EOR (feasibility to execution)

EOR (Enhance Oil Recovery): Feasibility-Implementation-Evaluation

Production Geologist (Development Geologist)

Practical use and Reference

EOR ACTIVITY Feasibility Study

Screening of EOR Method

Laboratory Study

Review and Update GGRPFE/GGRP

Process facility study

Full Scale Economic Evaluation

Feasibility Study Result

Implementation Trial/ Pilot EOR

Implementation Trial/ Pilot EOR Proposal

Preparation Trial/ Pilot EOR

Execution Trial/ Pilot EOR

Data gathering, Monitoring & Surveillance

Evaluation Trial/ Pilot EOR

Production gain method

Operation technical method

Reporting of Implementation Trial/ Pilot EOR

Feasibility Study

The purposes of EOR (Enhance Oil Recovery) Feasibility Study is tounderstand fully of the fields in the first place, whether the fieldseconomic/ feasible to be developed by EOR method implementation.

The feasibility study consist of screening of EOR method, LaboratoryStudy, Review and Update GGRPFE, Process facility study, then FullScale Economic Evaluation. If categorized feasible, then need to betested by field trial / pilot about 1-2 pattern

Screening of EOR (Enhance Oil Recovery) Method should conduct eachlayer / zone due to may have different reservoir characteristic.Reservoir parameters are necessary for EOR Screening , consist of:

1. Oil API gravity

2. Oil viscosity

3. Rocks Porosity

4. Oil Saturation

5. Lithology

6. Permeability

7. Reservoir Depth & temperature

8. Hydrocarbon composition etc.



There are 16 type of EOR (Enhance Oil Recovery) method (Aladasanifrn.2010) such: Miscible CO2, Miscible Hydrocarbon, Miscible WAG,Miscible Nitrogen, immiscible Nitrogen, immiscible CO2, immiscibleHydrocarbon, immiscible Hydrocarbon + WAG, Polymer, Alkaline-Surfactan-polymer (ASP), Surfactant +P/A, Combustion, Hot water,Steam, Surface mining, microbial.

Laboratory test consist of fluids characteristic, native core/ Rocks, and media EOR as follows:

1. Rocks / native core; routine core & SCAL, Porosity and permeability, SEM, XRD, Rocks chemical analysis, rocks wettability.

2. Water Formation and injection test: pH, salinity, density, viscosity, complete water analysis, bacterial, scaling tendency

3. Oil characteristic: density, viscosity, melting point, acid number, composition, oil type

4. Chemical test: ASP if necessary add cosurfactan & solvent where each can mixed/ formulated as flow diagram (next Slide).

Laboratory Study

Flow Diagram

Formulated/ Selection

of surfactant

If all surfactant parametersfulfilled , then may conductanother test adjusted as coreflood simulation test. Need toconsider synthetic core whethernative core very limited.

Sometime surfactant liquid needto take compatibility test,behavior phase test, IFT stabilitytest, Filtration test, andadsorption test.

Polymer test

Polymer evaluation purposes is toget polymer material that mayimprove water viscosity inreservoir, therefore mobility oil-water ratio smaller than 1 (one).

See The flow diagram of polymerstudy

Gas / solvent

(miscible and

immiscible) test

The parameters are as follows:

1. PVT analysis, current reservoir pressure; (hydrocarbon composition analysis, constant composition expansion, Differential liberation, separator test, asphaltic content)

2. Solvent-crude oil properties (viscosity, density)

3. Slim tube test for define MMP (minimum Miscible Pressure)

4. Swelling and extraction test

5. Coreflood.

Thermal media

testThermal method use heat energy as themedia, with assume that increasing thetemperature made oil viscosity goes down inreservoir, the media may steam, hot water,etc. The parameters are as follows:

1. PVT analysis, current reservoirpressure; (hydrocarbon compositionanalysis, constant compositionexpansion, Differential liberation,separator test)

2. Viscosity and density of fluid andthermal media

3. Rocks structure break @ temp.

4. Oil swelling due to thermal expansion

5. Heat capacity from rocks and reservoirfluid

6. Bottom water

7. Loss heat/ thermal

8. Coreflood (recovery test)

Another media

testAnother media method such MEOR (Microbialenhance oil recovery), its amount of microbe inreservoir where the population improved bygiving enough nutrition in reservoir condition.Microbe activity to be expected give surfactanteffect and also break HC chain and decrease theoil viscosity. The parameters are as follows:

1. Define the amount and microbe type

2. Selection/ formulation of nutrition toimprove the acceleration of microbegrowth @ (time function, nutritionconcentrate and reservoir temp.)

3. Filtration test @ microbe and nutritionconcentrate

4. Viscosity test and reservoir density fluid @incubation time

5. IFT test @ reservoir temp.

6. Imbibition as time function

Review and Update

GGRPFE

Review and Update GGRPFEThe main purposes of reservoir simulation are to make oilproduction forecast in field scale using chosen EORmethod and input data of laboratory test also updateG&G model. Then evaluate the necessity of productionand injection facility also the economic as the finalfeasibility study. If the field feasible, the continue to fieldtrial / pilot.

The field trial / pilot is better use pattern that has goodconnectivity between injection and production wells,good oil saturation, area pattern about 4-5 acre with 4-5spot, and distance injection-production wells max 100mas for surveillance will be fast.

Input data for EOR reservoir simulation consist of:

Static 3D model reservoir geology model (Porositydistribution, facies distribution, permeabilitydistribution)

Dynamic reservoir data (SCAL, PVT {Pb, Bob, Gassolution, Specific gas}, and Production data withpressure)

Laboratory study as EOR type e.g. ASP

Legend:

Injector

Producer

Monitor

confining

Injection facility studyMaking sure the water fulfill criteria and compatible with reservoir thereforeneed treatments. It has to through filtering, free oil & plug from microbe, watersoftener, neutral pH. The water composition must adjusted with conditionfrom laboratory test therefore the chemical has property as formulated.

Injection facility that necessary for each EOR method can be explain as follows:

1. Chemical method (ASP), the facility consist of: Tank(for chemical), mixer tank (main solvent), mixer tank ( for solvent as formulated lab.), filter, storage tank/ surge tank, transfer pump & pipe between equipment, injection pump to the well.

2. Gas/ solvent method, the facility consist of: separator (for absorption, distillation, gas dryer etc.), Surge tank, pipe for surface facility to well head and compressors (transfer & injection.)

3. Thermal method, the facility consist of: heat exchanger and boiler, water treatment, pipe (with insulation for steam transport), and pump.

4. Microbe method, the facility consist of: mixer tank (nutrition), Pipe and transfer pump. Injection pump.

Production Facility study

Production test in Collector station, should separate

with existing facility therefore the measurement will

more accurate and the handling will be easier

particularly with emulsion.

Economic evaluation comprises: ROI (Return on

investment), NPV (Net present value), and IRR

(Internal rate of return) as company standard.

Economic sensitivity need to be done for giving the

success criteria picture of field trial/ pilot. If the

evaluation result assume gain profit, then it can

recommend for field trial/pilot implementation.

Full Scale Economic Evaluation

Feasibility study result that can be used as guidance field trial/

pilot implementation consist of:

1. Quantity and quality water injection data and water

process that needed as field necessity

2. Quantity, quality, and operation condition EOR media that

needed (such chemical material: IFT, FR, concentration

etc.)

3. The best Pattern location include area and pattern type

that recommended

4. Surface facility that needed

5. Oil and gas reserves on pilot scale and full field scale

6. Forecast production for pilot scale

Feasibility Study Result

Implementation Trial/ Pilot EOR

Implementation Trial/ Pilot EOR is proving or confirmation step

from feasibility study. According to the result of EOR feasibility

study, the party have to prepare work plan and budget also

activity step that necessary as regulator guidance, and then

after get approval from any related parties the Implementation

Trial/ Pilot EOR need to be prepared (Subsurface, surface and

procurement to monitoring & surveillance).

The next Implementation Trial/ Pilot EOR step is Execution,

consist of: EPCI and production wells, injector, also monitoring

as necessary. Mitigation risk also needed for avoid any

unwanted disturbance or other factor may delay the

Implementation Trial/ Pilot EOR project.

The proposal usually consist of:

1. Candidate Trial/ Pilot EOR area process selection

2. Reservoir performance (Primary and secondary recovery)

3. Screening process EOR method

4. Uncertainty factor and GGRP model

5. Additional gain reserve forecast and production profile full field

6. Full field EOR economic

7. Existing operational condition (facility, wells etc.)

8. Simulation pattern design for pilot and full field EOR

9. Trial/ Pilot EOR plan (Purposes, pattern type , wells & facility Trial/ Pilot EOR necessity, injectant EOR defined, parameter EOR, baseline, monitoring success criteria, schedule, budget etc.)

10. Project schedule for full scale EOR usually in POD or POFD

Implementation Trial/ Pilot EOR Proposal

The Preparation Trial/ Pilot EOR usually consist of:

1. Team executor (total support from top management, operational decision making, independent in handling area trial/ pilot, dedicated and experienced etc.)

2. Budgeting (allocation particular budget for Trial/ Pilot EOR obvious)

3. Procurements of EOR bulk material (volume nd specification, estimation budget)

4. Surface facility (FEED{Front end engineering design} for Trial/ Pilot EOR, EPCI (Engineering Procurement Installation) phase

5. Make sure laboratory Available for monitoring & surveillance

Preparation Trial/ Pilot EOR

Execution Trial/ Pilot EOR comprises Monitoring & surveillance program andQuality assurance QA / Quality control QC. And the Monitoring & surveillanceprogram consist of:

1. Monitoring production wells (Daily-production test Gross/net, WC.Weekly-WHP{well head pressure}, Dynamic fluid level, sonolog/dynagraph. Monthly-SBHP{static bottom hole pressure})

2. Monitoring Injection well (daily-rate injection, injectant concentration,BHP. Weekly- WHP. Oxygen activate logging min twice in Pilot. Fall off testas necessary)

3. Monitoring EOR Plant (chemical/ Polymer/ Miscible and immiscible gasetc.)

4. Surveillance program (tracer test, pulse test, pressure build up, and skinfactor min twice in Pilot time. Pattern balancing, fluid drift, patternrealignment for gaining comprehensive data in building confident levelfrom field trial/ pilot result)



Quality assurance QA / Quality control QC depends on Injectant such:

1. Chemical: chemical material must calculate bulk volume asrequested, then sampling with randomly, after that conductlaboratory test to know the quality as specification, and finallyput in the right place.

2. Polymer: Same as chemical step

3. Miscible and immiscible gas (solvent): Same as chemical step butusually put in compressor

4. Thermal: Same as chemical step but different supportingequipment

5. Another (microbe): Same as chemical step

Data gathering, Monitoring & Surveillance consist of:

1. Performance of mixing plant, WTP, and WIP as target

2. Quality from EOR parameter (SI, IFT, pH etc.)

3. Analyze Injection Well performance, such: Hall-Plot analysis

4. Process improvement from monitor Area(Production wells Injections and Surface facility) from evaluation result.

5. Plotting daily actual oil production to simulation result.

Data gathering, Monitoring & Surveillance


The success evaluation field trial/ pilot EOR is based on two method they are Production gain method & Operation technical method. The Production gain method conducted with plotting production realization as long as field trial/ pilot using daily basis and compare it with forecast field trial/ pilot that from simulation result. Success criteria in Production gain method based on economic sensitivity from feasibility study.

The Operation technical method conducted by using the scoring on influenced parameters.


The parameters success criteria of Operation technical method consist of:

1. Health, safety, security, & environment (HSSE)

2. Fluid handling & facilities performance

3. Monitoring & surveillance reliability

4. Production performance

5. Injectan performance

6. Operation reliability

7. Design matching (Laboratory, Reservoir simulation-forecast production, and production facilities)

Reporting of Implementation

Trial/ Pilot EORThe reporting of Implementation Trial/ Pilot EOR containing the documentation thatdescribe the process, performance results, prediction and actual comparison,recommendations and conclusions from all Implementation Trial/ Pilot EOR events. Thedocument comprises:

1. Summary data (Trial/ Pilot EOR Material, budget)

2. Recovery factor (Oil saturation before and after flooding such: coring, RST, CHFR, tracer test)

3. Production performance (Production profile Forecast vs actual, Rate production)

4. Injection Performance (Rate Injection, Pressure performance, Volume)

5. Operation Performance (Mixing, QA/QC, Injection, Production, Laboratory test)

6. Pressure Performance (Pressure distribution, anomaly, down time)

7. Update/ Fixing chance (EOR quality material, Slug design, operation improvement, Facility design, well design, pattern design, etc.)

8. Success evaluation

9. Recommendation and future plan (full scale economic based on implementation Trial/ Pilot EOR with comparing sensitivity on feasibility study result, justification for full scale EOR)

Screening EOR Method with nitrogen and flue gas

Injection (according to Taber and friends - 1997)

Screening EOR Method with miscible hydrocarbon

injection (according to Taber and friends - 1997)

Screening EOR Method with CO2 Injection (according

to Taber and friends - 1997)

Screening EOR Method with Polymer, ASP Injection

(according to Taber and friends - 1997)

Screening EOR Method with Polymer Injection


Screening EOR Method with Insitu combustion

Injection (according to Taber and friends - 1997)

Screening EOR Method with Steam Injection


Screening EOR

Method (according to

Aladasani and friends -

2010)

area of zone ：420.6 sq km oil-bearing area ：3.8 sq km

geological reserves ： million barrels The oil gravity ：35-50°API

geological stratification; 14 small layers reservoir thickness ：1-12m

reservoir depth：30-460m the average pressure coefficient ：0.49 the

average porosity ：0.29 the average permeability ：122.7md

OMG regional geological characteristics

CASE: OMG Field in SE Asia

Because OMG oilfield rely on natural depletion long-term, recovery

degree is 20.65%, at present the Formation energy shortfall is serious, the

energy yield is low, it is necessary to combine the factors such as structure,

sandstone development condition, drilling horizon of the wells, the

condition of oil well output and so on to optimize well group in water

injection site testing to analyze the feasibility of waterflooding, which can

provide the basis for the field of large-scale water flooding adjustment

Test area selection and structural characteristics


Test area selection is mainly based on the following principles:

① located in the oil production center, closer to the terminal, convenient

for management, and convenient for tracking the effect;

② there is no floor production equipment on well site and it is

advantageous for the construction;

③ the connecting condition with oil well is relatively good;

④ has the water injection conditions;

⑤. Consider the utilization condition of 3 Wells which were drilled in 2016;

⑥. Select OM-1, OM-3, OM-5 layer to inject.


SB1 Qoi 50.3 bopd (?/?/???)

PU: 64bfpd/1.3 bopd/98%WC(Sep’1991)

Cum. 10.5MBO (Des’87-Sep’91)

STC Qoi 32.6 bopd (Okt’91) & 7.25 bopd (Jul’2005)

PU: 13bfpd/2.7bopd/79.5%WC(Jan’2010)

Cum. 37.6MBO (Des’87-Jan’2010)

TD =173m

TOC 131.5m

SB2 (OH) Qoi 38 bopd (Jul’1908)

Cum. 10.5MBO (Des’87-Sep’91)

STC Qoi 4.4bopd (Nov’1903)

PU: 2bfpd/1.7bopd/85%WC(Okt’2011)

Cum. 22.6MBO (Des’87-Okt’2011)

TD =236.5 m

OMG-107KB =93.2m

SqueezePropose

dOpen

Injection

OMG-104KB=73.1m 144m

OMG-158AKB =82.8m180m

STC Qoi 17.48bopd (Nov’1991)

PU: 11.8bfpd/1.1bopd/90.4%WC(Jul’2011)

Cum. 40.7MBO (Des’87-Des’2011)

TD =128 m


Injection - Production history, Oil reserve at Area Pilot & Forecast

Production Pilot

Distribution of injection wells

Injection - Production history

OMG-107

Oil reserve at Area Pilot

Forecast Production Pilot


Design basis: the reservoir engineering design of improving oil recovery

by water flooding in KM oilfield

Design principle: on the basis of reservoir engineering plan, combine

with the reservoir characteristics and oil field technological conditions,

chose the economic and practical production technology to ensure the

requirements of reservoir development; Pay attention to the whole

process of reservoir protection, environment protection and

construction safety during the oilfield development; Chose a complete

set of mature production technology in order to reduce investment and

operation cost and optimize machine mining equipment.

Production engineering

design


Injection process design

1. Water injection design Based on reservoir engineering design requirements, OMG107 Well injection

allocation 400 BBL/day, OMG 606 well injection allocation 600 BBL/day.

2. Water injection string design

Tubing: 2 7/8 "EUE tubing;General injection string: 2 7/8 "EUE tubing + bell guide;

Separate injection string: eccentric injection mandrel and constant pressure valve.

3. Wellhead selection

Design water injection wellhead pressure 10 MPa, and have test, blowout, wash well,

and other functions.

Lifting scheme design process

1. Lifting way choice

Choose lifting way follows the principle: the election rise way can ensure the

development plan forecast capacity index, at the same time consider lifting way of

reliability, economy.

At present more mature lifting method for pumping unit, and its advantages for fluid

volume adaptation range, and large scope, matching technology is mature, workers

skilled operation. Therefore determination by way of pumping unit lifting.


2. Pumping unit, sucker rod, pump

(1) Determine the pump depth

Under the pump depth is determined according to the single well perforation, and

ensure reasonable flowing pressure. This plan according to the geological

requirements, depth of pump depth more than 20 m in the reservoir.

(2) Pump diameter

According to the geological forecast production, at 25% of the pump efficiency

calculation, considering water cut rising problem in the process of mining, selected

pump should be set aside room for maneuver. Choose pump is 50.8 mm in diameter.

(3) Sucker rod design

Oil well pump under different depth, stroke, Circulation per minute, pump diameter,

on the basis of equal strength principle, the use of software for dynamic simulation,

the calculation of the various parameters.

Selects the c-class 19 mm rod can meet the requirements.

(4) Lifting way model and power distribution equipment selection

Lifting mode choice models:

Underground pumping unit model mainly depends on the rod string and liquid

column load. When put into production early design utilization is 65% ~ 95%, can

press load torque utilization is 55% ~ 90% range to choose pumping unit.


Pumping

unit model

stroke Pump

diameter

Circulation

per minute

theoretical

displacement

pump efficiency

of 25% forecast output

(m) (mm) (1/min) （bbl/d）（bbl/d）

25-67-36 0.914

50.8

12 201.3 50.3

10 167.7 41.9

9 150.9 37.7

38.1

12 113.2 28.3

10 94.3 23.6

9 84.9 21.2

40-76-48 1.21

50.8

12 266.4 66.6

10 222 55.5

9 199.8 50.0

38.1

12 149.9 37.5

10 124.9 31.2

9 112.4 28.1

Estimation pump drainage quantity under 25% the pump efficiency CASE: OMG Field in SE Asia

Pumping unit modelrated torque

(KN.m)

rated load

(KN)

Max stroke

(m)

25-67-36 2.82 29.8 0.914

40-76-48 4.52 33.78 1.21

57-76-54 6.44 33.78 1.37

On the basis of pump diameter 50.8 mm，sucker rod 19 mm, 12 times/min calculation

pumping parameters calculation

Pumping

unit model

stroke Depth of

the pump

Calculating

the torque

Torque

utilization

Calculation of

maximum load

Utilization

rate of loadThe motor

(m) （m） (KN.m) (%) (KN) (%) (kw) (HP)

25-67-36 0.914 370 2.26 80.1 15.7 52.7 4.7 6.31

40-76-48 1.21 430 3.61 79.9 18.7 55.4 7.6 10.08

57-76-54 1.37 540 5.17 80.3 23.8 70.5 10.8 14.44

current model under the maximum depth of the pump


The choice of motor:

Motor selection to meet the installed power and under the premise of

stable operation, convenient for later production management.

(5) Wellhead design

Meet the admissions materials, pressure, casing connections, tubing

suspended load, operation convenient.

3. the tubing design

On the basis of joint connection strength, collapsing strength and internal

pressure strength requirement. Choose 2 7/8 "N80 EUE tubing.


NO. NAME Specification Unit Quantity

1 Pumping unit 40-76-48 set 7

2 Pumping unit 25-67-36 set 3

3 Electric motor 20HP set 7

4 Electric motor 10HP set 3

5 Christmas tree oil well set 10

6 Christmas tree injection well set 2

7 POLISHED ROD 1 1/8", 22 FT joint 10

8 Polished rod clamps 1 1/8" unit 10

9 POLISHED ROD coupling 1 1/8"-3/4" unit 10

10 SUCKER ROD 3/4"X 25 ft GRADE D CW, SR COUPLING m 2970

11 PONY ROD 3/4"X 4 FT, CW, SR COUPLING joint 20

12 PONY ROD 3/4"X 6 FT, CW, SR COUPLING joint 10

13 Sucker rod centralizer FGKC19-58WR unit 70

14 Oil pump RWMA 25×200×12ft set 10

15 Tubing 2 7/8 ", J55, 6.5 PPF, EU, R2 m 3680

16 Pup Joint of Tubing 2 7/8", 2ft joint 2

17 Pup Joint of Tubing 2 7/8", 6ft joint 1

18 Screen SG-1.5 joint 10

19 Plug 2 7/8"EU unit 10

The material list for petroleum engineering


Check

valve flow

gauge

gate

valve

gate

valve

flow

gauge

gate

valve

gate

valve

gate

valve

packer

air release

valve

wellheadair release valve

Ground seat union

Ground seat union

Connect to

tubing

Connect to

casing

oil layer oil layer

oil layer oil layer


Design basis: the reservoir and production engineering design of improving oil

recovery by water flooding in KM oilfield.

Design principles: strictly carrying out the relevant national laws, regulations and

the relevant national and industry standards and norms; To protect environment,

reduce pollution, oil, gas, water gathering and processing should satisfy the

standard of environmental protection, do not discharge oil, waste gas, waste water.

The ground engineering design

Oil gathering system

The production Wells located in OMG station, new production fluid on mechanical

production Wells are relying on the existing station remaining capable of handling.

According to the situation of oil collecting system has been built, this project adopts

the concentrated tank, multiwell concatenated set oil, oil transfer pump transmission

oil gathering process regularly. Total construction 10 wells, new oil pipes 1.48 km, 2

tank and 1 pump (Q = 120 BBL/h, h = 160 m; P = 40 HP)


Full Scale EOR Waterflooding

KM-001

KM-002KM-003

KM-004

KM-005AKM-005B

KM-006

KM-007

KM-008

KM-009

KM-010

KM-011

KM-012KM-013KM-014

KM-015

KM-016

KM-017

KM-018

KM-019

KM-020

KM-021

KM-022

KM-022/55J

KM-023

KM-023/38

KM-023/96

KM-024

KM-024/77

KM-025

KM-025/17J

KM-025/1E

KM-026

KM-027KM-028

KM-029

KM-030

KM-031

KM-032

KM-033

KM-034

KM-035

KM-036KM-037

KM-038

KM-039

KM-040

KM-041

KM-042

KM-043

KM-044

KM-045

KM-046

KM-047

KM-048

KM-049

KM-050

KM-051

KM-052

KM-053

KM-054

KM-055

KM-056

KM-057

KM-058

KM-059

KM-060

KM-061

KM-062

KM-063

KM-065KM-066

KM-067

KM-068KM-069

KM-070

KM-071

KM-072

KM-073AKM-073B

KM-074

KM-075

KM-076

KM-077

KM-078

KM-079

KM-080

KM-081

KM-082

KM-083

KM-084

KM-085

KM-086

KM-087

KM-088KM-089

KM-090

KM-091

KM-092

KM-092A

KM-093

KM-094

KM-095

KM-096

KM-097

KM-098

KM-099

KM-100KM-100A

KM-101

KM-102

KM-104

KM-105

KM-106

KM-107

KM-108KM-109KM-110

KM-111

KM-112

KM-113

KM-114

KM-115KM-116

KM-116A

KM-117

KM-118

KM-118A

KM-119

KM-126

KM-127

KM-128

KM-129

KM-134

KM-135

KM-136

KM-137

KM-138

KM-139

KM-148

KM-149

KM-150

KM-156

KM-157

KM-158

KM-158A

KM-159

KM-161KM-162

KM-163

KM-171

KM-172

KM-173

KM-174

KM-174A

KM-175

KM-176

KM-177

KM-178

KM-179

KM-180

KM-181KM-181A

KM-182

KM-183KM-183A

KM-184KM-185

KM-186

KM-187

KM-188

KM-189

KM-192

KM-193

KM-194

KM-195

KM-196

KM-197

KM-198

KM-199

KM-201

KM-202

KM-203

KM-205

KM-206

KM-208KM-208A

KM-209

KM-210

KM-211

KM-213

KM-214

KM-215

KM-216

KM-217

KM-218

KM-219

KM-220

KM-222

KM-224

KM-225

KM-226 KM-227 KM-228

KM-229

KM-230KM-231

KM-232KM-233 KM-234

KM-235

KM-236

KM-236A

KM-237

KM-238

KM-239

KM-240

KM-241

KM-243

KM-245

KM-246

KM-247

KM-248

KM-249

KM-251

KM-252A

KM-253

KM-255

KM-256

KM-257

KM-258

KM-260

KM-261

KM-262

KM-264

KM-265

KM-267

KM-268

KM-269

KM-270

KM-273

KM-274

KM-276

KM-281

KM-284

KM-288

KM-289

KM-290

KM-292

KM-293

KM-294

KM-298

KM-299

KM-300

KM-301

KM-306

KM-308

KM-316

KM-317

KM-322

KM-326

KM-327

KM-330KM-336

KM-370

KM-405

KM-418

KM-426

KM-444

KM-500

KM-501

KM-502

KM-503

KM-504

KM-505

KM-506

KM-507 KM-507A

KM-508

KM-509

KM-510

KM-510A

KM-511

KM-512

KM-513

KM-513A

KM-514

KM-515

KM-516

KM-517

KM-518

KM-519

KM-520

KM-521

KM-522

KM-523

KM-524

KM-525

KM-526

KM-527

KM-528

KM-529

KM-530

KM-531

KM-532

KM-533

KM-534(KME-X1)

KPM-01

KPM-02

483 68

483 68

483 69

483 69

483 70

483 70

483 71

483 71

483 72

483 72

483 73

483 73

483 74

483 74

483 75

483 75

483 76

483 76

483 77

483 77

483 78

483 78

95

9295

92

95

9395

93

95

9495

94

95

9595

95

95

9695

96

.

.

河道河口坝

砂体沉积微相图

席状砂水道间

s3A

图例 HKB

XZS

YSB

HKB

YSB XZS

NYSB

SDHKB

XZS

HKB

SD

YSB

HKB

HKB SD

HKB

YSB

YSB

100 0 100 200 300 400 500 m

0

60 154 294 420544.5 648.3 721.9 725.8 689.5 620.6

0

10

20

30

40

50

60

70

80

90

100

0

1000

2000

3000

4000

5000

6000

7000

8000

9000

1 2 3 4 5 6 7 8 9 10

YEAR

RATE

OIL

-FL

UID

-W

ATER

PRODUCTION & INJECTION FORECAST 2 PATTERN PER YEAR

BOPD

%WC

1 A 407.65 185.60

2 B 388.6 185.60

3 C 116.68 98.50

4 D 190.95 164.40

5 E 196.56 172.20

6 F 190.17 148.40

7 G 139.75 116.80

8 H 129.71 114.10

9 I 144.67 124.60

10 J 308.74 259.80

11 K 180.61 155.70

12 L 116.09 98.60

13 M 113.44 94.50

2,623.62 1,918.80

Forecast (MBO)

TOTAL

No PatternRem. Reserves

Area (MBO)


Reference

From many Sources