Africa (Sub-Sahara) Oil was discovered at the Ekales-1 wildcat well located in Block 13T in northern Kenya. The well has a potential net pay of between 197 and 322 ft in the Auwerwer and Upper Lokone sandstone formations. Tullow (50%) operates 13T with partner Africa Oil (50%). The Mzia-3 appraisal well in Block 1 off Tanzania encountered a combined total of 183 ft of net pay in the Lower and Middle sands and confirmed reservoir quality in line with that seen in the Mzia-1 and Mzia-2 wells. Asia Pacific The Luba-1 offshore well on Brunei Block L was spudded. The well will evaluate the hydrocarbon potential of the Triple Junction structure. Serinus has a 90% interest in Block L, through indirect wholly owned subsidiaries Kulczyk Oil Brunei (40%) and AED SEA (operator, 50%).
Africa (Sub-Sahara) Eni finished a production test on its Minsala Marine 1 NFW well, located in Marine XII block, 35 km offshore The Republic of the Congo. During the test, the well delivered natural flow in excess of 5,000 B/D of 41 API crude and 14 MMcf/D of natural gas from a 37-m opened section of the discovery's 420-m column. Eni (65%) is operator, with state-owned partner SNPC (25%), and New Age (African Global Energy) Limited (10%). Asia Pacific CNOOC started natural gas production from the Panyu 34-1/35-1/35-2 project at the Pearl River Mouth basin in the South China Sea. Main production facilities for the three gas fields include one comprehensive platform, two sets of underwater production systems, and 13 producing wells. Two wells are producing a total of 21 MMcf/D of gas. The project is expected to reach peak production of 150 MMcf/D.
Africa (Sub-Sahara) Petroceltic International said that the first of up to 24 new development wells planned in Algeria's Ain Tsila gas and condensate field was successful. The AT-10 well, situated about 2 miles from the AT-1 field discovery well, reached a total depth of 6,578 ft. Wireline logs indicated that the expected initial offtake rate would be comparable to the AT-1 and AT-8 wells, both of which test-flowed at more than 30 MMcf/D. Petroceltic is the operator with a 38.25% interest in the production-sharing contract that covers the Ain Tsila output. The remaining interests are held by Sonatrach (43.375%) and Enel (18.375%). Sonangol reported that it has found reserves in the Kwanza Basin of Angola that could total 2.2 billion BOE, including reserves in a block jointly owned with BP. Block 24, operated by BP, holds an estimated 280 million bbl of condensate and 8 Tcf of gas, totaling 1.7 billion BOE, Sonangol said in a statement seen by Reuters.
Summary Seismic attributes are powerful tools that allow interpreters to make a more comprehensive and precise seismic interpretation. In this paper, we apply an unsupervised multiattribute technique called Independent Component Analysis to reduce dimensionality and extract the most valuable information of multiple spectral magnitude components in order to make an unsupervised seismic facies classification of channel complexes located in the Moki A Formation, Taranaki Basin, New Zealand. Introduction Depending on the seismic attribute that we choose, different information can be extracted (Infante-Paez and Marfurt, 2017) from the seismic volume, thus, relying on only one attribute information lead to an incomplete seismic interpretation. For this reason, multi-attribute techniques such as Principal Component Analysis (PCA), Selforganizing Maps (SOM) are commonly used. Based on higher order statistics, Independent Component Analysis separates a multivariate signal into subcomponents which are independent of each other (Hyva rinen and Oja, 2000), thus extracting more valuable information than techniques such as Principal Component Analysis (PCA) which tends to mix geology.
Alhakeem, Aamer (Missouri University of Science and Technology) | Liu, Kelly H. (Missouri University of Science and Technology) | Zhang, Tianze (Missouri University of Science and Technology) | Gao, Stephen S. (Missouri University of Science and Technology)
Inversion of poststack seismic data is validated with rock physics analysis from the well data. The acoustic impedance is computed throughout the well-seismic-tie and synthetic seismogram generation. Seismic attributes, including velocities and results of inversion, are generated to study the potential prospect in the Maui Field, Taranaki Basin, New Zealand. Seismic interpretation generated structure and amplitude horizon slices as well as the recursive algorithmic attribute are applied to invert the seismic traces to provide quantitative predictions on the reservoir properties. Stratigraphic evaluation is obtained from the interpretation. After evaluating the petrophysical parameters from well logs, the poststack inversion of the seismic data is validated. The results are reliable for future use in an artificial neural network.
Presentation Date: Tuesday, October 16, 2018
Start Time: 9:20:00 AM
Location: Poster Station 19
Presentation Type: Poster
Zhang, Tianze (Missouri University of Science and Technology) | Lin, Yani (Missouri University of Science and Technology) | Liu, Kelly H. (Missouri University of Science and Technology) | Alhakeem, Aamer (Missouri University of Science and Technology) | Gao, Stephen (Missouri University of Science and Technology)
Summary The ant tracking technique has been widely used in fault interpretation. However, the reliability of the results is highly dependent on appropriately choosing signal processing method and volume attributes. In our study area, which lies in the southern Taranaki Basin, we applied Graphic Equalizer as the processing tool and the Chaos attribute before running the ant tracking algorithm. Results show that the procedure has better quality and can map both the major and minor faults more efficiently than the conventional fault interpretation procedure. Introduction Data and Methodology The study area is located in the Kupe area in the south of the Taranaki Basin (Fohrmann et al., 2012).
Recent developments in integrating seismic interpretation and geological modeling are aiming at removing common industry bottlenecks such as the often cumbersome updating process of existing models. This paper will demonstrate a streamlined application of maintaining existing structural and hence geological, models live and with it improvements in risk analysis by applying flexible uncertainty assessment to such existing models without having to remodel the entire structure. This can be either local updates or applying uncertainty onto existing interpretations. This approach of assessing seismic interpretation uncertainty is based on the uncertainty associated with an individual interpreted point and can be carried throughout a full modeling workflow. Such flexible uncertainty envelopes can be applied onto new seismic data or, in this case, onto an existing interpretation of structural elements for capturing and reassessing structural uncertainty.
Seismic geometric attributes like dip magnitude, azimuth and apparent dip are computed over 3D Pre-stack Time migrated seismic data of Parihaka block covering an area of approximately 1,710 sq km in the NW part of offshore Taranaki basin for obtaining a detailed structural definition of the Urenui Formation that got deposited during the Kapitian to Waipipian times (6 to 3 Ma) within the prospect area. The seismic data volume was steered in the direction of dip and azimuth of the seismic reflectors to obtain a steering cube that preserves the dip information at every sample location of the data volume. This was then used to compute geometric attributes. The results of these attributes brought out an enhanced image of the fault signatures observed over the formation. The composite display maps of dip and azimuth attributes outlined the major structural trend (ENE-WSW) of the faults. Imaging of subsurface structural details is going to go in long way in exploration and development of the field.
Presentation Date: Tuesday, October 18, 2016
Start Time: 11:10:00 AM
Location: Lobby D/C
Presentation Type: POSTER
The Mount Messenger Formation in Taranaki New Zealand provides both reservoir and seal units for hydrocarbon accumulations. This paper presents the results of geomechanics testing of samples from the formation at the GNS Science Rock and Soil Mechanics Laboratory, in combination with mercury injection testing. Strength testing, which was on blocks from outcrop exposures or shallow (<60 m) depth cores, included unconfined and triaxial compression at effective confining pressures up to 20 MPa that gave Mohr Coulomb strength parameters of cohesion (c') between 1.5 and 2.5 MPa and friction angles (Φ') between 15° and 26°. Other testing, which included consolidation, ultrasonic (p and s wave) velocities, air permeability gave results typical of New Zealand sedimentary soft rocks with unconfined compressive strength <5 MPa. The mercury injection testing gave a mercury-air threshold entry pressure of ~80 psia. The low to moderate strengths and a low threshold entry pressure together indicate a borderline hydrocarbon reservoir seal quality for the samples.
The Taranaki region of New Zealand is known for both onshore and offshore hydrocarbon production. The Mount Messenger Formation , which has a widespread onshore distribution in North Taranaki (Fig. 1), is associated with both reservoir and seal units for hydrocarbon accumulations (e.g., ).
This paper presents the results of a range of laboratory geomechanics testing, in particular for strength and compressibility properties. The main intention of the paper is to demonstrate the capability of the GNS Science Rock and Soil Mechanics Laboratory in Lower Hutt to obtain mechanical properties at pressures associated with New Zealand hydrocarbon reservoirs.
GNS Science has well-established capabilities in engineering geology and petroleum geoscience. In engineering geology these are largely associated with infrastructure foundations, landslides and geological hazards and for hydrocarbon geology the assessment of hydrocarbon systems, including the development of reservoir traps and associated seals.
The Rock and Soil Mechanics Laboratory was originally established to complement engineering geology programmes (e.g., ), while a recent expansion of capabilities has targeted an ability to perform testing at higher loads and pressures including use of a stiff loading frame and associated triaxial cells.
Kidd, Samuel Lewis (Scaled Solutions Limited) | Stalker, Robert (Scaled Solutions Limited) | Graham, Gordon Michael (Scaled Solutions Limited) | Einzinger, Christian (OMV) | Duff, Lauchlan Grant (Genesis Oil & Gas Consultants) | Hobbs, George Wiliam (Strategic Chemistry)
The Maari Field is located 50 miles off the coast of South Taranaki, New Zealand. In this paper, we will present details of a laboratory test programme which was conducted to assist in the design of removal and mitigation treatments for flow assurance in the Maari oilfield. Main operating partner OMV initiated laboratory testing of a series of carbonate and sulphate scale dissolver and inhibitor treatments for use in the field, examining formation damage aspects potentially associated with the use of such fluids in the field. The waxy nature of the reservoir crude oil presented challenges for core flood testing, in particular the design of appropriate crude oil conditioning techniques to provide representative samples and core flood protocols to omit potential laboratory artefacts.
The Maari crude oil contains heavy oil fractions, high wax content and a high wax appearance temperature. Standard field sampling, laboratory conditioning and sub-sampling methods can result in loss of light fractions through evaporation and thus a crude oil sample weighted towards the heavier molecular weight oil fractions. Also there is potential for heavy end losses due to insufficient conditioning temperature, filtering and sub-sampling. Appropriate protocols were therefore required to condition the crude oil to a field representative state for use. Heavy oil fractions within the crude oil presented challenges for conducting effective core flood tests. Oil particulates and heavy fractions can induce wax deposits and fines mobilisation effects that can be considered test artefacts obscuring formation damage test results. Alternative test methods were therefore designed to ensure the crude conditioning methods and core flood tests are as representative as possible of the oilfield whilst also providing clear and accurate formation damage assessment.
This paper therefore presents a laboratory strategy designed to account for the aforementioned challenges alongside laboratory test results and subsequent recommendations for crude and core conditioning and core test protocols under similar conditions.