2-EOR Experiment Assessment
Establishing a CO2-EOR assessment system based on physical simulation experiment in formation
conditions.
Test:
Minimum Miscibility Pressure(MMP) Test
CO2-Oil Phase Behavior Test
Influence of CO2 Injection on Reservoir
Influence on CO2-EOR Efficiency
Channeling and Sealing system
Flowing gelatum Modified starch gelatum system Fracture sealing
PROGRESS
Part 1 Part 2 Part 3 Part 4
11
3. Injection-production Casing String Design and Anti-corrosion Technology
• Injection-production casing string design has been optimized,
• Anti-corrosion technology has been determined as “ordinary steel+ inhibiter”
Production systemInjection system
PROGRESS
Part 1 Part 2 Part 3 Part 4
12
No. ReservoirGeological Reserves
(104t)
Storage Capacity
(104t)
EOR
(%)
Incremental Oil 𝐏roduction
Tonnes of CO2
Storage
Coefficient
1 杏子川-化子坪区-长2层 1015 265.63 6.99 0.27 0.26
2 靖边-乔家洼-长6 (Jingbian) 931 209.87 4.03 0.18 0.23
3 永宁-永宁油区-长6 1333.69 357.41 10.83 0.40 0.27
4 西区-义吴-长4+5、长6、长7 4754.79 1207.39 9.85 0.39 0.25
5 定边--延10 424 145.83 10.83 0.31 0.34
6 七里村-郭旗西区-长61、62 3110 769.90 8.67 0.35 0.25
7 直罗-埝沟-长2 240 62.42 7.43 0.29 0.26
8 南区-湫沿山-长6 278.6 62.80 10.52 0.47 0.23
9 吴起-油沟-长4、长5(Wuqi) 801 194.25 8.58 0.58 0.56
A new CO2 geological Storage Capacity Assessment System has been established in consideration of interaction between CO2-EOR and Storage. The result shows the effective CO2 storage capacity could be 0.4 billion tonnes in Yanchang oilfield.
4. CO2 geological Storage Capacity Assessment System
PROGRESS
Part 1 Part 2 Part 3 Part 4
13
5. “Underground—Surface—Atmosphere” CO2 Storage Monitoring System
3D-Seismic Monitoring Vegetation Physiological & Biochemical Analysis
Sample Analysis
PROGRESS
Casing string Monitoring Soil Gas Monitoring Online Monitoring System
Part 1 Part 2 Part 3 Part 4
14
6. CO2-EOR and Storage Pilot Test
Since September 2012, the total amount of CO2 injection is 87,300 tons.
1、Jingbian CCS Pilot Site
Liquid Production/well: 0.53m3/d — 1.05m3/d
Oil Production/well: 0.17 t/d — 0.33 t/d
Water-cut: 64%
PROGRESS
Pay-zone Depth:1300m-1600m
Injection Pressure: 8.3Mpa
Reservoir Temperature:44℃
Part 1 Part 2 Part 3 Part 4
15
6. CO2-EOR and Storage Pilot Test
Since September 2014, the total amount of CO2 injection is 380,000 tons.
2、Wuqi CCS Pilot Site
PROGRESS
Liquid Production/well: 2.88m3/d — 3.07m3/d
Oil Producton/well: 1.91 t/d — 2.23 t/d
Water-cut decrease: 6.5%
Pay-zone Depth:2000m
Injection Pressure: 9.5Mpa
Reservoir Temperature:60℃
Part 1 Part 2 Part 3 Part 4
16
360,000 t/a CO2 Capture Project in Yulin Energy and Chemical Company
The feasibility study of 360,000 t/a CCUS Demonstration Project has been
approved, the project is now in the construction scheme design phase.
7. Yanchang 360,000 t/a Integrated CCUS Demonstration Project
PROGRESS
Part 1 Part 2 Part 3 Part 4
17
FUTURE PLAN
Phase 1:36万吨/年CCUS示范工程。 360k tons/year CCUS project.
Phase 2:100万吨/年CCUS工业化应用。1 million tons/year CCUS project.
Phase 3:400万吨/年CCUS推广应用。 4 million tons/year CCUS project.
Pipeline(Phase 1)
CO2 Capture Site
CO2 Injection Site(Phase 2)
Pipeline(Phase 1)
CO2 Injection Site(Phase 1)
CO2 Injection Site(Phase 3)
Pipeline(Phase 3)
Well Testing in Yanchang oilfieldWuqi reservoir
Date: 27st June 2018
Vahab Honari
AcknowledgementsProfessor Andrew Garnett; Professor Jim Underschultz; Professor Xingjin Wang
For their contribution and support, UQ would like to acknowledge:
Commonwealth Government of Australia;
ACA Low Emissions Technology Pty Ltd (ACALET).
Disclosure
The UQ-Surat Deep Aquifer Appraisal Project (UQ-SDAAP) is forecasted to run until end April 2019 within total current budget limit of up to AUD$8.1 million. The project is currently funded by the Australian Government, through the CCS RD&D programme, by ACA Low Emissions Technology (ACALET) and by The University of Queensland.
Disclaimer
The information, opinions and views expressed here do not necessarily represent those of The University of Queensland, the Australian Government or ACALET. Researchers within or working with the UQ-SDAAP are bound by the same policies and procedures as other researchers within The University of Queensland, which are designed to ensure the integrity of research. The Australian Code for the Responsible Conduct of Research outlines expectations and responsibilities of researchers to further ensure independent and rigorous investigations.
Research Collaborators:China University of Mining Technology Beijing, Yanchang Petroleum Company,
Thanks also to APLNG, Bridgeport Energy, Shell/QGC and Armour Energy for provision of proprietary data and models for the wider Surat Deep Aquifer Appraisal Project.
Acknowledgements to Schlumberger, Computer Modelling Group and IHS Markit for provision of modelling software
Yanchang oilfield map
Location of CO2 Capture and Injection Sites
CO2 geological Storage Capacity Assessment System
No. ReservoirGeological Reserves
(104t)
Storage Capacity
(104t)
EOR
(%)
Incremental Oil 𝐏roduction
Tonnes of CO2
Storage
Coefficient
1 杏子川-化子坪区-长2层 1015 265.63 6.99 0.27 0.26
2 靖边-乔家洼-长6 (Jingbian) 931 209.87 4.03 0.18 0.23
3 永宁-永宁油区-长6 1333.69 357.41 10.83 0.40 0.27
4 西区-义吴-长4+5、长6、长7 4754.79 1207.39 9.85 0.39 0.25
5 定边--延10 424 145.83 10.83 0.31 0.34
6 七里村-郭旗西区-长61、62 3110 769.90 8.67 0.35 0.25
7 直罗-埝沟-长2 240 62.42 7.43 0.29 0.26
8 南区-湫沿山-长6 278.6 62.80 10.52 0.47 0.23
9 吴起-油沟-长4、长5(Wuqi) 801 194.25 8.58 0.58 0.56
Wuqi CCUS Pilot Site
Since September 2014, the total amount of CO2 injection is 380,000 tons.
Liquid Production/well: 2.88m3/d — 3.07m3/d
Oil Production/well: 1.91 t/d — 2.23 t/d
Water-cut decrease: 6.5%
Pay-zone Depth:2000m
Injection Pressure: 9.5MPa
Reservoir Temperature:60℃
Project objectives
• Design and implement a long pumping test in Wuqi reservoir (tight reservoir with average permeability of 2mD).
• Achieve a relatively large radius of investigation.
• Quantify any existing heterogeneity/fracture in the reservoir.
• Use dynamic reservoir pressure response acquired from this test to de-risk the prediction of carbon storage capacity and injectivity.
Static and History matched dynamic model• Wireline logs were interpreted and grid properties
were upscaled/distributed across the model.
• Experimental data for Wuqi fluid and rock properties were incorporated into the model.
• 4 water injection wells (blue stars) were in theselected area of interest for this study.
• The monthly historical water injection rates wereused in conjunction with history production ratesto calibrate the sub-sector model.
Interference test design trial using two monitoring wells• Well 106 (blue star) was considered as injection well and
101 (located 270 m apart from 106) and 103 (located 325 m apart from 106) (green stars) as the monitoring wells.
• Only well 101, 103 and 106 were shut-in in the model during the test.
• The initial shut-in period of at least 60 days (for base case K=2mD) would be essential to acquire interpretable data at the observation well.
• This needs to follow up with 120 days of injection and 30 days of FO.
• The flow rate needed to be 7 m3/day (44 bblday).
2000m
60 days Initial shut-in relaxation (101 and 103), 120 days INJ at rate of 44 STB/day (7m3/day) and 30 days FO (210 days total)
Initial shut-in period Injection period
Fall
Off
pe
rio
d
Pressure response in injection (106) and two monitoring (101 and 103) wells modelled in Petrel RE
Interpretation of FO pressure response at injection well (106) using IHS WellTest software
• The ROI at injecting well was about 140 m. This is just at the outer edge of water flooded zone. Calculated permeability at the injection well was 0.29 mD.
Chaudhry (2004)
Bourdet (2002)
Flooded zone
Partially flooded
zone
Non-flooded
zone
Fiss
ure
d
syst
em
Tran
siti
on
The INJ data at observation well was matched with the type-curve, resulting in K=0.45 mD and 0.51 mD at well 101 and 103, respectively.
60 days Initial shut-in relaxation (101 and 103), 120 days INJ at rate of 44 STB/day (7m3/day) and 30days FO (210 days total)
Monitoring well 101 Monitoring well 103
Interpretation of INJ pressure response at observation wells (101 and 103) using type-curve matching described by Earlougher (1977).
CO
2In
ject
ion
pe
rio
d
CO
2Fa
ll O
ff p
eri
od
All interference test sequences
60 days Initial shut-in relaxation (101 and 103), 120 days INJ at rate of 44 STB/day (7m3/day) and 30days FO (210 days total) followed by 60 days of CO2 injection (4000 sm3/day) and 90 days of shutin(BHP<=200bar)
CO2 front
Water front
Pressure response in injection (106) and two monitoring (101 and 103) wells modelled in Petrel RE
Interpretation of FO pressure response at injection well (106) using IHS WellTest software
The log-log plot derived from the CO2 injection into the water flooded oil reservoir would potentially predict the gas front and water front as well as the formation (relative) permeability change when CO2 is introduced to the reservoir.
Summary• This is a low permeability reservoir. Thus, any new disturbance to the reservoir
system causes long lasting effects that make the data collection/interpretation challenging.
• The interference test with two monitoring wells sequence with a follow-up CO2
injection test is the most favourable, achieving the test objectives of establishing the reservoir characteristics and constraining dynamic CO2 storage capacity within a reasonable testing time.
• The largest current uncertainty remains to be the bulk reservoir permeability.
• Based on assumptions about permeability the best test options are:Phase 1 Interference test: “A” days initial shut-in relaxation at the monitoring (101 and 103) wells, “B” days INJ at the injection (106) well at rate of 44 STB/day and “C” days FO;
Phase 2 The INJ-FO test will be followed by CO2 INJ and FO with the period of “D” and “E”, respectively.
• Note*: As the test is being run and real time P/T readout is observed, we will be able to determine which permeability scenario is most likely and make decisions on test segment duration accordingly.
Summary (2)
Average permeability (mD) Initial shutin time (day) Injection period (day) Fall off period (day) CO2 injection (day) CO2 falloff period (day) Total testing period (day)
2 60 120 30 60 90 360
5 15 60 30 60 90 255
10 15 30 30 60 90 225
A B C D E F
Thank you