Kurdistan News – Page 25 – Cursor international

28 February, 2018

Report: Shaping Iraq’s Oil and Gas Future

By John Lee.

A new report for the Atlantic Council argues that gas, being less politically fraught than oil, has the potential to serve as a key area of cooperation between Baghdad and Erbil and could help improve the reliability of electricity supply.

In Shaping Iraq’s Oil and Gas Future, Ellen Scholl recommends that:

Baghdad and Erbil must get the incentive structure right. Part of the incentive structure should include supportive gas pricing.
Institutions should mirror ambition.
Baghdad and Erbil should take a comprehensive approach to developing and integrating infrastructure throughout the supply chain, including mid- and downstream infrastructure.

The full report can be downloaded here.

(Source: Atlantic Council)

21 February, 2018

Chevron Resumes Drilling in Kurdistan

By John Lee.

Chevron has reportedly announced that it had resumed drilling operations at the Sarta-3 well in Iraqi Kurdistan.

The US company temporarily suspended operations in October following the controversial independence referendum, which increased tensions between Baghdad and Erbil.

According to Kurdistan 24, it currently operates and holds an 80-percent contractor interest in two production-sharing contracts covering the Sarta and Qara Dagh blocks.

(Sources: Reuters, Kurdistan 24)

18 February, 2018

KRG pays Genel under Receivable Settlement Agreement

Genel Energy plc has announced that it has received an override payment of $7.05 million from the Kurdistan Regional Government (KRG).

The payment represents 4.5% of Tawke gross field revenues for the month of November 2017, as per the terms of the Receivable Settlement Agreement.

Taken together with the monthly entitlement payments for Taq Taq and Tawke announced yesterday, Genel’s net share of payments relating to November 2017 exports totals $26.81 million.

(Source: Genel Energy)

14 February, 2018

Genel Updates on Oil Reserves

By John Lee.

Genel Energy has announced the completion of competent person’s reports (‘CPRs’) relating to the oil reserves and resources at Taq Taq, Bina Bawi, and Miran.

McDaniel and Associates have updated the CPR relating to the Taq Taq field (Genel 44% working interest, joint operator).

RPS Energy Consultants Ltd. (‘RPS’), as part of its work on the updated CPRs for the Bina Bawi and Miran West fields (Genel 100% and operator), has finalised its evaluation of the oil resources at both fields.

Murat Özgül (pictured), Chief Executive of Genel, said:

“The 40% replacement of 1P reserves at Taq Taq follows the success of well TT-29w, and reflects the stability in cash-generative production that we have seen from the field in the second half of 2017. The significant increase in high-value Bina Bawi 2C oil resources offers a tangible opportunity for near-term value creation.”

Taq Taq oil reserves

Taq Taq gross 2P reserves as of 31 December 2017 are estimated by McDaniel at 54.7 MMbbls, compared to 59.1 MMbbls as of 28 February 2017, with the difference being production in the intervening period, partly offset by a small upward technical revision.

The CPR results in a 12% reserves replacement for 2P and 40% reserves replacement at the higher confidence 1P level as a result of stabilising production and the integration of well TT-29w. A reconciliation from the reserves reported in the CPR released in February 2017 to the updated estimates in the CPR published today, is shown in the following table:

Gross oil reserves (MMbbls – McDaniel)	1P	2P	3P
28 February 2017	25.8	59.1	95.0
Production	(5.0)	(5.0)	(5.0)
Technical revisions	2.0	0.6	0.1
31 December 2017	22.8	54.7	90.1

Bina Bawi and Miran oil resources

Bina Bawi gross 2C light (c.45◦ API) oil resources as of 31 December 2017 are estimated by RPS at 37.1 MMbbls, compared to 13 MMbbls as of July 2013. The increase reflects higher recovery factors than initially estimated due to integrating learnings from analogue carbonate fields of similar oil quality. As the high-quality Bina Bawi oil is in close proximity to export infrastructure, the field represents a potentially attractive near-term development candidate for the Company.

Miran West gross 2C heavy (c.15◦ API) oil resources as of 31 December 2017 are estimated by RPS at 23.7 MMbbls, compared to 52 MMbbls as of April 2013. Volumes have reduced as RPS has adjusted its view on the oil water contact uncertainty range and also adjusted its view on reservoir properties, including data from MW-5 drilled in July 2013.

Because of field experience at Taq Taq, Genel management has taken the view that it is unlikely that any matrix will contribute to primary depletion at Miran and, as such, has taken a more conservative view and will only record 18.5 MMbbls of viable 2C contingent resources at the field.

	Gross 2C Contingent Resources oil (MMbbls – RPS)
	2013	31 December 2017
Bina Bawi	12.9	37.1
Miran West	52.0	23.7

Appendix

Summary of Contingent Resources – Development unclarified (Gross 100% working interest basis) attributable to the Bina Bawi and Miran West fields as of 31 December 2017.

Gross (100% WI) Contingent Resources		Gross (100% WI) Contingent Resources
Bina Bawi	Oil (MMbbls – RPS)	Miran West	Oil (MMbbls – RPS)
1C	15.2	1C	6.1
2C	37.1	2C	23.7
3C	78.4	3C	67.6

(Source: Genel Energy)

9 February, 2018

Iraq signs Deal for Kirkuk Refinery

By John Lee.

Iraq’s Oil Ministry has announced that it has signed an agreement to build a 70,000-bpd oil refinery near Kirkuk.

The statement said the refinery would be built by “Rania international company“, which Reuters refers to as Ranya International, which it says is based in Iraqi Kurdistan.

The plant will produce high octane gasoline and other petroleum products.

(Source: Ministry of Oil, Reuters)

8 February, 2018

DNO: Revenues and Investment Rise Sharply

DNO ASA, the Norwegian oil and gas operator, today announced a 50 percent hike in 2018 spending in the Kurdistan region of Iraq to USD 250 million net to the Company on the back of higher revenues and regular export payments.

Annual 2017 revenues stood at USD 347 million, up 72 percent from 2016, bolstered by fourth quarter revenues of USD 116 million, the highest quarterly level in more than three years.

The Company fast tracked the development of the Peshkabir field with two wells currently producing a total of 16,000 barrels of oil per day (bopd) and commingled for export with another 97,000 bopd from the other DNO-operated field, Tawke, on the same license.

DNO’s Executive Chairman Bijan Mossavar-Rahmani:

“We made the Peshkabir Cretaceous discovery early in 2017, initiated early production in June, tripled output by year’s end and already have exported two million barrels with an estimated value of USD 100 million – more than twice the investment to date. And we have only started to appraise and develop this field which continues to surprise to the upside.”

A total of six Peshkabir wells will be drilled this year with field production expected to reach 30,000 bopd by summer and continue to ramp up in the second half of the year.

At the Tawke field, plans are being finalized with partner Genel Energy plc to drill four wells in 2018, in addition to the currently drilling Tawke-48 well slated for completion by end-February.

Elsewhere in Kurdistan, DNO has re-entered and sidetracked the Hawler-1 well to appraise the Benenan heavy oil field in the Erbil license, achieving a technical milestone with the first ever multilateral well and the first ever dual completion in Kurdistan. Testing will commence shortly, and if successful, will be followed by additional wells.

The Company received 12 monthly Kurdistan export payments during 2017 totaling USD 380 million net to DNO. The landmark August 2017 receivables settlement agreement, which increased DNO’s stake in the Tawke and Peshkabir fields from 55 percent to 75 percent plus three percent of gross license revenues over five years, contributed to higher export payments.

Operational cash flow more than tripled to USD 339 million in 2017 and DNO exited the year with a net cash position of USD 30 million versus net debt of USD 139 million at end-2016.

(Source: DNO)

8 February, 2018

DNO: Revenues and Investment Rise Sharply

Annual 2017 revenues stood at USD 347 million, up 72 percent from 2016, bolstered by fourth quarter revenues of USD 116 million, the highest quarterly level in more than three years.

DNO’s Executive Chairman Bijan Mossavar-Rahmani:

A total of six Peshkabir wells will be drilled this year with field production expected to reach 30,000 bopd by summer and continue to ramp up in the second half of the year.

At the Tawke field, plans are being finalized with partner Genel Energy plc to drill four wells in 2018, in addition to the currently drilling Tawke-48 well slated for completion by end-February.

Operational cash flow more than tripled to USD 339 million in 2017 and DNO exited the year with a net cash position of USD 30 million versus net debt of USD 139 million at end-2016.

(Source: DNO)

25 January, 2018

Genel Energy Updates on Operations in Kurdistan

Genel Energy has issued a trading and operations update in advance of the Company’s full-year 2017 results, which are scheduled for release on 22 March 2018. The information contained herein has not been audited and may be subject to further review.

Murat Özgül, Chief Executive of Genel, said:

“A strong final quarter of 2017 completed a very positive year for Genel. During the quarter, the successful Peshkabir-3 well result tripled production at the field to c.15,000 bopd, a figure that is expected to grow in 2018, while at Taq Taq the TT-29w well was brought on production.

“Payments for oil sales were received from the Kurdistan Regional Government (‘KRG’) in every month of 2017, totalling over $260 million net to Genel and leading to $140 million of free cash flow in the year. The 2017 payments were bolstered by the receipt of override payments in the fourth quarter under the Receivable Settlement Agreement (‘RSA’), and payments have continued in early 2018.

“The recently announced CPRs reaffirmed the potential of the Bina Bawi and Miran fields, with combined 1C gross raw gas resource estimates higher than the gas volumes agreed under the Gas Lifting Agreements. The upstream field development plans are expected to complete shortly, and will help define the roadmap to unlocking the value in these major resources.

“The successful debt refinancing in late 2017, and the expectation of ongoing material free cash flow, provides us with a solid platform and financial flexibility to execute our growth plans during 2018 and beyond.“

2017 OPERATING PERFORMANCE AND 2018 ACTIVITY OUTLOOK

2017 net production averaged 35,200 bopd, with Q4 averaging 32,760 bopd. Production and sales by asset during 2017 was as follows:

(bopd)	Export via pipeline	Refinery sales	Total sales	Total production	Genel net production
Taq Taq	11,700	6,350	18,050	18,050	7,940
Tawke PSC	108,250	10	108,260	109,050	27,260
Total	119,950	6,360	126,310	127,100	35,200

Note: Difference between production and sales relates to inventory movements

Tawke PSC (Genel 25% working interest)
- Tawke PSC production averaged 109,050 bopd in 2017, with aggregate production from the Peshkabir-2 and Peshkabir-3 wells contributing 3,590 bopd to this figure. Combined production from the two fields currently averages c.110,000 barrels of oil per day
- Preparations are underway to drill the Peshkabir-4 well. Additional drilling activity is planned on both the Tawke and Peshkabir fields during 2018, with overall activity levels dependent on production performance, drilling results, field studies, and ongoing payments from the KRG
Taq Taq PSC (Genel 44% working interest and joint operator)
- Taq Taq field production averaged 18,050 bopd in 2017
- Production in Q4 2017 averaged 14,035 bopd (Q3 2017 14,080 bopd). Ahead of the completion of a number of wells in Q4 2017, the overall rate of production decline slowed during the year due to the implementation of a proactive well intervention and production optimisation programme
- In 2018 to date, production from Taq Taq has averaged 14,540 bopd, with the TT-29w, TT-30, and TT-31 wells contributing to the stabilisation in production from the beginning of Q4
- As previously announced in late 2017, the TT-29w well was brought onto production after encountering a deeper free water level and more extensive oil bearing cretaceous reservoirs on the northern flank of the field than previously forecast. The results of the well will be analysed ahead of finalising the 2018 drilling programme, with field activity likely to be weighted towards the second half of the year. The ongoing Taq Taq well intervention programme, focused on the provision of artificial lift and water shut off in existing wells, will continue throughout 2018
- Going forward, the Company will revert to reporting Taq Taq field production on a quarterly basis, as part of its corporate level disclosures
Bina Bawi and Miran (Genel 100% and operator)
- As announced on 23 January 2018, Genel has agreed a 12 month extension to the conditions precedent schedule contained within the Gas Lifting Agreements for the Bina Bawi and Miran PSCs
- CPRs for the Bina Bawi and Miran West gas fields concluded a c.40% increase in the combined 2C gas resources compared to the pro-forma end-2016 2C resource
- The field development plans, being carried out by Baker Hughes, are on schedule to be completed shortly, and will help define the roadmap to unlocking the value of the assets
- Genel will continue its systematic efforts to maximise the value of Bina Bawi and Miran, which includes optimising the cost and schedule of the proposed upstream developments
  - § In 2018 Genel expects to undertake an extended well test of Bina Bawi-4, which will provide valuable data on well deliverability and gas composition
- The Company will continue to build momentum behind the development of Bina Bawi and Miran, and will continue engagement with potential farm-in partners for upstream participation at an optimal time to secure maximum value for Genel shareholders
African exploration update
- Onshore Somaliland, the acquisition of 2D seismic data on the SL-10B/13 (Genel 75%, operator) and Odewayne (Genel 50%, operator) blocks has now completed – the first time that seismic has been obtained in this highly prospective area for over 25 years. The project acquired c.3,150 km in total, including infill 2D seismic acquisition of targeted high-graded areas. Processing of the data has commenced, and will facilitate seismic interpretation and the associated development of a prospect inventory, in turn guiding the optimal strategy to maximise future value
- As announced in November 2017, Genel’s prior commitment to drill one well on the Sidi Moussa licence, offshore Morocco (Genel 60% working interest), has been replaced by an obligation to carry out a 3D seismic campaign across the Sidi Moussa acreage, significantly reducing anticipated expenditure. Planning is ongoing, with seismic acquisition set to begin in 2018, which is expected to materially de-risk the prospectivity of the Sidi Moussa licence

FINANCIAL PERFORMANCE

$263 million of cash proceeds were received in 2017 ($207 million in 2016), of which $72 million was received in Q4
Following the signing of the Receivable Settlement Agreement, effective 1 August 2017:
- $19 million in override payments for the Tawke field were received in Q4
- An additional $7 million of cash flow was generated from the elimination of the capacity building payment on Genel’s profit oil from the Tawke PSC
$19 million in payments for oil sales during October 2017 received post-period in January 2018
Free cash flow (pre interest payments) totalled $140 million in 2017
In December 2017, the Company successfully completed the refinancing of its existing bonds, reducing the outstanding bond debt from $421.8 million to $300 million by way of an early redemption of a notional amount of $121.8 million. The new 5 year bond has a coupon of 10% per annum
Following the successful refinancing, unrestricted cash balances at 31 December 2017 stood at $162 million ($268 million at 30 September 2017). IFRS net debt at 31 December 2017 stood at $135 million ($138 million at 30 September 2017)
Capital expenditure for 2017 totalled $95 million (in line with guidance), with the majority of spend on the Taq Taq and Tawke PSCs ($64 million)

2018 GUIDANCE

Combined net production from the Tawke and Taq Taq PSCs during 2018 is expected to be close to Q4 2017 levels (as disclosed above)
Capital expenditure net to Genel is forecast to be c.$95-140 million, spanning a range of firm and contingent spend, with activity levels dependent on ongoing drilling results and progress on Miran and Bina Bawi. It is expected that capex will be funded entirely from operational cash flow, and includes:
- Tawke and Taq Taq net to Genel of $60-85 million
- Miran and Bina Bawi capex of $25-40 million
- African exploration cost of $10-15 million
Opex: c.$30 million
G&A: c.$15 million cash cost
Based on a continuation of payments throughout 2018, Genel expects to generate material free cash flow in 2018

(Source: Genel Energy)

24 January, 2018

Genel Energy gets more time for Gas Project

Genel Energy has announce that it has agreed with the Kurdistan Regional Government (KRG) a 12 month extension to the schedule for satisfying the conditions precedent (‘CPs’) contained within the Gas Lifting Agreements (‘GLA’s) for the Bina Bawi and Miran fields signed in February 2017.

The revised date by which the CPs are to be satisfied or waived is 9 February 2019.

The CPs contained within the February 2017 GLAs included, inter alia, the execution of final agreements on the midstream gas processing facilities and pipeline transportation, and the completion of updated competent person’s reports (‘CPRs’) for Bina Bawi and Miran.

The CPRs relating to the contingent gas resources at the Bina Bawi and Miran West fields have recently been completed, details of which were announced on 19 January 2018.

(Source: Genel Energy)

22 January, 2018

GKP to Invest Further in Shaikan

Gulf Keystone Petroleum (GKP), operator of the Shaikan Field in the Kurdistan Region of Iraq, is today providing an operational and corporate update.

This is in advance of the Company’s full year results for the period ended 31 December 2017 which are expected to be announced on Wednesday 11 April 2018. The information contained herein has not been audited and may be subject to further review and amendment.

Operational Update

GKP has continued its strong safety performance in 2017 and into 2018 with no lost-time incidents at the Shaikan field. Operations in the area remain secure.
Plant uptime of 99% in 2017 helped contribute to an average gross production of 35,298 barrels of oil per day (“bopd”), in the middle of our guidance range of 32,000-38,000 bopd for the year.
Since 15 November 2017, the Kurdistan Regional Government’s (“KRG”) Ministry of Natural Resources (“MNR”) has resumed exporting the Shaikan crude via the export pipeline to Turkey. The Company sees the latest export development as confirmation of the suitability of the Shaikan crude within the Kurdish blend.
The Company was encouraged by the signature of the crude oil sales agreement announced on 16 January 2018. The Company is also in dialogue with the MNR on the terms of a potential 2^nd PSC Amendment.
Subject to resolution of the commercial matters and the KRG continuing regular payment of monthly invoices, the Company currently intends on investing this year in wells and facilities to expand production capacity to 55,000 bopd.
Part of these investments would include the hook-up of a short (400m) spur pipeline from Production Facility 2 to the Atrush export line, which links to the main export oil line to Turkey. This will reduce trucking requirements, HSE risk and improve netbacks.
Final investment plans for 2018 are under review and will be provided to the market in due course.