Transient Pressure and Temperature Interpretation in · 5 Completion: In-well Monitoring & Flow...

SPE Aberdeen

3rd Inwell Flow Surveillance and

Control Seminar

3rd October 2017

Transient Pressure and Temperature Interpretation in

Intelligent Wells of the Golden Eagle Field

Khafiz Muradov

Institute of Petroleum Engineering, Heriot-Watt University, Edinburgh, UK

Ken Macrae

Nexen Petroleum U.K. Ltd.

2

Outline

• Field and Well Description

• Temperature Transient Analysis (TTA) Basics

• Useful Events and Input Data

• TTA Selected Results

• Conclusions

Transient Pressure and Temperature Interpretation in Intelligent Wells of the Golden Eagle Field (SPE-185817) • Khafiz Muradov and Ken Macrae

3

The Golden Eagle Field


• The Golden Eagle Area is located 100 km NE of

Aberdeen in the UKCS

• Production started in October 2014 with water injection

some months later.

• The field produces a light, under-saturated black oil

from the:

• Lower Cretaceous Punt sandstone

• Upper Jurassic Burns sandstone

• The two formations were, and possibly still are, in

communication in at least one area of the field.

Golden Eagle Area Development Map

4

The Golden Eagle Field


• I-well technology installed in most of

the 14 production and 5 injection

wells

• ICVs manage the production from

up to 3 zones/per well

• Produced separately or

comingled in any combination.

Cross Section Through Central Golden Eagle Field

5

Completion:

In-well Monitoring & Flow Control


Completion:- In-well Monitoring & Flow ControlWell A: A 60o deviated, high PI, 3-zone, intelligent, oil

production well

DTS

FBG1 ICDs and screens

Fibre-optic In-well Monitoring:

• FBG - high precision (within

1.5psi and 0.02ºC) P/T gauges:

1 per zone

Zonal Control:

• 10-position, hydraulic ICVs (on inner tubing)

and ICDs (on outer screens)

ICV1

FBG1 (P/T gauge)

and Flow Meter

Courtesy of

Halliburton

FBG2 (P/T gauge)

FBG3

(P/T gauge)

ICV2

ICV3

Zone 1

(Upper Punt)

Zone 2

(Lower Punt)

Zone 3

(Burns)

Well A

• 2-phase flowmeter measures total

well rate and Water Cut

• DTS across completion interval

(insufficient resolution for this study)

FBG3

FBG2

6

Problem Statement


1. In-well flowmeters measure total well rate and

• Pressure & Temperature data measured by permanent, high-precision gauges but

• Workflow required to turn measured data into information on zonal flow rate allocation, reservoir

monitoring, history matching, etc.

2. ICVs are regularly cycled.

• Provides zonal flow-rate build-up and drawdown (transient) data as part of routine operations for:

i. Pressure Transient Analysis (PTA)

• Well-developed with high quality analysis software available

ii. Temperature Transient Analysis (TTA)

• Novel

• Golden Eagle Field provides a unique set of data to extend and verify industry knowledge in this

area

7

Outline





• Conclusions


8

Transient Temperature Analysis

A Game Changer for Multi-zone Wells


Example from: MURADOV, K. & DAVIES, D. 2012b. Temperature transient analysis in

horizontal wells: Application workflow, problems and advantages. Journal of Petroleum

Science and Engineering, 92–93, 11-23

Discrete and Distributed TTA analysis:

An attractive source of information:

1. Differentiates zones

2. Layer-by-layer testing no longer required

• ALSO Tolerant to gauge drift & accuracy

BUT analysis workflow not widely adopted yet

99.4

99.6

99.8

100

100.2

100.4

100.6

21/08/04 22/08/04 23/08/04 24/08/04 25/08/04 26/08/04 27/08/04

Tem

pera

ture

, C

Time

Zone 1

Zone 2

Zone 3

Zone 4

zonal temperatures – discriminates zonesones

215

225

235

245

255

265

21/08/04 22/08/04 23/08/04 24/08/04 25/08/04 26/08/04 27/08/04

Pre

ss

ure

, ba

r

Time

Zone 1

Zone 2

Zone 3

Zone 4

zonal pressures - indiscriminate

vs

A 4-zone intelligent well shut-in & start-up

9

Potential Benefits of Transient Pressure &

Temperature Data

1.E+02

1.E+03

1.E+04

1.E+05

1.E+06

1.E+07

1.0E-03

1.0E-02

1.0E-01

1.0E+00

1.0E+01

1.0E+02

1000 10000 100000

d(B

HP

i-B

HP

)/d

ln(e

lap

se

d tim

e),

ba

r /

ln(s

)

dB

HT

/dln

(ela

ps

ed

tim

e),

K / ln

(s)

elapsed time, s

zonal temperature derivative over logarithm of elapsed time

zonal pressure derivative over logarithm of elapsed time

1/2 slope

0 slope

Example from MURADOV, K. & DAVIES, D. 2012b. Temperature transient analysis in horizontal wells: Application workflow, problems and advantages.

Journal of Petroleum Science and Engineering, 92–93, 11-23

1. P data is better at describing the reservoir at a distance

2. T recognises the near-wellbore effects much better than P

T signal propagates much slower than P signal


11

Physics of Pressure & Temperature changes


𝜕

𝜕𝑡𝜙𝜌 + 𝛻 ∙ −𝜌

𝑲

𝜇𝛻𝑃 = 0

Pressure Model (Diffusivity equation)*

Transient pressure change Divergence of mass flux

Thermal Model*

𝜌 𝐶𝑃𝜕𝑇

𝜕𝑡− ∅𝛽𝑇

𝜕𝑃

𝜕𝑡− ∅𝐶𝑓 𝑃 + 𝜌𝑓 𝐶𝑃𝑓𝑇

𝜕𝑃

𝜕𝑡= −𝜌𝑣 𝐶𝑝 ∙ 𝛻𝑇 + 𝛽𝑇𝑣 ∙ 𝛻𝑃 − 𝑣 ∙ 𝛻𝑃 + 𝐾𝑇𝛻

2𝑇

Transient temperature

change

Transient fluid

expansion

Transient formation

rock compression

Heat convection Joule-Thomson

effect

Heat conduction

Pressure and Temperature response

compared for a numerical model of a

vertical, oil production well

12

Selected Solutions Available To-Date


TTA Research is relatively new ( since 2008)

TTA

Researc

h

Liquids

Numerical

Texas A&M (Sui et.al.)

Chevron (App, J.F)

Analytical

Bashkir State Uni. Russia (Ramazanov et.al.)

Heriot-Watt, UK (Muradov & Davies)

Istanbul Tech. Uni

(Onur et al.)

Gas

Numerical

Texas A&M (Sui et.al.)

Stanford, US (App et.al)

Chevron (App, J.F)

AnalyticalHeriot-Watt, UK (Dada,

Muradov, Davies)

Used here for data

interpretation of:

1. Late-time TDD in

damage zone

2. Late-time TDD

beyond damage

zone

3. Late-time TBU

4. Multi-zone late-

time TDD

*TDD - Temperature

Draw Down

*TBU - Temperature

Build-Up

(Equations derived in

SPE 136256 and

SPE 180074)

13

Outline





• Conclusions


15

Select Well A Data for TTA interpretation

after 5 months:


Routine ICV cycling/testing

1. Zone 1 and 2 TTA events due to rate change in another zone selected

2. ICV3 cycling: simultaneous rate change in all zones used for multi-zone TTA

130

140

150

160

170

180

190

200

120

125

130

135

140

145

150

155

16/11/2015 17/11/2015 17/11/2015 18/11/2015 18/11/2015 19/11/2015 19/11/2015

Pre

ssu

re Z

on

e 3

, bar

g

Pre

ssu

re Z

on

es

1 a

nd

2, b

arg

Zone 1 Ptub, Pt1 Zone 2 annulus P, Pa2 Zone 3 annulus P, Pa3

74

74.5

75

75.5

76

76.5

77

77.5

78

78.5

79

16/11/2015 17/11/2015 17/11/2015 18/11/2015 18/11/2015 19/11/2015 19/11/2015

Tem

pe

ratu

re, d

egC

Zone 1 annulus T, Ta1 Zone 2 annulus T, Ta2 Zone 3 annulus T, Ta3

0

50

100

150

16/11/2015 17/11/2015 17/11/2015 18/11/2015 18/11/2015 19/11/2015

Surf

ace

ch

oke

o

pen

ing,

%

Axis Title

0

2

4

6

8

10

12

17/11 00/00 17/11 12/00 18/11 00/00 18/11 12/00 19/11 00/00

ICV

op

en

ing,

po

siti

on

icv1 icv2 icv3

Da

tas

et

for

Zo

ne

1 T

TA

Da

tas

et

for

Zo

ne

2 T

TA

Da

tas

et

for

mu

lti-

zo

ne

TTA

Z1 Tubing Pressure

Z2 Annulus Pressure

Z3 Annulus Pressure

Z1 Annulus Temperature



Surface Choke opening:

from 0 to 100%

Zonal ICVs opening:

positions from 0 to 10

ICV1

ICV2

ICV3

16

Fluid and Formation Properties


1. Conventional PVT properties available.

2. In-situ Thermal fluid properties are unknown, however there are multiple ways to estimate them cheaply and accurately. From instance in this work:

Specific heat capacity, Cp

estimated using black oil correlations

Adiabatic (η) and Joule-Thomson (ε) coefficients:

estimated directly from the pressure and temperature measurements

* See paper SPE-185817 for more detail

17

Solutions and Workflows Used*


Radial flow models applied to well A. The corresponding TTA solutions were used as follows:

1. The temperature slopes were used to estimate the kh values for each zone

2. The damage radius and permeability kdam were also reliably estimated using temperature,

because the rate at which the radius of investigation for temperature increases in well A is ~200

times slower than for pressure.

3. These parameters were then used in a zonal Productivity Index model to calculate zonal Pis

Further, combined with the basic wellbore pressure measurements (no PTA) the above estimates of

zonal PIs were used to

4. Estimate zonal pressures (zonal shut-in is not required)

5. Reliably allocate zonal flow rates or flow rate changes

* See paper SPE-185817 for more detail

18

“Traditional” Pressure based Well Surveillance

that was Used in Well A to confirm TTA results


Combining TTA with “Traditional PBU/PDD” methods “Adds Value” by:

1. Confirmation of TTA results.

2. Well monitoring, reservoir characterization & flow rate allocation, e.g.:

a. Zonal PBUs

b. Nodal analysis, multi-layer/zone, wellbore model used routinely.

Measure stabilised pressures and total Qwell for various combinations of ICV positions and

estimate:

Zonal PI or Pres for each zone & solve 𝑄𝑤𝑒𝑙𝑙 = 𝑖=13 𝑃𝐼𝑖(𝑃𝑟𝑒𝑠,𝑖 − 𝑃𝑎𝑛𝑛,𝑖)

c. 𝛥𝑃𝐼𝐶𝑉* used for virtual flow metering: 𝛥𝑃𝐼𝐶𝑉 =𝛾⋅𝑞2

𝐶𝑉2

where CV for each ICV position provided by the ICV manufacturer

*𝛥𝑃𝐼𝐶𝑉 must be sufficiently large.

19

Outline





• Conclusions


20

Top Zone (Zone 1) TTA: an event (instantaneous

increase in q1) generated by Zone 2 closure


Selected Findings and Observations:

Instantaneous temperature

jump in Zone 2 after shows

that the zone is cleaned up. It

is also used to estimate fluid

thermal props

The Zone 1 slopes ratio is

used to estimate fluid thermal

props

Further, the Zone 1 T slope

analysis gives kh estimate of

75 D*ft. (matches the (earlier)

PBU result of 71 D*ft!)

The damage zone (radius,

permeability) is also described

using TTA (unique result)

Zone 2 TDD and Zone 1 TBU

22

Well A Results:


Zone 1 (Upper

Punt)

Zone 2 (Lower

Punt)

Zone 3

(Burns)

kh damage zone,

mD.ft

7,000 2,000 1,000

kh original, mD.ft 75,000 22,000 n/a

Damage radius 1ft 1ft > 3 ft

Damage skin 3 6 n/a

Zone clean during

test?

Yes Yes No

Zonal TTA results:

Zonal PBU results:

Zone 1 (Upper

Punt)

Zone 2 (Lower

Punt)

Zone 3 (Burns)

kh, mD.ft 71,000 19,000 – 29,000 3,000 – 15,000

Total skin +0.9 approx. -1 + 2 to -3

PI,

bbls/day/psi

34.6 15.4 4.3

Major results:

a. KH values from TTA & PBU data analyses agree

b. TTA uniquely provides depth and permeability of formation damage zone

c. Zonal shut-ins also used for well clean-up quality monitoring

Formed the basis of comprehensive guidelines for implementing TTA (+data

sampling, metrology & test design) by project sponsors

75.7

75.8

75.9

76

76.1

76.2

76.3

76.4

76.5

100 1000 10000

T, C

elapsed time, s

Ta2

Zone 2 TDD

171.7

171.75

171.8

171.85

171.9

171.95

172

172.05

172.1

172.15

1 10 100 1000 10000

T,

F

elapsed time, s

Ta3

1700

1800

1900

2000

2100

2200

2300

2400

0 1000 2000 3000 4000 5000

Axi

s T

itle

elapsed time, s

Pa3

Pa3

Zone 3 TDD

23

Simultaneous, Multi-zone TTA


1. Simultaneous analysis (flow profiling) of multiple zones from a single

transient is a unique to TTA.

Downhole flow control (incl. zonal shut-ins) is not required

2. Thermal contribution of each zone =

the total, thermal contribution –

the combined contribution of all upstream zones.

3. Solutions for temperature slopes allows:

Ignoring thermal mixing and wellbore heat flow effects

Extracting sand face slopes for each zone from one event

24

Verification of simultaneous analysis of multiple

zones - by comparing zonal derivatives


146.5

147

147.5

148

148.5

149

149.5

77.86

77.865

77.87

77.875

77.88

77.885

77.89

77.895

77.9

1 10 100 1000 10000

P, b

ar

T, C

elapsed time after the latest ICV3 movement, s

Ta3 Pa3

Zone 3 TDD and PDD

76.08

76.09

76.1

76.11

76.12

76.13

76.14

76.15

76.16

76.17

76.96

76.98

77

77.02

77.04

77.06

77.08

77.1

77.12

77.14

77.16

1 10 100 1000 10000

T1,

C

T2,

C

elapsed time, s

Ta2 Ta1

Zone 1 and 2 TDD

TTA predicted ratio of zonal rates: Δq1:Δq2:Δq3 = 19:7:20

PBU predicted ratio of zonal rates: Δq1:Δq2:Δq3 = 20:8:20

This unique ability of TTA to profile reservoir properties, or rates, from a single

transient without the need for zonal closure also applies to conventional wells

25

Outline





• Conclusions


26

Conclusions


1. Practical field application of TTA solutions to wells equipped with high-precision in-well monitoring

and zonal control confirmed

2. Input fluid property data derived directly from TTA data set

3. TTA reliably estimated zonal flow rates, formation damage zone properties and well clean-up

parameters.

4. TTA solution accuracy of ± 5-20% for this field’s data set

• Results uniquely verified by other data sources.

5. TTA also suited to interval-by-interval Temperature analysis for flow and Kh profiling of

conventional wells.

6. TTA has “stand-alone” workflow or combined with PTA

• TTA can reduce the number of well or zonal flow tests by ≥ 50%

• Compensates for failed ICVs / sensors.

27

Analysis of In-Well Temperature Data:

The Future


Multiple methods for interpretation and well

test design steady-state (DTS) and transient

(FBG, PDG, ATS) pressure & temperature

(both) for smart and conventional wells

producing either liquids or gas.

Latest “Value from Advanced Wells” JIP starting shortly, will develop:

1. In-well monitoring and data interpretation Theme

- Integrated, Pressure and Temperature Transient data analysis for gas-liquid

production wells

- DTS interpretation methods for oil and gas wells

- Data mining of in-well measurements and

2. Modelling and Optimisation Theme

- Maximise “Added Value” from downhole flow control completions

P+

T T

ran

sie

nt A

na

lysis

Liquids

Numerical

Analytical

GasNumerical

Analytical

28

Acknowledgements / Thank You / Questions


Khafiz Muradov would like to thank the 2014-2016 sponsors of the

“Value from Advanced Wells” Joint Industry Project,

who promote the development of monitoring, control, design, and modelling

methodologies for smart wells:

Nexen; Woodside; Statoil; Petrobras; Husky Energy

We also thank Nexen Petroleum U.K. Limited and the Golden Eagle

Development Co-venturers for permission to present the field data:

• Maersk Oil North Sea U.K. Limited

• Suncor Energy UK Limited

• DYAS EOG Limited

• Oranje-Nassau Energy Petroleum Limited

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