Prueba de flujo Hickory-1: segundo descubrimiento de petróleo ligero
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18:34 22/03/17
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15 de abril de 2024
88 Energía limitada
HICKORY-1 FLOW TEST - SECOND LIGHT OIL DISCOVERY
Destacados
· Dual reservoir success at Hickory-1 with second light oil discovery at the SMD-B reservoir.
· Peak flow rate of ~50 barrels of oil per day (bopd) of light oil (measuring approx. 39-degree API oil gravity, under nitrogen lift).
· The SMD-B reservoir showed little to no measurable associated gas flow (low Gas-oil-Ratio (Gor), which validates the pre-test analysis.
· Hickory-1 has now delivered two successful oil flows and three independent discoveries:
- SMD-B (today's result): with a peak flow rate of ~50 bopd of light oil (measuring approx. 39-degree API oil gravity, under nitrogen lift).
- Upper SFS (USFS) (previously announced on 2 April 2024): with a peak flow rate of over 70 bopd of light oil (measuring approx. 40-degree API oil gravity, under natural flow).
- Both flow rates result from low volume stimulations over small 20ft perforated intervals in vertical well.
- Previously announced Ventilador de piso para lavabo (BFF) Gross Best Estimate (2C) Contingent Resource of 250 Million Barrels of Oil Equivalent (MMBOE) (refer 88E ASX release dated 6 November 2023)
· Quality and deliverability of both SMD-B and USFS demonstrated via oil production to surface with the USFS reservoir producing under natural flow - positively differentiating Hickory-1 from results on adjacent acreage.
· It is anticipated that these reservoirs will be developed from long horizontal production wells which typically produce at multiples of between 6 to 12 times higher than vertical wells. Project Phoenix also benefits from the ability to produce concurrently from multiple reservoirs in a single development scenario.
· Well testing results from the current field season confirm long-held views of the producibility of multiple reservoirs at Project Pheonix.
· As such, the Hickory-1 flow test results can be rightly characterised as in-line with those observed from equivalent reservoirs on adjacent acreage. Importantly, the performance of the USFS reservoir exceeded expectations, with the well flowing naturally with increasing oil cut.
· The results from the Hickory-1 flow tests permits an independent Contingent Resource assessment for both the SFS and SMD reservoirs; expected to be complete during 2H 2024.
· Project Phoenix JV to conduct post-test studies for integration into existing models allowing refined development planning for all reservoirs; studies to commence 2H 2024.
· Commercialisation options to be advanced in parallel, including farm-out to a strategic development partner and/or early, capital-lite production, given proximate infrastructure advantages (Hickory-1 next to Dalton Highway and Trans-Alaskan Pipeline System (TAPS)).
88 Energy Limited (ASX: 88E, AIM: 88E, OTC: EEENF) (88 Energía o de Empresa) is pleased to announce further successful flow test results from the Company's Hickory-1 discovery well, located in Project Phoenix on the North Slope of Alaska (88 Energy ~75% WI owner).
La directora general, Ashley Gilbert, comentó:
"Having now successfully demonstrated light oil flow from two reservoirs at Hickory-1 in recent weeks, it is clear that this is a significant milestone in the history of 88 Energy. The USFS success represents the first time that we have successfully flowed oil to surface in Alaska - and under natural flow - as well as being the first time we have confirmed a light oil discovery of substantial scale in close proximity to the critical Dalton Highway and Trans-Alaskan Pipeline System infrastructure. To then achieve a second successful flow of light oil from the SMD-B reservoir, with a low gas/oil ratio, is an outstanding outcome for 88 Energy and its shareholders.
The flowing of light oil from multiple reservoirs demonstrates the potential that this acreage holds for our shareholders, positioning the Company to grow and extract value from Project Phoenix via multiple potential development and commercialisation pathways. These include farm-out to a strategic partner in pursuit of a carry towards a development proposition and/or accelerated, capital-lite production given the highly development-friendly location of Hickory-1 within the North Slope. Development of these reservoirs is anticipated to be via long horizontal production wells, with numerous production analogues elsewhere demonstrating many multiple times the flow rates achieved from vertical wells.
Detailed evaluation of these development options, and pursuit of the optimal pathway, is the process that we are now set to undertake over the coming months. This work will be undertaken alongside the assessment of independent Contingent Resource declarations for the SFS and SMD reservoirs at Hickory-1, which will be additive to the BFF Contingent Resource previously declared. It is a busy and exciting time ahead for 88 Energy."
SMD-B flow test results; further detail
A 20ft perforated interval in the SMD-B reservoir was stimulated via a single fracture stage comprising 226,967 lbs of proppant volume. The well was cleaned-up and flowed for 84 hours in total, utilising nitrogen lift throughout the entire test period. The average fluid flow rate over the duration of the flow back period was approximately 445 bbls/d, with choke sizes ranging from 8/64ths to 33/64ths.
The SMD-B test produced at a peak estimated flow rate of ~50 bopd. Oil cuts varied throughout the flow back period, reaching a maximum of 10% oil cut. The well produced at an average oil cut of 4% following initial oil to surface, with instantaneous rates observed during the 16-hour period varying as the well cleaned up. Some 70% of stimulation fluid had been recovered at the conclusion of the test at which time water salinity measurements indicated that stimulation fluid was still being recovered and the well was still cleaning up. Oil cut would be expected to improve once stimulation fluid was fully recovered.
Multiple oil samples were recovered, with measured oil gravities of between 38.5 to 39.5 API, representing a light crude oil.
Importantly, the SMD-B zone flowed oil to surface with little to no measurable gas, representing a low GoR production rate. Pressurised oil samples collected during both the USFS and SMD tests will be transported to laboratories for further analysis.
The SMD-B flow test was concluded with sufficient information for the next steps, and the data recorded will assist 88E in optimisation and design processes in the next phase of advancement of Project Phoenix.
Hickory-1 flow test unlocks broader Project Phoenix potential; USFS Recap
Two separate successful flow tests were conducted at Hickory-1, over the SMD-B and Upper SFS reservoirs. As previously announced, the deeper USFS reservoir was initially tested which produced the following results:
· A 20 ft interval was perforated in the Upper SFS reservoir which was then stimulated via a single fracture stage of 241,611 lbs proppant volume. The zone flowed at a peak flow rate of over 70 bopd. Oil cuts increased throughout the flow back period as the well cleaned up, reaching a maximum of 15% oil cut. Once oil cut was established during the natural flow back period the well produced at an average oil flow rate of approximately 42 bopd during the natural flow back period.
· Importantly, the USFS zone flowed oil to surface under natural flow, with flow back from other reservoirs in adjacent offset wells only producing under nitrogen lift. Multiple oil samples were recovered with measured oil gravities of between 39.9 to 41.4 API (a light crude oil).
· Additionally, some NGLs were produced during the USFS test, as was anticipated in the planning phase. The presence of NGLs was demonstrated by samples from the flare line and by visible black smoke in the flare. The company anticipates NGLs produced to be at a similar rate to those observed during flow tests on adjacent acreage given the consistency of results observed between the USFS test and tests conducted on adjacent wells. It may be possible to estimate the amount of NGLs that were not measured in these tests, once fluid characterisation studies are completed in laboratory. Historically, NGLs prices on the North Slope of Alaska have been similar to, or slightly below, light oil prices and are therefore considered highly valuable. Further work is required to quantify the exact volume of NGLs, which 88 Energy intends to include as part of a maiden certified Contingent Resource assessment at Project Phoenix for the SFS and SMD reservoirs.
plan de avance
The Joint Venture will P&A the Hickory-1 well with any future appraisal and/or development activities at this location being via a long horizontal production well. The rig and associated services are expected to be off-location within the next ten days. It is anticipated that the flow test will be concluded at an estimated cost of circa US$14.5 million gross, due to the additional length of operations.
88 Energy now plans to undertake post-test studies, including fluid testing to characterise reservoir fluids, and downhole pressure and temperature data analysis to determine reservoir properties, at distances beyond the depth of investigation of the wireline logs. These studies will then be integrated into existing data sets and models to refine appraisal and development plans for each reservoir, with pre-FEED studies expected to commence during 2H 2024. Development of these reservoirs is anticipated to be via horizontal production wells, with numerous production analogues elsewhere demonstrating many multiple times the flow rates achieved from vertical wells. Additionally, horizontal developments are common practice on the North Slope of Alaska with Conoco Philips's Alpine and Kuparuk fields both utilising this technique.
Production rates in long horizontal production wells are typically multiples of 6 to 12 times higher than tested in vertical wells, as evidenced in many Lower 48 analogues. Project Phoenix also benefits from the ability to produce from multiple reservoirs concurrently in a development.
Commercialisation options for Project Phoenix are to be advanced in parallel, including farm-out to a strategic development partner and/or early, capital-lite production given proximate infrastructure advantages (Hickory-1 is located right next to the Dalton Highway and TAPS).
In addition, the Company plans to work with independent geological consultants to secure a Contingent Resource estimate over the SMD and SFS reservoirs (complementing the previously announced Contingent Resource estimate over the BFF reservoir; refer 88E ASX release dated 6 November 2023). Completion of these estimates is expected during Q2 2024.
Further updates on the Hickory-1 results and Project Phoenix forward plan will be announced in due course.
Información adicional relacionada con Hickory-1:
Hickory-1 está ubicado en tierras estatales en la vertiente norte de Alaska, adyacente a la autopista Dalton y al oleoducto Trans Alaska, dentro del contrato de arrendamiento de petróleo y gas de Alaska ADL 392314. 88 Energy tiene una participación operativa de ~75 % en el pozo y es el operador. El pozo se perforó el 9 de marzo de 2023 y se perforó hasta una profundidad total de 10,650 pies. Se identificaron múltiples zonas productivas prospectivas en el yacimiento de arenisca entre las profundidades 7,700 y 10,500.
88 Energy informó una estimación inaugural de Recursos Contingentes certificada de forma independiente de 136 MMbbl de hidrocarburos líquidos (mejor estimación bruta (2C)) y 628 BCF de gas, para el yacimiento Basin Floor Fan (BFF) en el Proyecto Phoenix el 6 de noviembre de 2023.
Este anuncio ha sido autorizado por la Junta.
88 Energía Ltda. Ashley Gilbert, directora general Tel: +61 8 9485 0990 Email:GME@dhr-rgv.com | |
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De conformidad con los requisitos del Capítulo 5 de las Reglas de Listado ASX y las Reglas AIM para Empresas, la información técnica y los informes de recursos contenidos en este anuncio fueron preparados por, o bajo la supervisión de, el Dr. Stephen Staley, quien es un Director No Ejecutivo de la empresa. El Dr. Staley tiene más de 40 años de experiencia en la industria del petróleo, es miembro de la Sociedad Geológica de Londres y es un geólogo / geofísico calificado que tiene suficiente experiencia que es relevante para el estilo y la naturaleza de los prospectos petroleros bajo consideración y para las actividades discutidas en este documento. El Dr. Staley ha revisado la información y la documentación de respaldo a la que se hace referencia en este anuncio y considera que las estimaciones de recursos y reservas están representadas de manera justa y consiente su publicación en la forma y el contexto en que aparecen. Sus calificaciones académicas y membresías de la industria aparecen en el sitio web de la Compañía y ambos cumplen con los criterios de "Competencia" bajo la cláusula 3.1 del Código Valmin 2015. La terminología y los estándares adoptados por la Sociedad de Ingenieros de Petróleo "Sistema de Gestión de Recursos de Petróleo" se han aplicado en produciendo este documento.
Apéndice A
Informe de resultados de exploración y perforación de materiales de conformidad con las reglas de cotización de ASX, Capítulo 5
Regla de listado de ASX | Requisito | Informe de prueba del pozo Hickory-1 | |
5.30 | (A) | El nombre y tipo de pozo. | Hickory-1, pozo de exploración vertical |
| (B) | La ubicación del pozo y los detalles del permiso o contrato de arrendamiento en el que se encuentra el pozo. | Hickory-1 está ubicado en tierras estatales en la vertiente norte de Alaska, adyacente a la autopista Dalton y al oleoducto Trans Alaska, dentro del contrato de arrendamiento de petróleo y gas de Alaska ADL 392314. |
| (C) | La participación laboral de la Compañía en el pozo. | ~ 75% |
| (D) | Espesor salarial bruto y espesor salarial neto | N/A |
| (E) | Tipo de roca geológica de la formación perforada. | Sandstone |
| (F) | Profundidad de las zonas probadas. | SMD-B perforation interval: 7,955' - 7,975' MDRT |
| (G) | Tipos de pruebas realizadas y duración de las mismas. | Fracture stimulate and flow test the SMD-B formation, utilising nitrogen lift. The well flowed under nitrogen lift for a period of approximately 84 hours, inclusive of clean up and recovery of frac fluids. |
| (H) | Las fases de hidrocarburos recuperadas en las pruebas. | Oil was recovered during the test, with little to no measurable gas noted. |
| (I) | Cualquier otra recuperación, como agua de formación y agua, asociada a las pruebas y sus respectivas proporciones. | 1,551 bbls of water was recovered during flow back, consisting of frac fluids injected into the reservoir (approximately 2,144 bbls of fluid was injected during frack operations). Further analysis of fluids will be conducted post the flow test to determine extent of reservoir fluids. Total stimulation load water was not recovered and water salinity measurements indicated we were recovering load water at the conclusion of the test. |
| (J) | El tamaño del estrangulador y los caudales y, si se miden, los volúmenes de las fases de hidrocarburos medidos. | Various choke sizes used during flow back operations from 8/64ths to 33/64ths of an inch. Total fluid flow rates (inclusive of recovery of frac fluid) averaged ~445 bbl/d over the duration of the flow back. Oil cut following establishment of production ranged from 1% to 10%. The well produced at an average oil cut of 4% following initial oil to surface, with instantaneous rates observed during the 16 hour period varying as the well continued to clean up at managed fluid flow rate of ~170 bbls/d with a calculated total volume during the flow back period following establishment of oil cut of ~4 stk bbls. No measurable gas or NGL's were recovered from the SMD-B test. |
| (K) | Si se probaron caudales, información sobre las presiones asociadas con el flujo y la duración de la prueba. | Well head pressures over the duration of the flow back period ranged from ~200 to 1,780 psig. |
| (L) | El número de etapas de estimulación de fracturas y el tamaño y naturaleza de la estimulación de fracturas aplicada. | The SMD-B zone was stimulated in a single stage and utilised a cross-linked polymer gel. The volume of sand proppant pumped was 226,967 lbs for the SMD-B. |
| (metro) | Cualquier volumen material de gases distintos de los hidrocarburos, como dióxido de carbono, nitrógeno, sulfuro de hidrógeno y azufre. | The SMD-B test showed no measurable CO2 o H2S. No other impurities were detected on site. |
| (norte) | Cualquier otra información que sea importante para comprender los resultados informados. | Ninguna |
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