2008 SPE Progressing Cavity Pumping - ALRDC - Home · 2008 SPE Progressing Cavity Pumping...

2008 SPE Progressing Cavity Pumping Conference and Exhibition

Houston, Texas April 27 – 29, 2008

Value of Real-Time Data From Automated and Integrated Well Monitoring Systems in a Venezuelan Heavy Oil Project

Ivan Prado – Production Engineer – PDVSA PetroPiar

Lee Zabel – Product Line Manager - Weatherford

April 27 - 29, 2008 2008 Progessing Cavity Pumping Conference

2

Agenda

• Geographic Location and Operational Environment• Architecture• Workflow and Analysis• Operation Improvements• Benefits and Conclusions


3

Geographic Location

Puerto La CruzPuerto La Cruz

Junin

Carabobo

BoyacáAyacucho

JoseJose

152 KmPDVSA PETROPIAR

PDVSA 70%

Chevron 30%

PETROECEDEÑO PETROANZOATEGUIPETROMONAGAS

CaracasCaracas

ORINOCO OIL BELTORINOCO OIL BELT

52 Km

VENEZUELA

ORINOCO OIL BELT


4

Geographic Location


5

Operational Environment


6

Operational Environment


7

Operational Overview•• In the Faja area, PCPs are the artificial lift In the Faja area, PCPs are the artificial lift

system of choice. system of choice.

•• Most PCP systems around the world are Most PCP systems around the world are controlled by surface parameter controlled by surface parameter interpretation (Torque, Speed, Flow Rate)interpretation (Torque, Speed, Flow Rate)

•• To effectively operate and maximixe the To effectively operate and maximixe the run life of the large high capacity PCPrun life of the large high capacity PCP’’s, s, there is a necessity to know bottomhole there is a necessity to know bottomhole operating conditions (pressures and operating conditions (pressures and temperatures). temperatures).

•• This information helps to optimize This information helps to optimize operating, reservoir performance, operating, reservoir performance, simulation and forecastingsimulation and forecasting

•• Data adquisitation system have been Data adquisitation system have been implementedimplemented


8

Architecture

• SCADA Host– csLIFT host server located at COB– Collects data from pressure sensors, VFDs, PLCs Wellpad

Manager Systems, XPIOs, and CS7X well test controllers.– Communication through fiber optic from well pads to COB– Communication from COB to Puerto La Cruz office– Provides monitoring and remote control of the field in COB– Provides monitoring access to all users at COB and Puerto

La Cruz office– Interfaces with main data base system (ORACLE)


9

Architecture

• Wellpads– Data loggers collect the downhole information from

subsurface sensors and VFD readings.– Two different models of data loggers - CS7X and XPIO.– PLC controllers set and maintain diluent injection rates, and

collect well test data from the multiphase flow meters.– Data loggers and VFDs are skid mounted with one data

logger and three VFDs per skid.


10

Oracle Database

DH Gauges

Well PadVariable

Well


11

Work Flow Diagram

MONITORINGWells & MPPsMONITORINGWells & MPPs

Field Data

csPCP (Short Term)

csPCP (Short Term)

PHDPHD

Daily Production Report

Daily Production Report

Daily Production Plan

Daily Production Plan

Monthly Production&

Official Rep.

Monthly Production&

Official Rep.

Data Storage

Welltest (csWelltest)

Welltest (csWelltest)

OFM(Long Term)

OFM(Long Term)ORACLEORACLE

Simulation & Well Planing

Simulation & Well Planing

• Cum. Oil • Failure Analysis & Workovers• Maintenance• PI Decline Forecast

• Cum. Oil • Failure Analysis & Workovers• Maintenance• PI Decline Forecast

ExperionExperion


12

Workflow and Analysis CASE

Monitoring(csPCP)

Alarm messages to easily detect problems

Daily monitoring of parameters to identify operationalconditions out of range, which allow prompt operator response to protect equipment


13

Operation Improvements: Daily Production Plan

Production Plan takes intake pressure, torque and welltest data from CASE to update operations conditions and flowrates for next 24 hours

Intake Pressure and Torque from CASE


14

Workflow and Analysis: Well test

csWelltest

Well Test data and operating data used to optimize production, evaluate pump performance and to size replacement pumps


15

Workflow and Analysis: Wellpad Display

General views of one wellpads


16

Workflow and Analysis: Wellbore Display

520.4 540.7

150.3 150.3


17

Workflow and Analysis:Welltest Display


18

PHD – MPP Monitoring Graph


19

Operation Improvements

Automated daily production reporting to operations and management


20

Operation Improvements

•Automated monthly production reporting, including allocation factors and allocation of individual well production to reservoirs.

•Automated reporting to meet government requirements.


21

Operation Improvements: Simulation and Forecasting

Calculated Cum Oil

Observed Cum Oil

Observed GOR

Calculated GOR

Pressure and allocated production data uploaded for use in well simulation and future well planning


22

Operation Improvements: Simulation and Forecasting

FIELD POTENTIAL

0

10000

20000

30000

40000

50000

60000

70000

80000

90000

100000

110000

120000

130000

140000

150000

160000

170000

180000

190000

200000

210000

220000

230000

240000

250000

7.7

7.75

7.8

7.85

7.9

7.95

8

8.05

8.1

8.15

8.2

8.25

8.3

POTENTIALPad J2 (38)Pad K2 (37)Pad L3 (36)Pad L4 (35)Pad G2 (34)Pad F2 (33)Pad G6 (32)Pad K5 (31)Pad H2 (30)Pad E6 (29)Pad C3 (28)Pad J5 (27)Pad F6 (26)Pad K4 (25)Pad K3 (24)Pad F3 (23)Pad J3 (22)Pad I3 (21)Pad H3 (20)Pad D6(19)Pad C6(18)Pad B6(17)Pad J4Pad I4Pad H4Pad H5Pad G5Pad E4Pad F5Pad B4(addn)Pad F4Pad E5Pad D5Pad C4Pad C5Pad B4(exist)Pad A4Pad B5Pad A5P90P50P10Field API

Historic PI decline trends (data from pressure gauges and production allocation) used to evaluate individual well capacity, total field capacity and for future field development plans

PRODUCTIVITY INDEX RATIO DECLINE

0.00

0.50

1.00

1.50

2.00

2.50

3.00

3.50

4.00

0 50 100 150 200 250 300 350

CUMULATIVE ALLOCATED OIL PRODUCTION (MSTB)

P.I.

Adjusted PI Match


23

Operation Improvements: Failures

Daily monitoring of data and trends to identify new or impending pump failures

Short TermCs PCP GRAPH: F3 P02

TorqueRPMIntake PressureDescharge Pressure


24

Operation Improvements: Failures

Daily monitoring of data and trends to identify new or impending pump failures

H3-P13 esta mostrando un incremento de presión de entrada y disminución de la presión de descarga sin haber variaciones de velocidad en un período de tiempo. Esto puede ser el inicio de una falla de la BCP. De ser este el caso la producción de este pozo sería cero 0 y se tendria que esperar a ser intervenido. Se recomienda ajustar a 250 RPM y realizar una prueba de flujo para determinar factor de bomba.

RPMIntake PressureDescharge Pressure

Torque


25

2005 06 07 080

300

600

900

1200

1500

0

50

100

150

200

250

Date

Well Name: B5-P09

Operation Improvements: History

Pum

p Sp

eed

(RPM

)

OFM GRAPH

Middle and Long Term

Torq

ue (l

b.ft)

–In

take

Pre

ssur

e (p

si) –

Dis

char

ge P

ress

ure

(psi

)


26

Benefits and Conclusions

• Real-Time Data from Automated and Integrated Monitoring System provides the following added value:

– Real time access to current operating conditions, as well as short-term, long-term historic data for trending, identifying failures

– Easy programming provides alarm conditions, quick operator response

– Allows proactive versus reactive decisions, reduces downtime anddeferred production

– Continuous PCP performance evaluation and production optimization

– Automated report generation

– Reduced operating cost , reduced manpower requirements

– Improved Reservoir Management and future field development planning


27

SPECIAL THANKS

SPECIAL THANKS TO:PDVSA-PETROPIAR MANAGEMENTSHAMACA PRODUCTION ENGINEER STAFF

• Luisana Peraza• Maria Rodriguez• Javier Sanchez• Rafael Medina

Jack English - ChevronDavid Watts


28

Questions...

2008 SPE Progressing Cavity Pumping - ALRDC - Home · 2008 SPE Progressing Cavity Pumping...

Documents

Transcript of 2008 SPE Progressing Cavity Pumping - ALRDC - Home · 2008 SPE Progressing Cavity Pumping...