Skoči na glavni sadržaj

Nafta i Plin, Vol. 39 No. 159. - 160., 2019.

Stručni rad

Determining the potential of geothermal reservoirs with dissolved hydrocarbon gas

Marko Gaćina ; INA-Industrija nafte, d.d., Zagreb
Maja Gregurić-Malekoci ; INA-Industrija nafte, d.d., Zagreb
Adaleta Perković orcid id orcid.org/0009-0005-7301-2146 ; INA-Industrija nafte, d.d., Zagreb
Jasmina Jelić-Balta ; INA-Industrija nafte, d.d., Zagreb

Puni tekst: engleski pdf 1.709 Kb

str. 99-109

preuzimanja: 49

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Sažetak

Since development and growth of geothermal energy is closely related to oil industry, in this paper we evaluate the possibility of geothermal reservoir production in which, in addition to water, a reservoir contains dissolved gas composed mostly of methane and carbon dioxide. Such gas could increase the cost-effectiveness of the development of a geothermal project, especially in its beginnings. The main focus of this work is to provide the required technical parameters such that a techno-economic analysis could be made for the cost-effectiveness of a geothermal project which utilizes pre-existing boreholes, made initially for hydrocarbon exploration. The study utilizes seismic data which was used to determine the reservoir area, well log data for the assessment of various lithologies, layer thicknesses and their porosities. Furthermore, DST analyses were observed from which can be seen that specific layers were saturated with water and gas and the proportion of carbon dioxide and hydrocarbon components varies according to reservoir depth. Since we are dealing with the gas originally dissolved in water, it was necessary to create a reservoir simulation model in order to determine its recovery factor while simultaneously producing gas saturated water and injecting degassed water. Different simulation cases were carried out, covering MIN, MAX and MED petrophysical datasets and are compared to the results of the previously created Monte Carlo model. In addition to the total gas recovery, we also considered the behavior of the reservoir pressure and temperature in a project lifetime of 30 years.

Ključne riječi

Hydrocarbon gas; geothermal energy; reservoir simulation; Monte Carlo method

Hrčak ID:

329301

URI

https://hrcak.srce.hr/329301

Datum izdavanja:

21.10.2019.

Podaci na drugim jezicima: hrvatski

Posjeta: 237 *

Publication date: 10 September 2019

Volume: 39

Issue: 159. - 160.

Pages: 99-109

DOI:

Article Information (continued)

Categories:

Subject: Stručni rad

Categories:

Subject: Professional Paper

Keywords:

Keyword: ugljikovodični plin

Keyword: geotermalna energija

Keyword: ležišna simulacija

Keyword: Monte Carlo metoda

Keywords:

Keyword: Hydrocarbon gas

Keyword: geothermal energy

Keyword: reservoir simulation

Keyword: Monte Carlo method

Određivanje potencijala geotermalnih ležištas otopljenim ugljikovodičnim plinom

Translated Title (en): Determining the potential of geothermal reservoirs with dissolved hydrocarbon gas

[ORCID] Marko Gaćina[1]

Email: marko.gacina@ina.hr

 

INA-Industrija nafte, d.d., Zagreb INA-Industrija nafte, d.d., Zagreb Av. Većeslava Holjevca 10, 10000, Zagreb

[ORCID] Marko Gaćina[*][1]

 

INA-Industrija nafte, d.d., Zagreb INA-Industrija nafte, d.d., Zagreb Av. Većeslava Holjevca 10, 10000, Zagreb

[ORCID] Maja Gregurić-Malekoci[1][1]

 

INA-Industrija nafte, d.d., Zagreb INA-Industrija nafte, d.d., Zagreb Av. Većeslava Holjevca 10, 10000, Zagreb

[ORCID] Adaleta Perković[2][2]

 

INA-Industrija nafte, d.d., Zagreb INA-Industrija nafte, d.d., Zagreb Av. Većeslava Holjevca 10, 10000, Zagreb

[ORCID] Jasmina Jelić-Balta[3][3]

 

INA-Industrija nafte, d.d., Zagreb INA-Industrija nafte, d.d., Zagreb Av. Većeslava Holjevca 10, 10000, Zagreb

Author notes:

Correspondence to: [*] AMarko Gaćina, INA-Industrija nafte, d.d., Zagreb, Av. Većeslava Holjevca 10, 10000, Zagreb marko.gacina@ina.hr

Abstract

S obzirom da je rast i razvoj geotermalne energije usko povezan i s naftnom industrijom, u radu je evaluirana mogućnost iskorištavanja geotermalnih ležišta gdje osim vode, u ležištu postoji i određena količina otopljenog plina koji u svom sastavu sadrži i ugljikovodike. Uloga takvog plina mogla bi biti značajna u podizanju rentabilnosti razvoja geotermalnog projekta, posebno u njegovom začetku. Glavni cilj rada je dati potrebne tehničke parametre kako bi se mogla izvršiti tehno-ekonomska analiza geotermalnog projekta koji se koristi već izbušenim bušotinama, rađenim za potrebe istraživanja ugljikovodika. U radu su korišteni seizmički podaci uz pomoć kojih je određena površina ležišta, bušotinski (karotažni) podaci za određivanje pojedinih litologija i debljina slojeva te njihove poroznosti. Također, korištena su i DST ispitivanja iz kojih je potvrđeno da su određeni slojevi zasićeni osim vode i s plinom u kojem udio ugljičnog dioksida i ugljikovodičnih komponenti varira ovisno o ispitivanom sloju. Obzirom da se radi o plinu otopljenom u vodi, potrebno je bilo upotrebom ležišne simulacije odrediti njegov iscrpak pri simultanoj proizvodnji plinom zasićene vode te utiskivanju degazirane. Provedeni su različiti simulacijski slučajevi koji pokrivaju MIN, MAX i MED petrofizikalne setove podataka te su uspoređeni s rezultatima prethodno kreiranog Monte Carlo modela. Osim ukupnog iscrpka plina, razmatrano je i ponašanje ležišnog tlaka i temperature u projektnom razdoblju od 30 godina.

Translated Abstract

Since development and growth of geothermal energy is closely related to oil industry, in this paper we evaluate the possibility of geothermal reservoir production in which, in addition to water, a reservoir contains dissolved gas composed mostly of methane and carbon dioxide. Such gas could increase the cost-effectiveness of the development of a geothermal project, especially in its beginnings. The main focus of this work is to provide the required technical parameters such that a techno-economic analysis could be made for the cost-effectiveness of a geothermal project which utilizes pre-existing boreholes, made initially for hydrocarbon exploration. The study utilizes seismic data which was used to determine the reservoir area, well log data for the assessment of various lithologies, layer thicknesses and their porosities. Furthermore, DST analyses were observed from which can be seen that specific layers were saturated with water and gas and the proportion of carbon dioxide and hydrocarbon components varies according to reservoir depth. Since we are dealing with the gas originally dissolved in water, it was necessary to create a reservoir simulation model in order to determine its recovery factor while simultaneously producing gas saturated water and injecting degassed water. Different simulation cases were carried out, covering MIN, MAX and MED petrophysical datasets and are compared to the results of the previously created Monte Carlo model. In addition to the total gas recovery, we also considered the behavior of the reservoir pressure and temperature in a project lifetime of 30 years.

Introduction

Besides water, deeper geothermal reservoirs always contain some amount of dissolved gas. Usually, the gas composition is mostly carbon dioxide but sometimes it is enriched with lighter hydrocarbons, namely methane. Those hydrocarbons could potentially be of a great interest if their amount is significant which is mostly related to the pressure and temperature conditions in the reservoir and water production rates. In this work, we have considered a potential geothermal reservoir located in the Croatian part of the Pannonian basin for which data collected during a well DST performance was available as well as petrophysical data, gas and water analyses and geological and seismic studies. The prospect was explored during the 1980s in order to find oil and gas reserves. Data collected served for the initialization of the conceptual reservoir simulation models. Considering very high investment needs at the beginning of every geothermal project, namely drilling wells and building the power plant, additional income coming from the hydrocarbon gas could have a key role in project economics and investment return rate.

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