Wrap Text
Oando Energy Resources announces year end 2015 result
Oando PLC
(Incorporated in Nigeria and registered as an external company in South Africa)
Registration number: RC 6474
(External company registration number: 2005/038824/10)
Share Code on the JSE Limited: OAO
Share Code on the Nigerian Stock Exchange: OANDO
ISIN: NGOANDO00002
("Oando" or the “Company")
OANDO ENERGY RESOURCES ANNOUNCES YEAR END 2015 RESULTS
CALGARY, ALBERTA, March 30, 2016 – Oando Energy Resources Inc. (“OER” or the “Corporation”) (TSX:
OER), a company focused on oil and gas exploration and production in Nigeria, today announced
financial and operating results for the three and twelve months ended December 31, 2015. The
audited consolidated financial statements, notes and management’s discussion and analysis
pertaining to the period are available on the System for Electronic Document Analysis and Retrieval
(“SEDAR”) at www.sedar.com and by visiting www.oandoenergyresources.com. All monetary figures
reported herein are U.S. dollars unless otherwise stated.
“Despite broader macroeconomic and commodity price challenges, 2015 proved to be an
operationally successful year for us as we maintained our production output and successfully reduced
our debt obligations with the restructuring of our hedge instrument,” said Pade Durotoye, CEO of
Oando Energy Resources. “2016 will be focused on maintaining our production levels through low
cost rigless activities and intensifying our efforts on Cash and Cost management”.
Key Financial and Operational Highlights
Production in 2015 increased to 19.9 MMboe (average 54,520 boe/day) from 9.1 MMboe (average
24,945 boe/day) in 2014. During the fourth quarter of 2015 production decreased to 4.8 MMboe
(average 52,637 boe/day), compared with 5.0 MMboe (average 54,721 boe/day) in the fourth quarter
of 2014. The increase between the annual periods is primarily as a result of the input from the Nigerian
onshore and offshore assets acquired on July 30, 2014 from the ConocoPhillips Company (“COP
Acquisition”) that included substantial production from OMLs 60 to 63, significant reserves and
resources, and a considerable base of development and exploration opportunities. Gas production
reduced quarter on quarter as a result of the production constraints arising from the Ebocha
flowstation fire;
During 2015 revenues increased by $33.5 million, to $455.0 from $421.4 million in 2014, primarily as a
result of the COP Acquisition producing assets of OMLs 60 to 63, countered by a substantial decline in
crude oil and natural gas sales prices;
In 2015, approximately 46% of crude oil production was hedged. At December 31, 2015, 9,617
bbls/day of crude oil production was hedged at $65/bbl (average) with expiries ranging from July
2017 to Jan 2019, and further upside if certain price targets are met, which represented 43% of the
fourth quarter production of crude oil;
The Corporation recognized net income of $16.1 million in 2015, compared to a net loss of $320.0
million in 2014. The increase was primarily the result of the decrease in the non-cash impairment of
assets, which was partially offset by lower commodity prices;
In December 2015, OER entered into an agreement to sell its interest in OMLs 125 and 134 to the
operator for cash proceeds of $5.5 million and assumption of $84.5 million in cash call liabilities due to
the joint venture. The divesture requires lender and regulatory consent;
In October 2015, the Corporation increased the capacity of the Senior Secured Facility and Corporate
Finance Facility by $90.7 million; proceeds from the loan and cash on hand were used to repay the
$100 million subordinated debt facility and fees of $4.6 million;
In December 2015, OER entered into a definitive agreement with Oando PLC and Oando E&P
Holdings Limited to acquire, by way of an arrangement, all of the issued and outstanding
common shares of OER for a cash consideration of US$1.20 per share. Following consideration
of the transaction by a committee comprised of the Corporation’s independent directors (the
“Independent Committee”) and the receipt of a formal valuation and fairness opinion, the
Independent Committee and board of directors recommended that OER’s shareholders vote
in favour of the transaction. At the meeting of OER’s shareholders held on February 25, 2016
for the purposes of considering the transaction, 100% of the votes cast were voted in favour
of the resolution to approve the transaction. On February 26, 2016 the Supreme Court of
British Columbia issued a final order approving the arrangement. Completion of the
transaction is subject to satisfaction or waiver of certain conditions precedent including the
consent of lenders under one of OER’s loan facilities and Oando PLC’s lenders. The outside
date for completion of the transaction is April 29, 2016; and
As at December 31, 2015, OER had a working capital deficiency of $835.8 million, compared with a
working capital deficiency of $567.2 million at December 31, 2014. The increase in the working capital
deficiency was due to the reclassification of non-current borrowings to current borrowings as a result
of breaching a loan agreement requirement at December 31, 2015. The Corporation had
amalgamated two of its subsidiaries, one of which was a party to the Senior Secured Facility,
prior to receiving lender consent which triggered a default and prompted lenders to exercise
their right to restrict cash payments from lender-held cash deposits. The default gives the
lenders the ability to accelerate the maturity of the facility on demand. As of the date of these
financial statements, the lenders have chosen not to exercise their acceleration rights under
the loans. As a result of this default, $268.6 million of borrowings was reclassified to current
borrowings as at December 31, 2015.
Selected Financial and Operational Review
The table below summarizes selected financial and operational information for the years ended
December 31, 2015, 2014 and 2013 and for the three months ended December 31, 2015 and 2014.
Selected Annual Information Fourth Quarter
2015 2014 2013 2015 2014
Financial:
Revenue 454,965 421,422 127,211 99,798 174,042
Funds from operations 1 181,308 101,303 52,632 29,509 52,945
Selected Annual Information Fourth Quarter
2015 2014 2013 2015 2014
Comprehensive income (loss) 16,119 (320,041) (38,230) 79,577 (232,033)
Net income (loss) per share: Basic 0.02 (0.53) (0.36) 0.10 (0.29)
Net income (loss) per share: Diluted 0.02 (0.53) (0.36) 0.10 (0.29)
Total assets 3,141,596 3,242,791 1,299,422 3,141,596 3,242,791
Total non-current liabilities 868,771 1,088,996 275,195 868,771 1,088,996
Operational:
Production:
Crude oil (bbl) 7,826,926 4,092,973 1,456,818 2,039,138 2,000,821
NGL (boe) 1,216,101 475,053 - 301,536 291,907
Natural Gas (mcf) 65,138,487 27,221,832 - 15,011,170 16,449,778
Total production (boe) 19,899,442 9,104,998 1,456,818 4,842,536 5,034,358
Daily production:
Crude oil (bbls/day) 21,444 11,214 3,991 22,165 21,748
NGLs (boe/day) 3,332 1,302 - 3,278 3,173
Natural Gas (mcf/day) 178,462 74,580 - 163,165 178,802
Total (boe/day) 54,520 24,945 3,991 52,637 54,721
Average selling prices 2, 3
Crude oil ($/bbl) 51.07 95.22 110.30 43.32 81.29
NGL ($/boe) 10.49 11.77 - 9.96 10.91
Natural gas ($/mcf) 1.68 2.54 - 1.38 2.46
1
See definition under non-GAAP measures.
2
Before royalties and the Government share of profit oil.
3
Average selling prices are calculated from volumes sold during the period.
Revenues in the fourth quarter of 2015 were $99.8 million compared with $174.0 million in the same
quarter of 2014. The $74.2 million decrease was the result of the significant reduction in crude oil and
natural gas prices, which was partially offset be additional revenue from Qua Ibo coming on-stream in
the first quarter of 2015. Revenue from sales during the fourth quarter of 2015 consisted of $83.4
million of crude oil, $18.6 million of natural gas, $3.0 million of NGLs, $4.2 million related to the sale of
power generated by the Kwale-Okpai independent power plant (“IPP”), and $0.7 million related to oil
transportation tariffs. In the fourth quarter of 2015, royalties on oil and gas sales were $10.1 million,
compared with $37.5 million in the same quarter of 2014. The decrease in royalties was a result of the
reduction in sales from lower commodity prices and an adjustment reducing prior year government
royalties at OML 56.
In 2015 the Corporation generated $455.0 million in revenue, net of royalties, compared with $421.4
million in 2014. Gross oil and gas sales increased $45.1 million to $507.1 million from $461.9 million in
2014. The increase in gross oil and gas revenues in 2015 was primarily a result of the acquisition of
OMLs 60 to 63, which was significantly offset by lower commodity selling prices in 2015. In addition,
royalties increased by $15.8 million to $71.4 million in 2015, compared with $55.6 million incurred in
2014. The increase in royalties, which are paid on production volumes, was attributed to the purchase
of OMLs 60 to 63 in mid-2014, compared to a full year of production in 2015, which was also
significantly countered by lower selling price of crude oil and natural gas.
Production expenses in the fourth quarter of 2015 were $66.5 million compared with $62.8 million in
the fourth quarter of 2014. During 2015 production expenses were $238.7 million, which was an
increase of $85.7 million over the $152.9 million incurred in 2014. The increase in 2015, compared with
2014, was primarily related to the additional production expenses from OMLs 60 to 63, offset by the
$38.6 million fair value adjustment related to the COP Acquisition. On a per boe basis, production
expenses, net of fair value adjustments, were $11.99/boe in 2015 and $12.56/boe in 2014. The modest
decrease was the result of the operating cost reductions realized at each of the Corporation’s
properties resulting from focusing on increasing efficiency, along with the effect of increasing
production volumes at Ebendo.
General and administrative (“G&A”) costs in the fourth quarter decreased to $20.7 million from $39.5
million in the fourth quarter of 2014. The decrease of $18.8 million was primarily a result of a
significant reduction in professional fees incurred that was partially offset by an increase in equipment
maintenance costs during the quarter. In addition, management has taken steps during the quarter to
reduce its G&A overhead costs by reducing its employee count and taking steps to delist the
Corporation from the TSX Exchange. The impairment of the joint venture receivable in the fourth
quarter of 2015 was $nil, compared to $48.0 million recognized in 2015.
G&A costs during 2015 were $69.6 million, remaining consistent with the $70.6 million incurred in
2014. On a per boe basis the G&A costs improved to $3.50/boe from $7.76/boe in 2014, as a result of
the increase in production between the years. G&A in 2015 include $2.8 million (2014 - $1.1 million) of
non-cash share-based payments expense and $15.1 million (2014 – $29.4 million) related to shared
and management costs for services provided by Oando PLC, which the Corporation would otherwise
have incurred separately. The Corporation expects its G&A costs to decrease in 2016 as a result of
reductions in the number of employees in the fourth quarter of 2015, and the expected delisting of
the Corporation from the TSX Exchange upon closing of the OER share buyout by Oando PLC and
Oando E&P Holdings Limited. During 2014 the Corporation incurred $84.9 million in relation to non-
reoccurring acquisition costs to effect the COP Acquisition. No acquisition costs were incurred in 2015.
The Corporation recognized net income of $79.6 million in the fourth quarter of 2015, compared to a
net loss of $232.0 million in the same quarter of 2014. The improvement in earnings during the fourth
quarter of 2015 was primarily attributed to the significant asset and joint venture receivable
impairment charges recognized in 2014 and the 2015 impairment reversal at OML 125, which were
partially offset by the reduction of net fair value gains on financial instruments and decreased income
from production activities in 2015. During the year ended December 31, 2015 net income was $16.1
million, which was a $311.6 million improvement from the $320.0 million loss recognized in 2014. The
increase in income between the periods was due to a decrease in non-recurring asset impairments
and the non-reoccurring acquisition expenses regarding the purchase of OMLs 60 to 63 recognized in
2014, which were offset by a significant decrease in net gains on financial instruments between the
periods. Production increased 119% in 2015 which led to greater production expenses and depletion
expense, however these expenses improved on a per boe basis compared with the same period of
2014. Production expenses improved to $11.99/boe in 2015, from $16.80/boe in 2014 and
depreciation, depletion and amortization (“DD&A”) expense improved to $6.57/boe in 2015, from
$9.74/boe in 2014. Net income in 2015 also included a non-recurring net loss from financial
instruments of $34.9 million, as a result of the early settlement and reset arrangements, along with a
non-recurring charge of $16.4 million in net financing expenses related to unamortized transaction
costs as a result of loan repayments in the first quarter of 2015.
During the year ended December 31, 2015 funds from operations increased $80.0 million to $181.3
million from $101.3 million generated in 2014. The increase in funds from operations during 2015 was
primarily a result of the acquisition of OMLs 60 to 63 on July 30, 2014 that added a full year of cash
flows in 2015, along with increased cash flows at Ebendo through enhanced production and Qua Ibo
being brought on-stream in 2015, all of which was partially offset by decreased revenues at OML 125
from lower crude oil prices. Furthermore, funds from operations in 2015 was also positively affected by
increased realized net gains on financial commodity contracts and a reduction in financing expenses,
compared to 2014.
As at December 31, 2015, the Corporation had a working capital deficiency of $835.8 million
(December 31, 2014 – $567.2 million) and an accumulated deficit of $621.2 million (December 31,
2014 – $638.1 million). In addition to its on-going working capital requirements, the Corporation must
secure sufficient funding to fund ongoing operations and commitments and repay at least $149.9
million in loan principal, as set out by loan repayment schedules. An additional $356.7 million of
borrowings was reclassified to current borrowings as a result of debt defaults; the defaults gives the
lenders associated with the Senior Secured Facility and Corporate Facility the ability to accelerate the
maturity of the loans on demand. The lenders chose not to exercise their acceleration rights under the
loans; despite this there can be no assurances that the lenders will not exercise these rights at a future
date. The Corporation has incurred significant levels of debt financing to finance on-going operations
and acquisitions. Furthermore, the decline in global oil prices has reduced cash flows from operations.
Global oil prices could remain at current low levels for 2016 and possibly longer, further impacting
revenues and operating cash flows and the ability of the Corporation to repay amounts due and its
various debt facilities. These circumstances lend significant doubt as to the ability of the Corporation
to meet its obligations as they come due and, accordingly, the appropriateness of the use of
accounting principles applicable to a going concern.
In February 2015, the Corporation entered into early settlement and reset arrangements with hedging
counterparties which resulted in the receipt of $226.2 million in net cash ($234.0 million including
scheduled February cash settlements) which was used to repay existing debt obligations. As a result of
the early settlement and reset arrangements, the Corporation has reduced short-term principal and
interest payments. In September 2015, the Corporation received consent from the lenders on the
Senior Secured Facility to remove the current ratio requirement. Also, as at December 31, 2015, the
Corporation has been advanced $83.9 million from the operator of OML 125; the arrangement with
the operator of OML 125, which is in line with the joint operating agreement, allows the Corporation
to defer the payment of cash calls until revenue from OML 125 is realized. In October 2015, the
Corporation increased the capacity of the senior secured facility by $90.7 million; proceeds from the
loan and cash on hand were used to repay the $100 million subordinated debt facility effectively
converting the $100 million obligation to a longer term obligation repaid over a 3-4 year period. By
repaying the $100 million loan, the Corporation expects a return of collateral of $50 million which was
advanced to Oando PLC to secure the letter of credit associated with the loan. Finally, in December
2015, the Corporation signed an agreement to sell its interest in OML 125 and 134 to the operator.
Despite these actions, requirements to maintain cash balances with the lenders and to repay principal
with excess cash from oil and gas sales (albeit at lower levels) remain. Furthermore, resetting the
hedges in the first quarter has reduced cash flow whilst also successfully decreasing debt levels.
During 2015, two unfortunate operational incidents occurred at facilities owned by the Nigerian Agip
Oil Company Joint Venture (“NAOC JV”), which is operated by Nigerian Agip Oil Company (“NAOC”).
The Corporation owns 20% of the NAOC JV. On June 28th, 2015 there was a fire involving three crude
storage tanks at the Ebocha flowstation in Rivers State, Nigeria, as a result of acts of sabotage. The fire
was successfully extinguished with no injuries, fatalities, or environmental spill. Most production in the
land area (LAR) was initially shut-in, leading to July production from crude oil, NGLs and natural gas
production being reduced by approximately 10,000 boe/day net during the month. Production was
restored near the end of July by the combination of installing booster pumps at the Ebocha terminal
and reconfiguring lines to bypass the storage facility, along with redirecting production along existing
pipelines. The Corporation estimates its share of repairs at $6.7 million. As a result the operator has
increased the level of security in and around the Ebocha terminal in conjunction with OER.
On July 9, 2015 a fire occurred during the inspection and repair of a crude theft point on Tebidaba-
Clough Creek Line, an oil pipeline in Nigeria's onshore Niger Delta. The incident resulted in the
unfortunate death of 14 members of the contractor’s inspection and repair team. The fire occurred
away from the repair point and pipeline, igniting some of the spilled hydrocarbon. The Corporation
expresses its deepest condolences to the families involved in this tragic accident. Investigations into
the immediate and remote causes of the fire have been carried out to ensure such an incident does
not occur again. The line was fully repaired and brought back on-stream during the quarter with
minimal interruption to production.
Selected Quarterly Results
The table below summarizes selected financial and operational information for the last eight quarters.
The Corporation’s quarterly results have been impacted primarily by acquisitions, fluctuating
commodity prices, asset impairments, gains and losses on financial instruments, and borrowing
activities.
Q4 Q3 Q2 Q1 Q4 Q3 Q2 Q1
2015 2015 2015 2015 2014 2014 2014 2014
Production (boe) 4,842,536 4,891,579 5,179,383 4,985,944 5,034,358 3,248,158 413,984 408,497
Total revenue 99,798 132,512 90,240 132,415 174,042 184,777 30,440 32,163
Net Income (loss) for the period 79,577 (13,107) (29,255) (21,096) (232,033) 89,541 (137,668) (39,881)
Earnings per share 0.10 (0.02) (0.04) (0.03) (0.29) 0.12 (0.24) (0.14)
Diluted earnings per share 0.10 (0.02) (0.04) (0.03) (0.29) 0.12 (0.24) (0.14)
Capital expenditures 8,321 22,505 19,127 37,804 41,206 52,910 24,355 42,550
Total assets 3,141,596 2,900,574 2,922,598 2,971,858 3,242,791 3,693,880 1,662,142 1,689,937
Total non-current liabilities 868,771 1,177,793 1,201,823 1,033,688 1,088,996 1,523,019 245,925 274,812
Figures in $’000 unless otherwise stated
Capital Expenditures
The corporation spent $8.3 million on capital expenditures in the fourth quarter of the 2015,
compared to $41.2 million in the fourth quarter of 2014. During 2015 the Corporation spent $87.8
million on capital expenditures related to the development of oil and gas assets and exploration and
evaluation activities, compared to $161.0 million in 2014.
The following provides a summary of 2015 focus area capital expenditures and compares the
budgeted expenditures to actual spending to date.
Actual Budgeted Budgeted
2015 2015 2016
OMLs 60 to 63 41,308 59,680 60,000
Qua Ibo (in OML 13) 3,755 3,590 850
Ebendo (in OML 56) 1,678 7,650 6,710
OML 125 36,373 67,130 -
Other assets, net 4,643 3,670 5,670
Capital expenditures, net 87,757 141,720 73,230
Figures in $’000 unless otherwise stated
OMLs 60 to 63
During 2015, capital expenditures on OMLs 60 to 63 totalled $41.3 million. Capital expenditures
during the period included $11.7 million spent on development drilling and completion activities in
the Ogbainbiri Deep 4 well, $27.5 million spent on pipeline and facility upgrades and $2.1 million
spent on geophysical exploration studies and other assets. The reduction of capital spending in 2015
compared to the budgeted amount was due to project delays and a reduction of spending as a result
of the lower crude oil and natural gas price environment.
In 2016, the Corporation estimates that a total of $60.0 million will be spent at OMLs 60 to 63,
consisting of $44.4 million directed to facilities for asset integrity, water disposal and flare down, and
$15.6 million on drilling three development wells and a workover.
Qua Ibo
In 2015, the Corporation incurred capital expenditures of $3.8 million at Qua Ibo on pipeline and crude
oil facility costs. The Qua Ibo field commenced production late February 2015 and realized its first
sales from production in the second quarter of 2015. The Corporation revised its 2015 budgeted from
$0.6 million capital spending to $3.5 million to account for additional facility requirements for water
handling, in addition to the previously planned facility enhancements.
In 2016, the Corporation has budgeted $0.9 million to be spent on gathering facilities and water
treatment facilities.
Ebendo
During 2015, the Corporation incurred $1.7 million in capital expenditures at Ebendo, which included
the pipeline facility enhancements and drilling site preparation costs.
Throughout 2016, the Corporation has estimated $6.7 million in capital expenditures for five well
workovers, a storage tank and Umugini pipeline upgrades.
OML 125
The Corporation incurred $36.4 million of capital expenditures during 2015 at OML 125 related to
gathering and transportation infrastructure enhancements and facility maintenance. The
enhancements included $23.1 million spent on Abo phase 3 gathering and transportation
construction, $4.2 million on well completion costs at Abo 12, $5.6 million on its floating production
storage and offloading vessel (“FPSO”) on capital maintenance, and $3.5 million on other capital
maintenance projects. The significant reduction of capital spending in 2015 compared to the
budgeted amount was primarily due to delaying planned projects as a result of the lower crude oil
and natural gas price environment to ration capital spending.
The Corporation has an agreement to divest of the OML 125 property in 2016 to the operator and has
currently classified the property as held for sale. The sale will generate $5.5 million in cash and reduce
cash call liabilities by $84.5 million. Therefore, no capital spending has been budgeted in 2016 at OML
125.
Other Assets
Other asset capital expenditures include spending on OML 131, OML 134 and EEL. During 2015 the
Corporation spent $4.7 million to advance exploration of the respective properties with geological
and technical studies.
In 2016, the Corporation estimates that $5.7 million will be expended on exploration projects and
corporate assets. The exploration is focused on OML 131, OML 145 and Block 5, to assess the
geological and geophysical aspects of the project areas, along with the environmental impacts
through technical studies and seismic acquisition.
Additionally, the Corporation has farmed out 65% of its participating interest in Block 5 for $7.4 million
to equalize past costs and will retain a 20% participating interest, with a 50% carry up to $9.0 million
each for both Phases II and III. The Corporation has also entered into an agreement to farm out 65% of
its participating interest in Block 12, retaining a 22.5% participating interest with a carry of the first
$2.0 million of OER’s portion of project costs. The farm-out for Block 12 is yet to be completed. The
Government of Sao Tome & Principe (through its national petroleum agency) hold 15% and 12.5%
carried interests in Blocks 5 and 12, respectively. Blocks 5 and 12 are prospective offshore exploration
projects in São Tomé and Príncipe within the Gulf of Guinea. The farmouts will allow for the projects to
move forward with minimal capital requirements and provide immediate cost recoveries.
Current Outlook
Operationally, 2015 has been a successful year for the Corporation notwithstanding broader
macroeconomic and commodity price challenges. Production remained relatively steady in 2015,
averaging 54,520 boe/day despite a number of operational incidents. In February 2015 OER used its
expertise to bring the Qua Ibo opportunity on-stream, which was its first in-house development
project from concept to development, through design and construction, up to commissioning of the
10,000 bbls/d crude processing facility and tie-in to the nearby FUN Group gathering facility, with the
production operatorship eventually being relinquished to the JV partner after commissioning. The
Corporation expects 2016 production to marginally decrease as a consequence of the scaled back
capital expenditures in 2015 and the continuation of natural gas pipeline constraints.
Financially, 2016 is expected to be a challenging year for the Corporation and the oil and gas industry
as a whole. Low crude oil prices have taken a toll on the Corporation’s finances. Throughout the
remainder of 2016 management only expects a modest improvement in crude oil prices. Therefore, in
response to the low prices, the Corporation has cooperated with its JV partners to cut operating costs
and has taken steps to decrease its monthly G&A expenses through employee reductions and the
intended delisting of the Corporation from the TSX upon completion of the OER share buyout.
The 2016 capital budget has been significantly reduced as a result of the decline in operating cash
flows and difficulties in raising equity in the oil and gas industry. Therefore, management has
concentrated its efforts on maximizing the immediate impact of capital spending by focusing on
essential asset integrity projects, production optimization projects with immediate returns, and facility
projects that will increase production and decrease per boe operating costs. In rationalizing capital
spending, management anticipates minimal exploration spending to hold blocks due to the
significant capital requirements and long-term nature of those opportunities. However, exploration
will continue at Blocks 5 and 12 by means of farmouts and equalizing of capital spent to provide an
immediate return and future upside. The Corporation looks forward to improving cash flow and
working capital deficit by divesting of its interest in OML 125 and 134, which has been operating at a
deficit.
Non-GAAP Measures
Funds from Operations
Funds from operations is not a measurement defined in IFRS, but is a financial term commonly used in
the oil and gas industry. The Corporation believes that in addition to cash flows from operating
activities as reported in the consolidated statements of cash flows, funds from operations is a useful
supplemental measure, as it provides an indication of the funds generated by OER’s principal business
activities prior to adjusting for proceeds from early hedge settlements and changes in non-cash
working capital. The Corporation considers this to be a key measure of performance as it
demonstrates its ability to generate cash flow necessary to fund growth through additional capital
investments. Funds from operations may not be directly comparable to similar measures presented
by other companies, as there is no standardized measure. A reconciliation of funds from operations to
cash flows from operating activities is available under results of operations in the Company’s MD&A
for the three and twelve months ended December 31, 2015.
About Oando Energy Resources Inc. (OER)
About Oando Energy Resources Inc. (OER) OER currently has a broad suite of producing, development
and exploration assets in the Gulf of Guinea (predominantly in Nigeria).
Cautionary Statements
More information about the Company's oil and gas assets, including cautionary language regarding
the estimation of reserves and resources, can be found in the most recent Form 51-101F1 filed under
the Company's profile on SEDAR at www.sedar.com. "Gross" or "gross" means, when used in relation to
production, reserves and resources, OER's working interest share of production, reserves and
resources before deduction of royalties. "Net" or "net" means, when used in relation to production,
reserves and resources, either OER's working interest share of production, reserves and resources after
deduction of royalties or OER's entitlement to production reserves and resources after deduction of
royalties and PPT for production sharing contracts. In relation to OER's interest in wells, "Net" or "net"
means the number of wells obtained by aggregating OER's working interest in each of its gross wells.
In relation to OER's interest in property, "Net" or "net" means the total area in which OER has an
interest multiplied by the working interest owned by OER. "WI" means with respect to interests
governed by a JOA, PSC, farm-in agreement or farm-out agreement, the undivided interest of such
party (expressed as a percentage of the total interests of all parties in the contract) in the rights and
obligations derived from such contract, which may be an operating or non-operating interest.
Oil and Gas Equivalents
Production information is commonly reported in units of barrel of oil equivalent ("boe" or "Mboe" or
"MMboe") or in units of natural gas equivalent ("Mcfe" or "MMcfe" or Bcfe"). However, boe's or Mcfe's
may be misleading, particularly if used in isolation. A boe conversion ratio of 6 Mcf = 1 barrel, or a Mcfe
conversion ratio of 1 barrel = 6 Mcf, is based on an energy equivalency conversion method primarily
applicable at the burner tip and does not represent a value equivalency at the wellhead. Readers are
cautioned that boe may be misleading, particularly if used in isolation.
Forward Looking Statements
This news release contains forward-looking statements and forward-looking information within the
meaning of applicable securities laws. The use of any of the words "expect", "anticipate", "continue",
"estimate", "objective", "ongoing", "may", "will", "project", "should", "believe", "plans", "intends" and
similar expressions are intended to identify forward-looking information or statements. In particular,
this news release contains forward-looking statements relating to intended acquisitions.
Although the Company believes that the expectations and assumptions on which such forward-
looking statements and information are reasonable, undue reliance should not be placed on the
forward-looking statements and information because the Company can give no assurance that such
statements and information will prove to be correct. Since forward-looking statements and
information address future events and conditions, by their very nature they involve inherent risks and
uncertainties.
Actual results could differ materially from those currently anticipated due to a number of factors and
risks. These include, but are not limited to: risks related to international operations, the integration of
assets acquired under the COP acquisition, the actual results of current exploration and drilling
activities, changes in project parameters as plans continue to be refined and the future price of crude
oil. Accordingly, readers should not place undue reliance on the forward-looking statements. Readers
are cautioned that the foregoing list of factors is not exhaustive.
Additional information on these and other factors that could affect the Company's financial results are
included in reports on file with applicable securities regulatory authorities and may be accessed
through the SEDAR website (www.sedar.com) under the Company. The forward-looking statements
and information contained in this news release are made as of the date hereof and the Company
undertakes no obligation to update publicly or revise any forward-looking statements or information,
whether as a result of new information, future events or otherwise, unless so required by applicable
securities laws.
For further information:
Pade Durotoye, CEO
Oando Energy Resources Inc.
pdurotoye@oandoenergyresources.com
+1 403- 561-1713
Tokunboh Akindele, Head Investor Relations
Oando Energy Resources Inc.
takindele@oandoenergyresources.com
+1 403-560-7450
Nigeria
30 March 2016
Sponsor: Sasfin Capital (a division of Sasfin Bank Limited)
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