Operations Update

RNS Number : 2212S

88 Energy Limited

22 June 2018

 

22^nd June 2018

88 Energy Limited 

Operations Update

88 Energy Limited (ASX: 88E) ("88 Energy" or the "Company") is pleased to announce the following update for its projects located on the North Slope of Alaska.

Highlights

·      Nitrogen lift continues at Icewine#2

Project Icewine - Icewine#2 Production Testing

As at 1730 21^st June (AK time), the flowback rate was 50 barrels of water per day on a variable choke setting (currently 36/64"). Wellhead pressure has been managed lower to 75psi to reduce back pressure in the system.

Since the last update on the 18^th June, adjustments were made to the flowback system to determine the optimal settings for the nitrogen lift operation. Consequently, flowback rates fluctuated between an average rate of 50 barrels of water per day to 120 barrels of water per day. The percentage of hydrocarbon gas in the flowback dropped to 5% at one stage due to an increased nitrogen injection rate, 300 scf/m, which is deemed to have limited the flowback of both water and gas from the borehole. The reduction in productivity is attributed to an effective downhole choke created between the 4.5" annulus and the 1.75" velocity string, limiting the flowback when the nitrogen rate is too high. The nitrogen injection rate is now being reduced back to 150 scf/m and should result in an increase in flowback of water and gas from the borehole.

During this period there has been no meaningful change to the composition of the returned gas and fluid. Flowback is considered to be 100% stimulation fluid and gas.

Hydrocarbon gas content continues to be predominantly methane (90%) with some heavier elements up to trace C6+. The composition and rate is as expected for this stage of the flowback and results are considered unrepresentative of the hydrocarbon composition in the reservoir, as the well is still in clean-up phase. Salinity measurements of the flowback fluid are also not indicative of connectivity to the reservoir, as expected at this stage of clean-up.

Total clean up fluid returned, (net of diesel for freeze protection and any other fluids introduced as part of the current operation), since commencement of flowback on 12^th June 2018 is 1,100 barrels interpreted as 100% stimulation fluid. Total fluid returned for the entire Icewine#2 flowback operation, including last year, is now 6,632 barrels or 24% of the frac fluid injected vs a target percentage return of at least 30%.

Icewine#2 Production Testing - Timeline

The Icewine#2 well is located on the North Slope of Alaska (ADL 392301). 88 Energy Ltd (via its wholly owned subsidiary, Accumulate Energy Alaska, Inc) has a 77.55% working interest in the well. The well was stimulated in two stages over a gross 128-foot vertical interval in the HRZ shale formation, from 10,957-11,085ft TVD, using a slickwater treatment comprising 27,837 barrels of fluid and 1,034,838 pounds of proppant.

Prior to Winter shut-in (2017) 20% of the stimulation fluids had been flowed back versus a projected minimum target of 30% to gain connectivity to the source rock reservoir.

Flowback re-commenced, on schedule, at 22:30 11^th June 2018 (AK time) to clean-up stimulation fluids from the Icewine#2 borehole with a well head pressure of 3,000 psi and flowback rate of 253 barrels of water per day on an 8/64" choke.

A production log was run on 12^th June and confirmed that all perforations were contributing to flow. As per the flowback design, nitrogen was then introduced gradually to the wellbore from 0845 13^th June (AK time), prior to installation of the coiled tube velocity string, to artificially lift stimulation fluids in order to gain connectivity to the reservoir. The flowback rate stabilised at 200 barrels of water per day through an 8/64" choke and then steadily declined to circa 100 barrels of water per day, as per expectation.

Flowback was interrupted, as per the program, on the 15^th June 08:00 (AK time) to allow installation of the velocity string. Flow was re-established on 15^th June at 20:00 (AK time) with nitrogen introduced into the annulus between the 4.5" casing and the 1.75" velocity string. After displacement of fluid in the annulus, the flowback rate stabilised at 350bpwd through a variable choke to maintain a target wellhead pressure of 200-400psi. This technique decreases the backside pressure in the system and optimises lifting of fluid from the wellbore.

Media and Investor Relations:

88 Energy Ltd

Dave Wall, Managing Director                                                         Tel: [phone]

Email: [e-mail] 

Finlay Thomson, Investor Relations                                               Tel: [phone]

Hartleys Ltd

Dale Bryan                                                                                    Tel: + 61 8 9268 2829

Cenkos Securities                                                                        Tel: + 44 131 220 6939

Neil McDonald/Derrick Lee   

Pursuant to the requirements of the ASX Listing Rules Chapter 5 and the AIM Rules for Companies, the technical information and resource reporting contained in this announcement was prepared by, or under the supervision of, Mr Brent Villemarette, who is a Non-Executive Director of the Company. Mr Villemarette has more than 30 years' experience in the petroleum industry, is a member of the Society of Petroleum Engineers, and a qualified Reservoir Engineer who has sufficient experience that is relevant to the style and nature of the oil prospects under consideration and to the activities discussed in this document. Mr Villemarette has reviewed the information and supporting documentation referred to in this announcement and considers the prospective resource estimates to be fairly represented and consents to its release in the form and context in which it appears. His academic qualifications and industry memberships appear on the Company's website and both comply with the criteria for "Competence" under clause 3.1 of the Valmin Code 2015. Terminology and standards adopted by the Society of Petroleum Engineers "Petroleum Resources Management System" have been applied in producing this document.

Project Icewine Overview

In November 2014, the Company entered into a binding agreement with Burgundy Xploration (BEX) to acquire a significant working interest (87.5%, reducing to 77.5% on spud of the first well on the project) in a large acreage position on a multiple objective, liquids rich exploration opportunity onshore Alaska, North America, referred to as Project Icewine. The current gross acreage position is ~475,000 contiguous acres (301,000 acres net to the Company). 

The Project is located on an all year operational access road with both conventional and unconventional oil potential. The primary term for the State leases is 10 years with no mandatory relinquishment and a low 16.5% royalty.

The HRZ liquids-rich resource play has been successfully evaluated based on core obtained in the recently completed (December 2015) Icewine #1 exploration well, marking the completion of Phase I of Project Icewine. Phase II has now commenced, with drilling at the follow-up appraisal well, Icewine#2, commencing early 2Q2017. Production testing is ongoing.

Significant conventional prospectivity has also been identified on recently acquired 2D seismic across the project acreage.

Cautionary Statement: The estimated quantities of petroleum that may be potentially recovered by the application of a future development project relate to undiscovered accumulations. These estimates have both an associated risk of discovery and a risk of development. Further exploration, appraisal and evaluation are required to determine the existence of a significant quantity of potentially movable hydrocarbons.

Exploration incentives provided by the State of Alaska with up to 35% of net operating loss refundable in cash were concluded for all expenditure post 31 December 2017.

The primary objective is an untested, unconventional liquids-rich shale play in a prolific source rock, the HRZ shale (Brookian Sequence), that co-sourced the largest oil field in North America; the giant Prudhoe Bay Oil Field Complex. Internal modelling and analysis indicates that Project Icewine is located in a high liquids vapour phase sweetspot analogous to those encountered in other Tier 1 shale plays e.g. the Eagle Ford, Texas.

Recently acquired 2D seismic has identified large conventional leads at Project Icewine within the same Brookian petroleum system and shallow to the HRZ shale, including potential high porosity channel and turbiditic sands associated with slope apron and deepwater fan plays. The Brookian conventional play is proven on the North Slope; the USGS (2013) estimated the remaining oil potential to be 2.1 billion barrels within the Brookian sequence. Two recent discoveries in the Brookian have already exceeded these estimates, with Armstrong/Repsol discovering 1.4 billion barrels in 2015 and Caelus announcing a 2.5 billion barrel discovery in 2016. Additional conventional potential exists in the Brookian delta topset play, deeper Kuparuk sands and the Ivishak Formation.

A Prospective Resources Report by DeGolyer and MacNaughton, was commissioned by 88 Energy to evaluate the unconventional resource potential of Project Icewine in February 2016 and was released to the market on 6^th April 2016.

About 88 Energy: 88 Energy has a 63% working interest and operatorship in ~342,000 acres onshore the prolific North Slope of Alaska ("Project Icewine"). Gross contiguous acreage position for the Joint Venture is ~475,000 acres (88E 301,000 net acres). The North Slope is the host to the 15 billion barrel Prudhoe Bay oilfield complex, the largest conventional oil pool in North America. The Company, with its Joint Venture partner Burgundy Xploration, has identified highly prospective play types that are likely to exist on the Project Icewine acreage - two conventional and one unconventional. The large unconventional resource potential of Project Icewine was independently verified by leading international petroleum resource consultant DeGolyer and MacNaughton. In addition to the interpreted high prospectivity, the project is strategically located on a year-round operational access road and only 35 miles south of Pump Station 1 where Prudhoe Bay feeds into the Trans Alaska Pipeline System. The Company acquired 2D seismic in early 2016 to take advantage of the globally unique fiscal system in Alaska, which allowed for up to 75% of 1H2016 exploration expenditure to be rebated in cash. Results from the seismic mapping and prospectivity review are encouraging, and form the basis of a conventional prospectivity portfolio for Project Icewine. In late 2015, the Company completed its maiden well at the project, Icewine#1, to evaluate an unconventional source rock reservoir play which yielded excellent results from analysis of core obtained from the HRZ shale. The follow-up well with a multi-stage stimulation and test of the HRZ shale, Icewine#2, spud in early 2Q2017. Flow testing at Icewine#2 is scheduled to re-commence in June 2018.

 

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