Member Info for SEA7

yes they mention 1TCM gas in that research

thanks thordon

thanks bobby - some good info on x1b, seeing as we haven't got much to go on!

although to be fair, i doubt each and everyone were involved in the specific areas covered, as the document does cover many other oil producing areas! should have stated that!!

those present at this AAPG get together back in september 2019 in Batmui Georgia

schlumberger
block energy
georgian oil and gas corp
georgia oil and gas ltd
omv petroleum

and others.

involved in below research..

Dr. Aix-Marseille University
Researcher ANAS Institute of Geography named after academician Hasan Aliyev
Principal Geologist ArcGeoLink Ltd
Mr. Arili+Director Blackbourn Geoconsulting
Non Executive Chairman Block Energy Plc
Chief Executive Of?cer Block Energy Plc
Technical Director Block Energy Plc
Financial Manager Block Energy Plc
Exploration Advisor BP
Petroleum Systems Analyst BP
Geologist CASP
Geologist CASP
Geologist CASP
Chief Geologist CASP
President / Ceo Caspian Well Services Ltd
Executive Chairman CEEC SG Executive Committee
Sales Geoscientist CGG
Technical Manager CGG Robertson
Director Of Research CNRS Université Côte d’Azur
Prof. Dr. Department of Geosciences - Univ. Fribourg
Master Student Department of Geosciences Univ. Fribourg (Switzerland)
Phd Student Eötvös Loránd University
Geologist ExxonMobil
Business Development Advisor For Europe/Caspian/Mena ExxonMobil
Geoscientist ExxonMobil International Limited
New Opportunities Manager ExxonMobil International Ltd
Geologist ExxonMobil International Ltd
Petrophysicist Ferdowsi university of mashhad
Geologist Freelance geologist
Geologist Freelance geologist
Member Of The Management Board Geogals
Leading Research Scientist Geology and Geophysics Institute of Azerbaijan National Academy of Sciences
Dr. Geophysics
Consultant Georgia Oil & Gas
Chief Advisor For Exploration Georgian Oil and Gas Ltd

and others

High Gamma Ray values (140-150 GAPI) observed in front of some reservoirs are associated with the presence of potassium and sodium feldspars (might be zircon as trace mineral) determined from LithoScanner data. To support the ELAN formation evaluation results, especially in the best porous zone, XRD, XRF and SEM analysis was performed for whole Middle Eocene section’s cutting at 5m sampling interval. The XRD results suggest that the reservoir layers with high GR readings show high content of feldspar (52%), which are relatively higher compared with to most of the Middle Eocene intervals. The correlation of high GR peak indicates good lateral distribution in the wells drilled on Patardzeuli ?eld. The high GR peaks are considered as a good indicator of presence of porous layers. In terms of oil production enhancement, this information serves as an important discriminator for well workover candidates’ selection and for further operation planning.

The Samgori-Patardzeuli Field Middle Eocene Petrophysical Properties And Reservoir Mineralogy Composition Based On Open Hole Logging Formation Evaluation And Cuttings

Xrd – Xrf AnalysisJ. Urazaliev, T. T. Yildiz, A. Orlov, D. Tsaplin, A. Goloborodko, S. Tirumanapalli, Schlumberger - A. Suter, Retired Schlumberger Employee

The Samgori-Patardzeuli ?eld in Block XIB has been the main producing ?eld in Georgia since 1970s when discoveries were made in Samgori, Samgori South Dome, Teleti, and Krtsanisi ?elds. The oil reservoirs are Middle Eocene volcaniclastic rocks deposited in the Kura Basin. The Middle Eocene deposits consist primarily of volcanogenic-sedimentary rocks including tuffaceous siltstones, phyllites and argillites. In the reservoir zones, fractures enhance permeability and caverns are observed predominantly along the fracture’s zones. Analysis of the core matrix shows relatively low effective porosity (average 3.9%) and is practically impermeable. Core permeability s varies from 0.001 mD to 0.1 mD, and one validated sample shows up to 2 mD. Samples with higher permeability are characterized by developed secondary porosity. This is supporting that oil production comes mainly from highly distributed fractures associated with matrix porosity.

During drilling of Middle Eocene formation in PAT-E1 well (12.25in hole section), advanced wireline logging was performed. The logging suite included PEX (HRLA, NEUT, DEN, Spectral GR, HD Caliper, GPIT), CMR, FMI, Sonic Scanner and LithoScanner. An ELAN multimineral model was built using dry weight elements of LithoScanner data and open hole logs: Bulk Density, Neutron Porosity, Compressional Slowness, Spectral Gamma Ray data. The Density and Neutron Porosity measurements were used for porosity computation. The NMR porosity was used as a guide in qualitative level as it is independent of lithology. The Spectral Gamma Ray data (potassium and thorium concentrations) along with elements’ dry weights were used for clay volume computation. As per the ELAN evaluation, the average effective log porosity is 4.4%, which is close to the value of effective porosity obtained from core study.

In the upper part of the Middle Eocene formation GR shows high reading while Neutron-Density logs is showing crossover, which is indicating presence of clean reservoir with an average effective porosity of 8 to 10%, an average water saturation of ~50%, a clay volume of 0-10% and a permeability of 22-140 mD. For validation of permeability values obtained from ELAN and CMR logs, the Sonic Scanner Stoneley mobility analysis was conducted, which shows that Stoneley mobility is comparable with ELAN derived KINT permeability (Mobility < KINT) and CMR computed KTIM permeability (Mobility > KTIM).

continued....

Organic geochemical studies proved that Samgori, South Dome, Patarzeuli, Ninotsminda, Norio and Satskhenisi ?elds were sourced mainly from the Maikop and with some contributions from the Upper Eocene source rocks of the Norio kitchen to the north.

Jointly these ?elds have produced more than 200 mmbbls. The quantitative basin modeling study shows that peak oil generation have started at about 3.6 mabp and gas at 1.7 mabp at depths of 3,600 m to 4,700 m and 4,350 m to 6,100 m, respectively. To the south of the thrusts, oil and gas generation occurred at much shallower depths due to hot water circulation. The rapid generation of oil and gas in the shaly Cenozoic source rocks led to abnormal pressure formation and opening up additional pore space by fracturing and reduction of kerogen volume. Self-propagating microfractures resulted in high primary migration volumes to enter into the strike slip faults formed at the time of thrust activity from the Middle Pliocene to Late Pleistocene. The effective oil migration took place at past peak oil generation and, thus, oils in the ?elds are generally light, more than 34 degrees API, and with high gas content. Except for the Ninotsminda ?eld, the gases in the oil ?elds are biodegraded. There is a continuous gas leak into the Ninotsminda structure from the north.

The computed most likely recoverable oil resources are 812 mmbbls and 365 mmbbls were already discovered during the Soviet Era. Most likely recoverable gas resources are 1.2 Tcm and this gas has not been explored yet.

The Upper Cretaceous sediments are clearly distinguished by a drastic change in lithology where marls are replaced by limestone. The porosity evaluated in the Upper Cretaceous sediments is very low (1.0-1.5%). According to the FMI log data, fractures are identi?ed throughout the entire Upper Cretaceous section. The fracture properties are different from the Lower Eocene sediments, as they show lower value of aperture (<0.015 mm) and a wider spread of fracture dips angles (6 to 90 degrees). The drilled thickness of Upper Cretaceous sediments in PAT-E1 well is 291 m. The Upper Cretaceous sediments and the lower part of the Paleocene were tested together in 5.875 in open hole section within 4558-5020 m MD interval. The gas flow rate for this interval ranged from 1400 to 3400 m3/day. The formation pressure gradient obtained in the open hole section is 1.45 SG, which corresponds to an over pressured Upper Cretace ous zone and con?rms the good cap rock proper-ties of Paleocene formation. Similar gas flow rates (6000 - 7400 m3/day) were obtained when testing the Upper Cretaceous sediments in the TLT-55 well. Legacy well test in Teleti ?eld and the presence of over pressure zone in PAT-E1 well suggesting potential for commercial gas accumulation analogue Upper Cretaceous of Patardzeuli structure.

Block XIB Lower Eocene, Paleocene, Upper Cretaceous formation characteristics and hydrocarbon potential

J. Urazaliev, T. T. Yildiz, A. Orlov, A. Carrillat, D. Tsaplin, A. Goloborodko, S. Tirumanapalli, Schlumberger - A. Suter, Retired Schlumberger Employee

Block XIB lies in the Kura basin of East Georgia, between the Greater Caucasus Mountains to the north and the Lesser Caucasus to the south. Historically, the block has been explored through the 1970s and 1980s and six oil ?elds have been producing from Middle and Upper Eocene reservoirs.

The Upper Cretaceous, Paleocene and Lower Eocene plays of Georgia are relatively poorly understood. Several wells were drilled on Teleti ?eld targeting Upper Cretaceous. One well (TLT-55) tested gas from Upper Cretaceous-Paleocene interval at rates between 6000 – 7400 m3/d. The well report of TLT-11 indicates a gas blow-out while drilling of Upper Cretaceous sediments at the depth 2700 m MD. The gas flow rate recorded was up to 250 000 m3/day, which suggests potential for commercial gas accumulation in the Upper Cretaceous reservoirs. The Lower Eocene gas play has been tested by ?ve wells in Samgori ?eld, with total production of 29.96 MMSCM in 4 wells during 1990 - 2000. As part of the Lower Eocene play evalua-tion, the neighboring Patardzeuli structure was drilled in 2018 (PAT-E1). The results of drilling and testing of the PAT-E1 well allowed to signi?cantly improve our understanding of Lower Eocene, Paleocene and the Upper Cretaceous formations. While drilling the 8.5 in and 5.875 in open hole sections, mudlogging, cutting sampling and its description, as well as high-reso-lution gas chromatography analysis was continuously performed. Advanced open hole logging including PEX, CMR, FMI, Sonic Scanner and LithoScanner were recorded in those sections to de?ne test intervals. The analysis and integrated inter-pretation of all the available data allowed us to compile a lithology-petrophysical model of the Lower Eocene, Paleocene and Upper Cretaceous formation with a clear identi?cation and justi?cation of their boundaries. In accordance with the log data obtained, the thickness of the Lower Eocene deposits in the PAT-E1 well is 1171 m, the effective porosity of reservoir layers varying from 4 to 16%. FMI logs show the presence of open fractures throughout the Lower Eocene section with clusters of high fracture density.

The Paleocene sediments show a total thickness of 665 m and are distinguished by a monotonous stratum of marls with thin streaks of mudstones and limestones. The effective porosity of the Paleocene formation is very low (1-3%) and shows no permeability. These rocks could be considered as a good cap rocks for the Upper Cretaceous formation. Despite the absence of porous rocks in the Paleocene sediments, signi?cant gas shows were recorded during drilling. These shows correspond to localized fractured zones which identi?ed in FMI log data. continued....

The same observation is made from analogue ?eld Ninotsminda located to the northeast of Patardzeuli where horizontal wells drilled at an angle to the fold hinge showed better production.Novel/Additive Information: The novel aspect of this project is the multi-scale approach rooted in seismic interpretation from newly reprocessed 3D PSDM seismic data, mapped regional structural trends, detailed fault imaging and interpretation, FMI log analysis combined together with Schlumberger’s advanced logging suite from PAT-E1 to determine the orientation of flow contributing fractures for optimizing well testing and design.

https://www.researchgate.net/publication/336141896_AAPG_GTW_Exploration_and_Production_in_the_Black_Sea_Caucasus_and_Caspian_Region

Middle Eocene fracture analysis for Block XIB:
Case Study from Patardzeuli Field, GeorgiaA. Orlov, A. Carrillat, T. T. Yildiz, D. Tsaplin, J. Urazaliev., A. Goloborodko, S. Tirumanapalli, Schlumberger

Objective and Scope: In the Kura fold and thrust belt, the Middle Eocene volcaniclastic rocks exhibit both low porosity and the absence of a matrix permeability. This is conflicting with the high production rates observed in the Patardzeuli ?eld. High losses of drilling fluids are observed during drilling and FMI reveals clusters of fractures suggesting a naturally fractured reservoir type 1. This study aims at using an integrated approach spanning from seismic interpretation to FMI log data analysis to identify the fractures contributing to the hydrocarbon flow and to provide the basis of design of an optimum well.

Methods, Procedures, Process: This integrated study uses borehole image log data (FMI) acquired in the Middle Eocene interval of the PAT-E1 exploration well. The main steps of the workflow were: 1) to carry out an interpretation of the FMI image for fractures identi?cation, 2) to classify the fractures as open, closed or healed and de?ne a hydrocarbon flow indicator by calibrating the fracture analysis to hydrocarbon flow zones (gas shows), and 3) to review this analysis in the context of the seismic structural interpretation and regional tectonic framework. The reprocessing and depth migration of the 3D seismic data allowed a detailed interpretation and improved image of subtle features supporting the ?eld observations and outcrop data.

Results, Observations, Conclusions: The results of the FMI interpretation for the Middle Eocene fractured volcaniclastic reservoir were used to identify hydrocar-bon flow zones (in absence of PLT data). The analysis of open fractures orientation, dip, aperture together with ?eld obser-vations, petrophysical data, seismic interpretation, paleo- and current stress regimes enabled to determine the fracture type associated with potential hydrocarbon flowing zones and their occurrence in the Middle Eocene interval. The analysis reveals that not all open fractures identifed on image log are effectively contributing to hydrocarbon flow. Accordingly, the selection of testing intervals on the basis of the highest density of fractures only is not a valid approach to determine prospective zones. It is observed that the best hydrocarbon zones are those where both open fractures and some matrix porosity is identi?ed from the petrophysical interpretation. From a structural point of view, in the current strike slip regime, fracture direction and dip are the main control to hydrocarbon flow with best contribution coming from open fractures oriented near orthogonal to the fold hinge of the field anticlinal structure. continue.d...

https://www.linkedin.com/in/jenis-urazaliev-14b94a32

enior Exploration Geologist
Dec 2017 – Present2 years 9 months

Tbilisi, Georgia

Schlumberger Rustaveli Company Limited, Georgia
Oil production increment from Middle Eocene highly fractured volcano-clastic reservoir and Lower Eocene fractured carbonate gas appraisal program on Block XI-B of Georgia (Kura basin).

Operations Geologist
Feb 2017 – Nov 201710 months

Tashkent, Tbilisi

Schlumberger Rustaveli Company Limited, Georgia
Oil production enhancement and gas appraisal program on Block XI-B of Georgia.

thanks badger

they will be holding for a buyout of block at a later date, when it is further along its development curve and someone goes exploring in the market for producing assets with reserves, rather than underground

i was buying at 1.05p - still hold them -

perhaps someone knows something...up 24%

on the move - up 6%

see a late reported 250k share buy showed up - probably see a few more of them

difference is that the tailings is a jv and not solely down to LC to get over the line. He has other influences driving this forward and that does make a difference.