Dler Baban - Academia.edu (original) (raw)

Papers by Dler Baban

Iraqi geological journal, Nov 29, 2023

The shale content and mode of distribution, along with their impact on the reservoir properties o... more The shale content and mode of distribution, along with their impact on the reservoir properties of the Jeribe Formation, were investigated using the available log data in the two selected wells, NET-10 and NET-12, of an oilfield northern Iraq. The dolomite and dolomitic limestone lithology of the formation contains different ratios of shale, with the highest near the middle part of the formation. Horizons of 70 to 99% shale content were identified, but the general ratios are ranging between 10% and 50%. The data from the Spectral Gamma ray log revealed that the shale content of the formation is mostly composed of low Potassium minerals such as Chlorite and Montimorlinite, with appreciable percentages of Illite. The low Th/U ratios along the formation indicated a reduced condition of deposition except for about 2-3 meters of the upper part of the formation in the well NET-10, which looks to be precipitated in a natural depositional environment. Dispersed, Laminar, and Structural modes of shale distribution coexist within the formation in both studied wells. As the different modes of shale distribution have different impacts on the porosity and permeability of the reservoir rocks, the decrease and increase in the shale content did not perfectly correspond with an opposite fluctuation in the porosity values of the formation. The shale content in the formation has an impact on the porosity calculation by overestimating it by about 4-5% and subsequently underestimating the water saturation by 9% in the well NET-10 and 7% in the well NET-12.

Iraqi geological journal, Jun 30, 2023

The flow capacity of the Lower Miocene Jeribe Formation was investigated in the two selected well... more The flow capacity of the Lower Miocene Jeribe Formation was investigated in the two selected wells, A and B, of an oilfield northeast of Tikrit City. The available wireline logs and core test data are adapted for characterizing the reservoir potentiality of the formation. Three Hydraulic Flow Units was identified by calculating the values of the Flow Zone Indicators. Most parts of the formation parts have the lowest flow capacity among the three determined flow types. The Jeribe Formation contains hydrocarbons in various ratios in both wells of the study. The Reservoir Unit RUJ-1 at the upper part of the formation has the highest moveable hydrocarbon saturation, especially in the well A. Most hydrocarbons in the RUJ-3 at the lower part of the formation in both wells are immoveable. The oilwater contact was expected within Dhiban Formation in the well B and was expected to be somewhere in the underlying Dhiban or Euphrates Formations in the well A. The nature of the hydrocarbons at the uppermost few meters of the formation consists of gas or light hydrocarbons and oil at the rest of the formation(residual and moveable oils).

Iraqi geological journal, Jun 30, 2023

The effect of Cementation Exponent has been investigated on the calculated water and hydrocarbon ... more The effect of Cementation Exponent has been investigated on the calculated water and hydrocarbon saturations and the estimated oil initially in place. The Aptian Lower Qamchuqa (Shua'iba) Formation from the well BH-96, Bai Hassan Oilfield, is used as a case study. Four different values of Cementation Exponent were applied in calculating water saturation using the Archie equation. The static value of 2 commonly used for carbonate reservoirs was one of the cases used to calculate an average of 68% water saturation. In the second case, the value of 1.81 is used for m based on the average m values obtained through testing 22 core samples in the laboratory. The average of 60.5% Sw was calculated for the studied part of the Lower Qamchuqa Formation in this case. The Pickett plot method was used as a third case, and 1.65 was estimated as the m value through which the average of 54% Sw was calculated. In the fourth case, variable values of m were used for the different depth intervals from which core samples were tested in the laboratory. In this case, the calculated average water saturation was equal to 60%. The upper part of the studied section was generally of low porosity and high water saturation, whereas the middle and the lower parts contained hydrocarbons with different saturations. Using shale content, porosity, permeability, and water saturation cutoffs for the four different cases, the net to gross pay ratios were calculated. The ratios ranged between 56.5% in the case of using the 1.65 value of m and 47.6% in the case of using variable core tested m values, and accordingly, the difference of about 4 m in net thickness is expected to be underestimated or overestimated, respectively, when is calculated.

Arabian Journal of Geosciences, Oct 3, 2013

The organic matter content of the Paleocene Aaliji Formation has been studied from the Qm-1 well ... more The organic matter content of the Paleocene Aaliji Formation has been studied from the Qm-1 well in the Qumar Oil Field, NE Iraq. A palynofacies analysis revealed the obvious domination of amorphous organic matter (AOM) in the samples studied in addition to the different ratios of palynomorphs, phytoclasts and opaque organic material. The deposition of the various percentages of organic matter components and types of palynomorphs appear to have occurred in a proximal suboxic-anoxic basinal environment. The samples analysed showed relatively low percentages of total organic carbon, indicating a generally poor source rock. The thermal alteration index for the palynomorphs (dinoflagellates) observed and identified ranged between 2, 2+ and 3−, indicating an immature to early stage of maturity for the section studied. No clear differentiation between the stages of maturity within the section was identified. The reflectance measured for a few vitrinite particles at a depth of 2,900 m showed uncertainly of 0.46 % Ro, indicating a still thermally immature stage. The values obtained from pyrolysis analysis also supported the formation being in the early stages of maturity, i.e. an immature condition, with T max values between 416 and 435°C. The quality of the organic matter examined and analysed appeared to be mostly type III gas-prone kerogen, as discerned from the hydrogen index, oxygen index and other pyrolysis parameters. The parameters obtained and calculated from gas chromatography analysis performed on a sample at a depth of 2,900 m found marginally mature marine source organic matter.

Arabian Journal of Geosciences, Apr 9, 2013

Ten samples from the Upper Jurassic Naokelekan and Barsarin Formations in an outcrop section near... more Ten samples from the Upper Jurassic Naokelekan and Barsarin Formations in an outcrop section near Sargelu Village were studied to evaluate their thermal maturity using vitrinite reflectance method. The studied beds appeared to be mature and within the oil generation window (0.79-1.25 % vitrinite reflectance in immersion oil (Ro)). Some of the reflectance histograms showed bimodal distribution indicating existence of nonindigenous populations which were all ignored during the measurements of the mean value of Ro. Comparison between the results obtained from vitrinite reflectance method and some other methods like pyrolysis and gas chromatography showed variations which finally more reality believed to be for the vitrinite reflectance method.

Arabian Journal of Geosciences, Dec 1, 2017

The Lower Miocene Euphrates and Jeribe formations are considered as the main targets of the Terti... more The Lower Miocene Euphrates and Jeribe formations are considered as the main targets of the Tertiary petroleum system in the western part of the Zagros Basin. The formations consist of carbonates with some evaporate intercalations of the Dhiban Formation. This study utilized data from a field investigation including newly described outcrop sections, newly discovered productive oil fields within the Kirkuk embayment zone of the Zagros Fold and Thrust belt such as Sarqala and Kurdamir wells. This work is the first to show a stratigraphic correlation and palaeoenvironmental interpretation by investigating both well data and new outcrop data. Three depositional environments were identified, an: 1. Inner and outer ramp belts environment; 2. shoal environment; and 3. restricted lagoon environment. Within these three environments twelve microfacies were identified, based on the distribution of fauna mainly benthonic foraminifera, rock textures and sedimentary structures. The inferred shallow water depths and variable salinities in both the Euphrates Formation and Jeribe formation carbonates are consistent with deposition on the inner ramp (restricted lagoon and shoal) environments. Those found in the Euphrates Formation constrained the depositional environment to the restricted lagoon and shoal environment, whilst the microfacies in the Jeribe Formation provided evidence for an inner ramp and middle to outer ramp belt environments. This study represents the first detailed research that focuses on the stratigraphic correlation and changes in carbonate facies with the main aim to provide a wider understanding of stratigraphy of these carbonate reservoirs throughout the northern part of Iraq.

73rd EAGE Conference and Exhibition incorporating SPE EUROPEC 2011, May 23, 2011

The organic matter content of the Paleocene Aaliji Formation has been studied from the Qm-1 well ... more The organic matter content of the Paleocene Aaliji Formation has been studied from the Qm-1 well in the Qumar Oil Field, NE Iraq. A palynofacies analysis revealed the obvious domination of amorphous organic matter (AOM) in the samples studied in addition to the different ratios of palynomorphs, phytoclasts and opaque organic material. The deposition of the various percentages of organic matter components and types of palynomorphs appear to have occurred in a proximal suboxic–anoxic basinal environment. The samples analysed showed relatively low percentages of total organic carbon, indicating a generally poor source rock. The thermal alteration index for the palynomorphs (dinoflagellates) observed and identified ranged between 2, 2+ and 3−, indicating an immature to early stage of maturity for the section studied. No clear differentiation between the stages of maturity within the section was identified. The reflectance measured for a few vitrinite particles at a depth of 2,900 m showed uncertainly of 0.46 % Ro, indicating a still thermally immature stage. The values obtained from pyrolysis analysis also supported the formation being in the early stages of maturity, i.e. an immature condition, with Tmax values between 416 and 435 °C. The quality of the organic matter examined and analysed appeared to be mostly type III gas-prone kerogen, as discerned from the hydrogen index, oxygen index and other pyrolysis parameters. The parameters obtained and calculated from gas chromatography analysis performed on a sample at a depth of 2,900 m found marginally mature marine source organic matter.

Iraqi journal of science, Jul 31, 2022

The reservoir characterization of Lower Qamchuqa (Shu'aiba) Formation (Aptian) is studied at the ... more The reservoir characterization of Lower Qamchuqa (Shu'aiba) Formation (Aptian) is studied at the well BH-86 of Bai-Hassan Oilfield in Kirkuk area, Northern Iraq. The lithological study (of 91 thin sections) revealed that the formation consists of shaly limestone, a thin bed of marl within the limestone, and dolomitic limestone. Four petrographic microfacies were noticed Lime mudstone microfacies, Dolomudstone microfacies, Lime wackestone microfacies, subdivided into benthonic foraminifera lime wackestone submicrofacies and bioclasts lime wackestone submicrofacies, and the last microfacies is the Lime packstone microfacies, which is subdivided into pelloidal lime packstone submicrofacies and Orbitolina lime packstone microfacies. Shale content is calculated from the gammary log, showing that the formation is mainly of low shale content (less than 35%). The porosity determined from sonic, density, and neutron logs reflect that the range between <1 and 15% and in some intervals about 6% is secondary porosity type. The estimated permeability ranges between <0.01 and 2.0mD, reflecting low permeability. The formation is subdivided into six reservoir units according to the shale content, average porosity, and permeability. The unit RU-5 has the best reservoir properties among the identified units with an average shale content of about 3.15%, about 6.2% porosity, and about 1.75mD average permeability. On the other hand, the least reservoir property is noticed in the unit RU-1 with average 9.48% shale content, 3.64% porosity, and 0.5mD average permeability. The research indicates that the fractures contribute to the flow within the Lower Qamchuqa Formation. Fluids flow through the formation in four unique Hydraulic Flow Units (HFU). Only about 8% of the gross 146m of the formation is expected to have the required reservoir properties for oil production and about 68% for gas production. The actual productive thickness for oil is only about 2.8% of the gross thickness of the studied section, and it's more than 50% of the gross thickness for gas.

گۆڤاری زانکۆی سلێمانی بەشی A, May 17, 2020

Arabian Journal of Geosciences, Apr 24, 2014

The Eocene Jaddala Formation has been studied from source rock potentiality point of view in the ... more The Eocene Jaddala Formation has been studied from source rock potentiality point of view in the well Qm-1, Qumar Oil Field, NE, Iraq. An average of about 2.4 % total organic carbon was measured from the five analyzed samples in this study. The lower part of the formation showed higher organic matter content and represented a deeper depositional environment than the upper part. The quality of the organic matter appeared to be mainly types II with contribution from type III with different ratios. The pyrolysis analysis, vitrinite reflectance technique, and gas chromatography (GC) analysis all indicated the immature state of the Jaddala Formation in the studied section. The thermal history of the formation showed that Jaddala never entered the maturity stage during its burial history.

Iraqi geological journal, Nov 30, 2021

Thirty rock samples were selected from the well Tq-1 that penetrated the Jurassic beds in the Taq... more Thirty rock samples were selected from the well Tq-1 that penetrated the Jurassic beds in the Taq Taq Oilfield to be studied the source rock potentiality of the Sargelu Formation. The formation is characterized by three types of microfacies, namely, foraminiferal packstone, grainstone microfacies, fossiliferous packstone microfacies, and foraminiferal wackestone which were deposited in an environment extending from middle to outer carbonate ramp. An average of 3.03 wt.% of total organic carbon was obtained from a Rock Eval pyrolysis analysis carried out on 24 selected rock samples. The petrographic analysis for such organic matters revealed that they are of kerogen types III and IV and they are currently in a post-mature state. Pyrolysis parameters showed that limited generation potential was remained for these sources to expel generated hydrocarbons. The palynological study showed that Amorphous Organic Matter forms the highest percentage of organic matter components with more than 70%, followed by phytoclasts with 10-25 % and palynomorphs of less than 10%. The organic matters within the Sargelu Formation are deposited at the distal part of the basin under suboxic to anoxic condition. The color of the organic matter components, examined under transmitted light, showed Thermal Alteration Index values between 3+ and 4-. Such values may indicate that these organic matters are thermally at the end of the liquid oil generation zone and beginning of condensate-wet gas generation zone. The thermal maturity of the Sargelu Formation depending on the calculated VRo% revealed that the formation in the studied oilfield is currently at the peak of the oil generation zone. The Sargelu Formation in the studied field is considered as an effective source rock, as it has already generated and expelled hydrocarbons.

Journal of Petroleum Exploration and Production Technology, Jan 15, 2018

Quick look methods (QLM) in log interpretation are helpful to the geologist because they provide ... more Quick look methods (QLM) in log interpretation are helpful to the geologist because they provide flags, or indicators, that point to possible hydrocarbon zones. The importance of QLM is in their ability to provide information about the nature of the fluids in the pore spaces and the lithology of the reservoirs in a quick and simple way. Four ways of QLM are applied on the Middle Miocene Jeribe Formation from the well Ja-49 in Jambour Oilfield. The apparent water resistivity (R wa) method helped in quick detecting the hydrocarbon-bearing zones of the formation. The logarithmic movable oil plot method assisted in detecting the intensity of the movability of the hydrocarbons within the hydrocarbon-bearing zones of the formation. The SP versus R xo /R t overlay is an additional helpful way for detecting water and hydrocarbon-bearing horizons without need to know porosity. movable hydrocarbon index (MHI) is also used as QLM for detecting the movability of the hydrocarbons through calculating the ratio of water saturation in the uninvaded zone to that of the flushed zone. Accordingly, the formation in the studied well appeared to be generally a hydrocarbon-bearing reservoir with zones of different movable hydrocarbon potentiality. The application of MHI method indicated that about 53% of the gross 56 m thickness of the formation contains movable hydrocarbons. The upper and lower 5 m of the formation appear to be containing the most efficient productive horizons. No actual oil water contact is observed in the studied section of Jeribe Formation, which means the oil column extends down to certain depth in the formations underlying Jeribe Formation.

Arabian Journal of Geosciences, Mar 1, 2016

Tertiary reservoir represented by Jeribe, Anah, Azkand, and Azkand/Ibrahim formations has been st... more Tertiary reservoir represented by Jeribe, Anah, Azkand, and Azkand/Ibrahim formations has been studied from reservoir characterization point of view in Khabbaz Oil Field/Northern Iraq. Examined thin sections prepared from core rock samples which are selected from the wells Kz-8 and Kz-9 revealed the existence of different microfacies in which are varies types of porosity such as interparticle, intraparticle, moldic, vuggy, and fractures have been noticed. In addition to these different types of diagenetic features are represented mainly by cementation, dolomitization, recrystallization, and dissolution. The available log data for the wells Kz-11, Kz-14, and Kz-16 have been used in characterizing the reservoir properties of the studied formations. The detected lithologies from porosity logs showed domination of limestone, dolomitic limestone, and dolomites in addition to few thin beds of anhydrites in Jeribe Formation and thin beds of sand dominated lithologies in Azkand Formation. Clay content has been calculated from gamma ray log along the studied sections and appeared to be mostly of dispersed clay type as shown from density-neutron porosity crossplot of Thomas-Stieber. Correction from the effect of clay content has been done for all the measured sonic, density, and neutron porosities. The available porosity and permeability values which are measured from core tests in the well Kz-9 for the formations of Jeribe, Anah, and Azkand have been adapted to formalize the best equation for calculating permeability in the other studied wells which have no core test measurements but only log data (Kz-11, Kz-14, and Kz-16 wells). Depending on porosity, permeability, and shale content, the studied sections have been subdivided into seven reservoir units in the wells Kz-11 and Kz-16, and for eight reservoir units in the well Kz-14.

Iraqi Geological Journal

The flow capacity of the Lower Miocene Jeribe Formation was investigated in the two selected well... more The flow capacity of the Lower Miocene Jeribe Formation was investigated in the two selected wells, A and B, of an oilfield northeast of Tikrit City. The available wireline logs and core test data are adapted for characterizing the reservoir potentiality of the formation. Three Hydraulic Flow Units was identified by calculating the values of the Flow Zone Indicators. Most parts of the formation parts have the lowest flow capacity among the three determined flow types. The Jeribe Formation contains hydrocarbons in various ratios in both wells of the study. The Reservoir Unit RUJ-1 at the upper part of the formation has the highest moveable hydrocarbon saturation, especially in the well A. Most hydrocarbons in the RUJ-3 at the lower part of the formation in both wells are immoveable. The oil-water contact was expected within Dhiban Formation in the well B and was expected to be somewhere in the underlying Dhiban or Euphrates Formations in the well A. The nature of the hydrocarbons at ...

Tikrit Journal of Pure Science

Unit A of Kurra Chine Formation has been studied in the well Shaikan - 4 (SH-4) at Shaikan Oilfie... more Unit A of Kurra Chine Formation has been studied in the well Shaikan - 4 (SH-4) at Shaikan Oilfield in Northern Iraqi Kurdistan Region. The available conventional wireline log data and the existed core test values have been used to characterize the reservoir properties of the studied unit and to determine the flow efficiency of the reservoired fluids. The dolomite and anhydrite dominated lithology of the studied unit contains low percentages of shale except the upper most part of the unit in which shale content exceeds 30%. The porosity is less than 5% in most parts of the unit and secondary porosity comprises less than 4% of the total porosity in some horizons. The shale content consists primly of Illite and Chlorite and distributes in a dispersed pattern. Hydrocarbons are exist almost along the studied unit in saturations exceeding 70% at the middle and lower part of the unit. No effective permeable intervals observed at the upper part of the unit, whereas permeable zones of great...

Iraqi Geological Journal

Iraqi Journal of Science

The reservoir characterization of Lower Qamchuqa (Shu'aiba) Formation (Aptian) is studi... more The reservoir characterization of Lower Qamchuqa (Shu'aiba) Formation (Aptian) is studied at the well BH-86 of Bai- Hassan Oilfield in Kirkuk area, Northern Iraq. The lithological study (of 91 thin sections) revealed that the formation consists of shaly limestone, a thin bed of marl within the limestone, and dolomitic limestone. Four petrographic microfacies were noticed Lime mudstone microfacies, Dolomudstone microfacies, Lime wackestone microfacies, subdivided into benthonic foraminifera lime wackestone submicrofacies and bioclasts lime wackestone submicrofacies, and the last microfacies is the Lime packstone microfacies, which is subdivided into pelloidal lime packstone submicrofacies and Orbitolina lime packstone microfacies. Shale content is calculated from the gamma-ry log, showing that the formation is mainly of low shale content (less than 35%). The porosity determined from sonic, density, and neutron logs reflect that the range between <1 and 15% and in some in...

73rd EAGE Conference and Exhibition incorporating SPE EUROPEC 2011, 2011

The organic matter content of the Paleocene Aaliji Formation has been studied from the Qm-1 well ... more The organic matter content of the Paleocene Aaliji Formation has been studied from the Qm-1 well in the Qumar Oil Field, NE Iraq. A palynofacies analysis revealed the obvious domination of amorphous organic matter (AOM) in the samples studied in addition to the different ratios of palynomorphs, phytoclasts and opaque organic material. The deposition of the various percentages of organic matter components and types of palynomorphs appear to have occurred in a proximal suboxic–anoxic basinal environment. The samples analysed showed relatively low percentages of total organic carbon, indicating a generally poor source rock. The thermal alteration index for the palynomorphs (dinoflagellates) observed and identified ranged between 2, 2+ and 3−, indicating an immature to early stage of maturity for the section studied. No clear differentiation between the stages of maturity within the section was identified. The reflectance measured for a few vitrinite particles at a depth of 2,900 m showed uncertainly of 0.46 % Ro, indicating a still thermally immature stage. The values obtained from pyrolysis analysis also supported the formation being in the early stages of maturity, i.e. an immature condition, with Tmax values between 416 and 435 °C. The quality of the organic matter examined and analysed appeared to be mostly type III gas-prone kerogen, as discerned from the hydrogen index, oxygen index and other pyrolysis parameters. The parameters obtained and calculated from gas chromatography analysis performed on a sample at a depth of 2,900 m found marginally mature marine source organic matter.

Tikrit Journal of Pure Science

Reservoir characteristics of the Upper Oligocene-Lower Miocene Ibrahim Formation has been studied... more Reservoir characteristics of the Upper Oligocene-Lower Miocene Ibrahim Formation has been studied from the well Hasira-1 (H-1) at Sarqala Oilfield and from the well Taza-3 (Tz-3) at Taza Oilfield in Garmian Area/ southeast Kirkuk City in the Iraqi Kurdistan Region. The available conventional wireline log data are used for detecting the dominant lithology of the formation which appeared to be limestone and argillaceous limestone. The formation in the well H-1 contains appreciable quantity of shale which in some horizons exceeded 35%. The formation is of poor porosity (5% and 8% as average porosity in the well H-1 and Tz-3 respectively) and of poor to fair permeability with an average of 1.9mD in the well H-1. The formation divided to five reservoir units depending on variations in the shale content, porosity and permeability in the well H-1. RU-2 and RU-4 at depth intervals 4125-4128m and 4109-4114m respectively are of relatively the highest reservoir quality among the five recognize...

Iraqi geological journal, Nov 29, 2023

Iraqi geological journal, Jun 30, 2023

Arabian Journal of Geosciences, Oct 3, 2013

Arabian Journal of Geosciences, Apr 9, 2013

Arabian Journal of Geosciences, Dec 1, 2017

73rd EAGE Conference and Exhibition incorporating SPE EUROPEC 2011, May 23, 2011

The organic matter content of the Paleocene Aaliji Formation has been studied from the Qm-1 well ... more The organic matter content of the Paleocene Aaliji Formation has been studied from the Qm-1 well in the Qumar Oil Field, NE Iraq. A palynofacies analysis revealed the obvious domination of amorphous organic matter (AOM) in the samples studied in addition to the different ratios of palynomorphs, phytoclasts and opaque organic material. The deposition of the various percentages of organic matter components and types of palynomorphs appear to have occurred in a proximal suboxic–anoxic basinal environment. The samples analysed showed relatively low percentages of total organic carbon, indicating a generally poor source rock. The thermal alteration index for the palynomorphs (dinoflagellates) observed and identified ranged between 2, 2+ and 3−, indicating an immature to early stage of maturity for the section studied. No clear differentiation between the stages of maturity within the section was identified. The reflectance measured for a few vitrinite particles at a depth of 2,900 m showed uncertainly of 0.46 % Ro, indicating a still thermally immature stage. The values obtained from pyrolysis analysis also supported the formation being in the early stages of maturity, i.e. an immature condition, with Tmax values between 416 and 435 °C. The quality of the organic matter examined and analysed appeared to be mostly type III gas-prone kerogen, as discerned from the hydrogen index, oxygen index and other pyrolysis parameters. The parameters obtained and calculated from gas chromatography analysis performed on a sample at a depth of 2,900 m found marginally mature marine source organic matter.

Iraqi journal of science, Jul 31, 2022

گۆڤاری زانکۆی سلێمانی بەشی A, May 17, 2020

Arabian Journal of Geosciences, Apr 24, 2014

Iraqi geological journal, Nov 30, 2021

Journal of Petroleum Exploration and Production Technology, Jan 15, 2018

Arabian Journal of Geosciences, Mar 1, 2016

Iraqi Geological Journal

The flow capacity of the Lower Miocene Jeribe Formation was investigated in the two selected well... more The flow capacity of the Lower Miocene Jeribe Formation was investigated in the two selected wells, A and B, of an oilfield northeast of Tikrit City. The available wireline logs and core test data are adapted for characterizing the reservoir potentiality of the formation. Three Hydraulic Flow Units was identified by calculating the values of the Flow Zone Indicators. Most parts of the formation parts have the lowest flow capacity among the three determined flow types. The Jeribe Formation contains hydrocarbons in various ratios in both wells of the study. The Reservoir Unit RUJ-1 at the upper part of the formation has the highest moveable hydrocarbon saturation, especially in the well A. Most hydrocarbons in the RUJ-3 at the lower part of the formation in both wells are immoveable. The oil-water contact was expected within Dhiban Formation in the well B and was expected to be somewhere in the underlying Dhiban or Euphrates Formations in the well A. The nature of the hydrocarbons at ...

Tikrit Journal of Pure Science

Iraqi Geological Journal

Iraqi Journal of Science

73rd EAGE Conference and Exhibition incorporating SPE EUROPEC 2011, 2011

The organic matter content of the Paleocene Aaliji Formation has been studied from the Qm-1 well ... more The organic matter content of the Paleocene Aaliji Formation has been studied from the Qm-1 well in the Qumar Oil Field, NE Iraq. A palynofacies analysis revealed the obvious domination of amorphous organic matter (AOM) in the samples studied in addition to the different ratios of palynomorphs, phytoclasts and opaque organic material. The deposition of the various percentages of organic matter components and types of palynomorphs appear to have occurred in a proximal suboxic–anoxic basinal environment. The samples analysed showed relatively low percentages of total organic carbon, indicating a generally poor source rock. The thermal alteration index for the palynomorphs (dinoflagellates) observed and identified ranged between 2, 2+ and 3−, indicating an immature to early stage of maturity for the section studied. No clear differentiation between the stages of maturity within the section was identified. The reflectance measured for a few vitrinite particles at a depth of 2,900 m showed uncertainly of 0.46 % Ro, indicating a still thermally immature stage. The values obtained from pyrolysis analysis also supported the formation being in the early stages of maturity, i.e. an immature condition, with Tmax values between 416 and 435 °C. The quality of the organic matter examined and analysed appeared to be mostly type III gas-prone kerogen, as discerned from the hydrogen index, oxygen index and other pyrolysis parameters. The parameters obtained and calculated from gas chromatography analysis performed on a sample at a depth of 2,900 m found marginally mature marine source organic matter.

Tikrit Journal of Pure Science