Managing liquid loading problem in gas wells in Burgos · PDF fileManaging liquid loading problem in gas wells in Burgos fields ... Pipesim Foam height and volume Foam declining time

2006 Gas Well Workshop

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Managing liquid loading problem in gas wells in Burgos fields

Otoniel Morales Martínez, José L. Martínez Galván, Dr Miso SolesaALS, México North, SLB; Leticia De la Mora, Eddi De la Vega, Region North, Pemex

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• To present the Methodology developed to Analyze the behavior of the Wells producing of Gas, with the purpose of proposing the best alternative of exploitation.

OBJECTIVE

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APPLIED METHODOLOGY FOR THE DIAGNOSE AND SOLUTION OF THE PROBLEM

Symptoms Problem

Diagnoses

Multi-CriteriaRanking Analysis

Composit System

Analysis

Data Preparation Data Analysis

Solutions

?

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PREPARATION AND ANALYSIS OF DATA

Type Number ofintervals Distance Flow type

Well completionscheme

Well productionand pressure

HistoryCurrent wellproduction Field Survey Data

Gas andCondensatecomposition

Fluid properties

Laboratory analysisof foamy agents

Monobore

Conventional

2-7/8"

3-1/2"

No packer

Packer

Sinlglezone

Multiplezone

Distance topacker

Distance betweenintervals

Coiled Tubing2", 1-3/4" and 1-1/2" Tubing

AnnulusTubing/Annulus.

Fractured

Short <= 50 m or justabove packer

Medium 50-200 m

Large > 200 m

Short <= 50 m

Medium 50-100 m

Large > 100 m

Gas rate

Liquid rate (waterand condensate)

Wellheadpressure

Casing pressure

Line pressure

Choke diameter

Flowing pressure andtemperature

Liquid level (casingand tubing)

Surface buildup anddrawdown test

Test with foamy agents

Correction of gascomposition according

to flowing pressure

Pipesim

Foam height andvolume

Foam declining time

Liquid lifting efficiency

Remaning liquidduring gas bubling

Remaning liquid aftergas bubling

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COMPOSIT SYSTEM ANALYSIS

Composit SystemAnalysis

Gas Wells with LiquidLoading Problem

Set Input Parameters andbuild the model

Gas compositioncorrection using wellbore

pressure survey

Precursorydata preparation Static pressure estimation

Cu le bra - 262Sim ulador de Pre s ión de Yacim ie nto-Conociendo un dato de Prueba

0.57

0.58

0.59

0.60

0.61

0.62

0.63

0.64

1000 1010 1020 1030 1040 1050 1060Pre s ión de Ya c im ie nto

Ma

xim

o g

ast

o d

e g

as

0

0.001

0.002

0.003

0.004

0.005

0.006

0.007

Qq m a x Mis hre Qg m a x Fetkovich D ife ren cia

Correlation matching

Model matching

Stable flowconditions?

No

Yes

Result:The best

correlation

Result:Well and reservoir

model

DetailedCompositional

Systemanalysis

Selection the mostimportant

paramets forsensitivity analysis

Reservoir pressureTubing sizeLine pressureChoke sizeHouldup factor......

Problens to match wellmodel

Unknown reservoir pressureMesurement data accurencyUnstable well operationCorrelations can notaccuratelly represent what ishappening down-hole whenthe well is loaded with liquidsTransient flow conditionsdue to very low permeabilityHigh system pressure andsubsonic flow through choke

Interpretationof the Results

Symptoms and ProblemDiagnosis using SA

resultsCritical gas rateFlow conditionsthrough the well and chokeSystem pressure influenceTubing sizeFuture performance

........

Recommendation using SAStable operation - leave the well toproduceRecomplete the well with CTDecrease the system pressure and use wellhead compresorUse liquid foam agentChange choke sizeReperforation...........

Intermittentoperation

Surfacebuildup test

available

Field testwith

chemicals

Perform thetest and

analyze results

Recommendations

Motor valve with electronic cycle controlerPlunger lift- casing, conventional and CTFoam stick with automatic lunchingcontrolCombined system (motor valve and foamstick)Two motor valvesMotor valve and coiled tubing

Yes

Yes

No

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ADJUST OF THE COMPOSITION

Calculation of the % Mole

The Percentage of the condensate and water into the liquid phase are obtained from the Three phase Measurement

Gas Cond. Water Grad.Mixture Dens.Gas Dens.Cond Dens.Water(%) (%) (%) (kg/cm2/m) 0.61 0.75 1

19% 81% % Gas % Cond % Agua

99.5 0.095 0.405 0.002341 18.426 0.018 0.07567.6 6.156 26.244 0.032477 12.519 1.140 4.86068.6 5.966 25.434 0.032213 12.704 1.105 4.71066.9 6.289 26.811 0.034339 12.389 1.165 4.96570.0 5.7 24.3 0.032019 12.963 1.056 4.50061.4 7.334 31.266 0.040076 4.548 0.543 2.316

72.333 5.257 22.410 0.028911 73.548 5.026 21.426

Grad Mw Grad / Mw Molgr/cm3 grm/grMol grMol/cm3 %

Total 0.28910924 0.0157318 100.00Gas 0.21263449 17.672 0.012032282 76.484Cond 0.0145302 55.659 0.000261058 1.659Agua 0.06194455 18.0152 0.00343846 21.857

Depth Temperature Gradiente Notes( m ) psia Kg/cm2 ( o C ) (kg/cm2/m)0 343.43 24.15 11.14 *

500 360.08 25.32 26.96 0.002341 Gas1,000 591.29 41.57 48.90 0.032512 Gas + Líquido1,500 820.38 57.68 67.84 0.032214 Gas + Líquido2,000 1,064.66 74.85 93.22 0.034350 Gas + Líquido2,500 1,292.14 90.85 111.18 0.031988 Gas + Líquido2,700 1,406.12 98.86 122.51 0.040069 Gas + Líquido

Bottom Hole PressureFlowing Bottom hole Pressure Measured

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ADJUST OF THE COMPOSITION OF THE GAS

V LVol Mw Dens. Masa Mol Mol Vol m Gas Liq.

bl/MMpc lbm/lbmol lbm/pie3 lbm lbmol % % % 70 30

16.0427 9.1131 0.00 0.0000 0.00 0.00 0.00 93.02 0.00

30.0696 22.8660 0.00 0.0000 0.00 0.00 0.00 3.10 0.00

4.76 44.0965 32.1946 860.48 19.5135 2.43 9.75 5.48 0.73 2.43

1.08 58.1234 35.0807 212.74 3.6601 0.46 2.21 1.36 0.14 0.46

0.6 58.1234 36.4283 122.73 2.1115 0.26 1.23 0.78 0.08 0.26

0.52 72.1503 38.9538 113.74 1.5764 0.20 1.06 0.72 0.06 0.20

0.17 72.1503 39.3190 37.53 0.5202 0.06 0.35 0.24 0.02 0.06

2.15 86.1772 41.3589 499.30 5.7938 0.72 4.40 3.18 0.22 0.72

28.0134 17.5532 0.00 0.0000 0.00 0.00 0.00 0.12 0.00

44.0099 52.4248 0.00 0.0000 0.00 0.00 0.00 2.51 0.00

39.562105 18.0152 62.3388 13,848.01 768.6848 95.86 81.00 88.23 0.00 95.86

48.84 15,694.52 801.86 100.00 100.00 100.00 100.00 100.00

L i q u i d

LL V

m=δ

L

Lw Mole

mM = Estimated composition of the Original Fluid

Fraction Formula %Methane CH4 65.11Ethane C2H6 2.17Propane C3H8 1.24Isobutane iC4H10 0.23Butane nC4H10 0.13Isopentane iC5H12 0.10Pentane nC5H12 0.03Hexane C6H14 0.37Nitrogen N2 0.08Carbon Dioxide CO2 1.76Water H2O 28.76Total 100.00

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INFLOW PERFORMANCE CURVE, IPR

Reservoir Pressure simulator-One test rate is known

0.000

0.200

0.400

0.600

0.800

1.000

1.200

1.400

1200 1300 1400 1500 1600 1700 1800 1900

Reservoir pressure

Max

imum

gas

rate

-0.01

0

0.01

0.02

0.03

0.04

0.05

0.06

0.07

0.08

0.09

Qqmax Mishre Qgmax Fetkovich Diff

WellQgt 0.52 MMscf Test gas ratePwft 1122.6 Psi BHFWP test

Assumed Qqmax Assumed Assumed QgmaxPr Mishre Flow exponent Flow constant FetkovichPsi MMscf/d n c MMscf/d

1 1800 0.665 0.5870 0.000104686 0.694 0.0297892852 1750 0.680 0.5870 0.000110621 0.710 0.0302784133 1700 0.697 0.5870 0.000117351 0.728 0.0304504094 1650 0.719 0.5870 0.000125064 0.749 0.0301215095 1600 0.745 0.5870 0.000134018 0.774 0.0290010926 1550 0.778 0.5870 0.000144575 0.805 0.0266156217 1500 0.820 0.5870 0.000157262 0.842 0.0221633878 1400 0.952 0.5870 0.000192759 0.952 7.0783E-059 1350 1.063 0.5870 0.000219172 1.037 0.02590108110 1300 1.239 0.5870 0.000256622 1.162 0.076943637

Input Data

DiffIterations

Culebra-825

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MULTI-CRITERIA MODEL

Structure of the MultiStructure of the Multi--Criterial ModelCriterial Model

1 2 3 4 5 6 7

Subclases: Individuals Factors at level micro

General Factors

Matrix of Evaluation

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MULTI-CRITERIA MODEL

The parameters that influence in the problem of accumulation of liquid and selection of the appropriate artificial system are classified in the following main groups:

GENERAL FACTORSGENERAL FACTORS

PRODUCTION AND PRESSURE HISTORY

WELL COMPLETION

CURRENT WELL PERFORMANCE

OTHER PROBLEMS

COSTS

LABORATORY TESTS

FIELD TESTS

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2

3

4

5

6

7

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MATRIX OF EVALUATION

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SYMPTOMS AND DIAGNOSES

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SOLUTIONS

Intermittent liftFlowing production

Coiled Tubing 2, 1 3/4Ó y 1 ?Ó

Wellhead compressor

Capillary Tube

Coiled tubing with liquid foam injection in casing

Motor valve

Motor valve and foam stick

Foam stick application (mannualy or automatic luncher)

Coiled tubing and motor valve

Coiled tubing with two motor valves

Plunger lift

Intermittent lift

APPLIED PRODUCTION SYSTEMS

Velocity String 2”, 1-3/4”, 1-1/2” and 1”

Wellhead compressor

Capillary Tube

Coiled tubing with liquid foam injectionIn casing

Motor valve

Motor valve and foam stick

Foam stick application(mannualy or automatic launcher)

Coiled tubing and motor valve

Coiled tubing and motor valveInstalled on casing

Coiled tubing with two motor valves

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PROCESS OF OPTIMIZATION

Initial welland network

anlalysis

RecommendationPrograms

Instllation

Check thewells

Compare withPrevious analysis

Operate according to analysis

There is possibilityto improve

New analysis

New operatingprogram

Check the Surface

conditionsContinue

with production

Initial wellanalysis

Programs to applyThe Recommendations

Installation

Check thewells

Compare withPreviousAnalysis

Operate according to analysis

There is possibilityto improve

New analysis

NewOperatingProgramCheck the

SurfaceConditions

ContinueWith

Production

Yes

YesNo

No

Yes

No

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ARCHITECTURE OF THE TELEMETRY SYSTEM

•OASIS

•PANDURA•CORINDON

•JAUJAL•GIGANTE

•VELERO•ARCOS

•ALONDRA

•QUITRIN•GEMINIS

•ARCABUZ•STA. ROSALIA•VIBORITAS

•MOJARREÑAS

•P. BLANCA •CARRETAS

•CUATRO MILPAS

•CULEBRA

•MISION•CAÑON

•REYNOSA•FCO. CANO

•CUITLAHUAC

•COMITAS

•18 DE MARZO

•Occidental

•Oriental

•REYNOSA•MATAMOROS

•NVO. LAREDO

•PRESA

•SULTAN

•Central•TORRECILLAS

•BENAVIDES

•RODEO

•OVEJA

•EMU

•LOBO

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PRESENTATION OF THE INFORMATION

TELEMETRY

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CASE STUDY

Well: CULEBRA-91

• Well Completion in “Tubing Less” 3-1/2”

• A single producing interval

• Belonging to the formation W-4, B3B

• Velocity String of 2 ”, 20 m above the producing interval

• Aligned to the Gathering Station Culebra 2

• Flow line of 3” and 530 m of length

157 m.

CULEBRA 91(ESTADO MECANICO ACTUAL)

Cul-91.PRZ

TR 9 5/8"

EXPLORACION Y PRODUCCIONEXPLORACION Y PRODUCCION

PROYECTO INTEGRALCUENCA DE BURGOS

EQUIPO ARCABUZ - CULEBRA

1566 m

2574.0 m.2547.0 m.

T. LESS 3 1/2" 2699 m.

TR 7"

(W-4)

PROF. TOTAL 2705.0 m.

DATOS FRACTURA W4FECHA:23/NOV/97INTERVALO 2547- 2574 m Arena Econoprop (20-40) = 3550 scsVol. Arena Super DC (20-40) = 858 scs

2501.0 m.2487.0 m. (W-3) PENDIENTE DE DISPARO

PMED=4280 PSI, PF=2050 PSI, Q=30 BBL/MIN, hP=314.

SE CUMPLIO 100% EL PROGRAMA 9:00-12:00 HRS WF-220, EMPLEANDO 405000 LBS DE 20/40 ECONOPROP Y 90000 LBS, DE 20/40 SUPER DC PARAMETROS OBETNIDOS: PR=3358 PSI, GF=0.8 PSI/PIE, ISIP=2030, PCIERRE= 1300,

Sarta de Velocidad de 2” a 2527 m

(1-may-02)

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CASE STUDYHistory of Production

Features:• The production began in Nov

28, 1996.• During the first 2 years of their

history, a strong decline was observed

• When the well was aligned to the system “Comprimido Baja”, the production increment was of 850% (May 31, 200)

• The liquid loading started before aligning to “ C. Baja”and then it was solved for a short period

• The liquid loading was solved with the installation of the Velocity String of 2”

• Starting from December of the 2003 the declination increased considerably

Pozo: CULEBRA-91Historia de Producción, pozo con Sarta de Velocidad de 2" a 2527 m.

100

300

500

700

900

1100

1300

1500

1700

1900

2100

2300

2500

2700

2900

27-N

ov-9

6

27-F

eb-9

7

27-M

ay-9

7

27-A

ug-9

7

27-N

ov-9

7

27-F

eb-9

8

27-M

ay-9

8

27-A

ug-9

8

27-N

ov-9

8

27-F

eb-9

9

27-M

ay-9

9

27-A

ug-9

9

27-N

ov-9

9

27-F

eb-0

0

27-M

ay-0

0

27-A

ug-0

0

27-N

ov-0

0

27-F

eb-0

1

27-M

ay-0

1

27-A

ug-0

1

27-N

ov-0

1

27-F

eb-0

2

27-M

ay-0

2

27-A

ug-0

2

27-N

ov-0

2

27-F

eb-0

3

27-M

ay-0

3

27-A

ug-0

3

27-N

ov-0

3

Fecha, dd-mm-aa

Pres

ión,

psi

g /

Pr

oduc

ción

de

líqui

do, b

pd

0.0000.2000.4000.6000.8001.0001.2001.4001.6001.8002.0002.2002.4002.6002.8003.0003.2003.4003.6003.8004.0004.2004.4004.6004.8005.0005.2005.400

Presión en cabeza Presión de línea Gasto de agua Gasto de condensado Gasto de gas

Gas

to d

e G

as, M

MPC

D

Inge

nier

ía: 2

0-M

ar-0

2

Con

SV

des

de 1

-May

-02

"Comprimido Baja"

24/64" desde 24-mar-04

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CASE STUDYDaily supervision

• The liquid loading started again in October, 2003 with the Velocity String

• The well was worked with Closings and foamy agents

• The maximum pressure at the well head was of 580 psig

• With the crew of Optimization it was possible to operate in continuous form and we could use the Technique of Nodal Analysis

Pozo: CULEBRA-91Datos de la Supervisión de pozos y Gasto de gas calculado con Ec. de campo.

-

100

200

300

400

500

600

700

800

900

24-M

ay-0

2

24-J

un-0

2

24-J

ul-0

2

24-A

ug-0

2

24-S

ep-0

2

24-O

ct-0

2

24-N

ov-0

2

24-D

ec-0

2

24-J

an-0

3

24-F

eb-0

3

24-M

ar-0

3

24-A

pr-0

3

24-M

ay-0

3

24-J

un-0

3

24-J

ul-0

3

24-A

ug-0

3

24-S

ep-0

3

24-O

ct-0

3

24-N

ov-0

3

24-D

ec-0

3

24-J

an-0

4

24-F

eb-0

4

24-M

ar-0

4

24-A

pr-0

4

24-M

ay-0

4Fecha, dd-mm-aa

Pres

ión,

psi

g

0.000

0.100

0.200

0.300

0.400

0.500

0.600

0.700

0.800

0.900

1.000

1.100

1.200

Presión de cabeza Presión de línea Gasto de gas Campo

Gas

to d

e G

as c

on E

c. D

e C

ampo

, MM

PCD

Hasta 24-Mar-04 16/64"

Con SV 2" desde 1-May-02

24/64"

Se trabajó con cierres y barras espumantes hasta re-establecer el flujo

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CASE STUDYAdjust of the Model

14-jun-02 con 16/64”

2-jun-04 con 24/64”

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CASE STUDYSymptoms and Diagnosis

• The well had a variable behavior of the production of gas

• At the end of October, 2004 the Wellhead Pressure declined until the load condition was reached and the well stopped to flow

• The well produces Water and Condensed, prevailing the phase Water

• The foamy agents present good efficiency when generating foam with the liquid of the well

• The main problem that affected the gas production was the liquid loading in the Velocity String

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CASE STUDYRecommendations and Evaluation

• To continue launching 3 Soap Stick “A” daily

• When the liquid loading occur again, evaluate the system of Capillary Tube and the Motor Valve combined with Automatic Soap Stick Launcher

Pozo: CULEBRA-91Historia de Producción, pozo con Sarta de Velocidad de 2" a 2527 m.

100

300

500

700

900

1100

1300

1500

1700

1900

2100

2300

2500

2700

2900

01-A

pr-0

2

01-M

ay-0

2

01-J

un-0

2

01-J

ul-0

2

01-A

ug-0

2

01-S

ep-0

2

01-O

ct-0

2

01-N

ov-0

2

01-D

ec-0

2

01-J

an-0

3

01-F

eb-0

3

01-M

ar-0

3

01-A

pr-0

3

01-M

ay-0

3

01-J

un-0

3

01-J

ul-0

3

01-A

ug-0

3

01-S

ep-0

3

01-O

ct-0

3

01-N

ov-0

3

01-D

ec-0

3

01-J

an-0

4

01-F

eb-0

4

01-M

ar-0

4

01-A

pr-0

4

01-M

ay-0

4

01-J

un-0

4

Fecha, dd-mm-aa

Pres

ión,

psi

g /

Pr

oduc

ción

de

líqui

do, b

pd

0.0000.2000.4000.6000.8001.0001.2001.4001.6001.8002.0002.2002.4002.6002.8003.0003.2003.4003.6003.8004.0004.2004.4004.6004.8005.0005.2005.400

Presión en cabeza Presión de línea Gasto de agua Gasto de condensado Gasto de gas

Gas

to d

e G

as, M

MPC

D

Inge

nier

ía: 2

0-M

ar-0

2

Con

SV

des

de 1

-May

-02

"Comprimido Baja"

24/64" desde 24-mar-04

Se re-estableció la Producciónen 1.063 MMpcd

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RESULTS OF THE PROJECT

Producción de Gas por SistemaDe Enero / 2002 a Agosto / 2005

0

20

40

60

80

100

120

140

Ene-

02

Abr

-02

Jul-0

2

Oct

-02

Ene-

03

Abr

-03

Jul-0

3

Oct

-03

Ene-

04

Abr

-04

Jul-0

4

Oct

-04

Ene-

05

Abr

-05

Jul-0

5

PRO

DU

CC

ION

DE

GA

S (M

MPC

D)

Sarta de velocidad Tuberia capilar Válvulas motoras Reactivo barras Émbolo viajero

64%10%

16%

10% 0%

Total of Wells with a System installed= 763 (Aug/05)

Gas Production by SystemFrom January/2002 to August/2005

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RESULTS OF THE PROJECT

APPLIED PRODUCTION SYSTEMS AND DATA RECORDEDAPPLIED PRODUCTION SYSTEMS AND DATA RECORDED

127 Velocity Strings 127 Velocity Strings 185 Flow Tubes Meter185 Flow Tubes Meter245 Motor Valve245 Motor Valve143 Automatic Soap Stick Launcher143 Automatic Soap Stick Launcher480,203 Soap Stick480,203 Soap Stick

2,713 Three Phase Measurement 2,713 Three Phase Measurement 863 Gauge of the Inside Diameter863 Gauge of the Inside Diameter764 Flowing Bottom hole Pressure764 Flowing Bottom hole Pressure

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CONCLUSIONS

• The developed methodology has demonstrated to be reliable and itis possible to apply it in other Gas Fields with Liquid Loading problems.

• We have been analyzed more than 763 wells and in 95% of them a system has been applied that has allowed to increase the production in 114 MMscfd during the period from Nov-2002 to Aug- 2005