Atrush Field

Atrush Field is a Jurassic fractured carbonate oilfield near Dohuk, Iraqi Kurdistan. It was discovered by the Consortium of General Exploration Partners. As of March 12, 2013 the Kurdistan Regional Government (KRG) has exercised its option to acquire a 25% Government Interest of the Atrush Field according to the PSC contract.[5]

Atrush Field
Location of Atrush Field
CountryIraq
RegionDohuk
LocationSheikan district
Offshore/onshoreOnshore
Coordinates36°51′48″N 43°27′1″E[1]
OperatorsTAQA (47.4%)
PartnersKurdistan Regional Government (25%) ShaMaran Petroleum Corp. (27.6%)
Field history
DiscoveryApril 13th 2011[2]
Start of productionJuly 3rd, 2017[3]
Production
Current production of oil45,000 barrels per day (~2.2×10^6 t/a)
Estimated oil in place296 million barrels (~4.04×10^7 t)
Recoverable oil102.7 million barrels (~1.401×10^7 t)
Producing formationsJurassic fractured carbonate[4]

General Exploration Partners (GEP) held 80% of Atrush and was in cooperation with Aspect Energy International, who owned 2/3 of GEP, thus Aspect Energy International had a share of 53,2%. Aspect Energy International sold its interest in GEP to TAQA for $600 mln,[6] which basically transferred Aspect's interest in GEP to TAQA. Shamaran's interest remained at 26,8% of Atrush, and the remaining 20% is held by Marathon Oil.[7]

In June, 2018 Shamaran Petroleum announced that it intends to purchase Marathon Petroleum's 15% share of the Atrush Block.,[8] with effect from Jan 1, 2018. ShaMaran will acquire all shares of MOKDV - Marathon’s Dutch subsidiary for USD 63m. ShaMaran will then sell 7.5% working interest to Taqa for USD 33m. The sale is expected to close in the first quarter of 2019.[9]

Oil began flowing through the Atrush Central Production Facility on July 3, 2017.[3] In September 2017, an agreement for the sale of Atrush oil was signed between TAQA, its partners and the KRG. Under the agreement, the KRG will buy oil exported from the Atrush field by pipeline at the Atrush block boundary. The quality of the oil will force a price adjustment of approximately $16/bbl lower than the dated Brent oil price. All local and international transportation costs will be an additional fee. This discount is based on the principles similar to other oil sales agreements in the Kurdistan Region of Iraq.[10]

Atrush Field Naming Conventions

In 2014 after a meeting of the Atrush Management Committee and the KRG Ministry of Natural Resources changes in terminology used with respect to activity in the Atrush Field were made:[11]

  • “Atrush Block”, “Atrush PSC” & “Atrush Field” were unchanged.[11]
  • The structure (previously referred to as the “Atrush structure”) is renamed after the Chiya Khere mountain, i.e. the Chiya Khere structure.[11]
  • All production facilities will be known as the Chiya Khere facilities.[11]
  • Future wells will remain sequential but will be referred to as “Chiya Khere”, short-form “CK”, commencing with well #5.[11]
  • Well pads will be known as Chamanke A, B, etc.[11]
  • Historic wells, AT-1 through AT-4, will retain their original nomenclature.[11]

Wells

Atrush-1 (AT-1) Well

Atrush-1 (AT-1) well was successfully spudded on October 5, 2010. The well had a natural flow of 6,393 barrels of oil per day. General Exploration Partners discovered 726 meters of oil column and 120 meter netpay. The well has since been permanently abandoned [9][2][12]

Atrush-2 (AT-2) Well

Atrush-2 (AT-2) well was successfully spudded on May 23, 2012. The well had a flow of 42212 barrels of oil per day using a Submersible pump,[13] estimated to have been the highest flow ever in Iraqi Kurdistan.[14] The design of the DST Program, as well as the permanent completion, was managed by Daniel Riedel, Richard Sharpe, Damon Yarshenko, and Wes Whitman with key execution support provided by core contractors. AT-2 was completed for production in Q3 of 2016.[4]

Atrush-3 (AT-3) Well

Atrush-3 (AT-3) well was believed the well spudded on the 26th of March 2013 but there is no information confirming this for now.[5]

AT-3 Well Summary
  • In December 2018 the well was worked over as a heavy oil production well and is now ready for the heavy oil extended well test.[9]

Atrush-4 (AT-4) Well

Drilled in 2014, Atrush-4 (AT-4) well is the second well to be drilled in support of the Phase One Facility.[11]

AT-4 Well Summary
  • High-angle deviated well. 82° was the maximum hole angle. This demonstrated that the field could be developed, using directional wells in the face of extremely rugged terrain.[11]
  • The well was drilled from the AT-1 pad, which is correctly known as Chamanke-A.[11]
  • The Jurassic reservoir is approximately 72m higher than when it was encountered in AT-1.[11]
  • Two limited well tests were performed for fluid samples.[11]
  • The combined rate of fluid production was over 9,000 barrels (1,400 m3) of oil per day of 26°API oil.[11]
  • There wasn't an indication of a gas cap.[11]
  • An interference test was also conducted. The test demonstrated instantaneous pressure communication with AT-2.[11]
  • AT-4 was suspended as Phase One Facility producer.[11]
  • AT-4 was completed for production in Q3 of 2016.[4]
  • Clean-up attempts were made during 2018, but resulted in disappointing productivity the well is now awaiting work-over for a smaller pump.[9]

Chiya Khere-5 (CK-5) Well

Chiya Khere-5 (CK-5) well[11] was completed in Q3 of 2015.[4]

Chiya Khere-6 (CK-6) Well

Chiya Khere-6 (CK-6) Phase 2 appraisal well has a total depth of 2,105 metres. The TAQA-operated well reached TD on November 5, 2014, after 36 operational days. Part of the eastern part of the Atrush block the well is located on the Chamanke C pad. This pad is also the location of AT-3. CK-6 is a directional well, drilled in SSE direction from the surface. CK-6 encountered the Jurassic age reservoir at a higher elevation (≈139 metres) than the nearby AT-3 well.[15] As of January 2019 the well is awaiting a work over to become an observation well during the heavy oil extended well test of AT-3.[9]
The well was recompleted in February 2019 and came online for production in May 2019 at 4,500 barrels (720 m3) of oil per day.[16]

Well Testing
DST #1[15]
  • Formation: Alan[15]
  • Perforated interval: 12 metres[15]
  • Using an Electric Submersible Pump (ESP) and nitrogen lift the heavy oil was produced at a low rate.[15]
  • The test interval was the deepest from which oil has been recovered. At -460 m below sea level, the CK-6 oil was found to be almost 200 m deeper than the oil recovered from the equivalent reservoir in well AT-2.[15]
  • The viscosity of the recovered oil was lower than the oil from AT-2.[15]

Chiya Khere-7 (CK-7) Well

Chiya Khere-7 (CK-7) appraisal and development well drilling operations commenced prior to September 19, 2017. CK-7 is located in the central area of the Atrush Block. The producing well, AT-2, is approximately 3 kilometres to the east, while AT-3 is 3.5 kilometres to the west. The well is most likely being drilled from the Chamanke E pad. The objectives are to add another producing well by appraising the Mus formation's commercial potential and to reduce the uncertainty in determining the depth of the medium to the heavy oil transition zone. The well is expected to reach the 1,575 metre Total Depth within 52 days, using the Romfor 25 drilling rig.[17]

Chiya Khere-8 (CK-8) Well

Chiya Khere-8 (CK-8) well[11] was completed in Q3 of 2015[4]

Chiya Khere-9 (CK-9) Well

Chiya Khere-9 (CK-9) water disposal well, was drilled successfully as planned and is ready for water injection.[9]

Chiya Khere-10 (CK-10) Well

Chiya Khere-10 (CK-10) well was drilled in June 2018[18] and tied into the facility in July 2018.[19]

Chiya Khere-11 (CK-11) Well

Chiya Khere-11 (CK-11) is a deviated infill production well, located on the Chamanke-G pad, that was spud on 3 January 2019, the Sargelu formation is the target.[9]
The well was drilled to its final depth by mid-March, came online for production on May 10, 2019, produced at 5,500 barrels (870 m3) of oil per day (during July 2019)[20] and increased to 8,500 barrels (1,350 m3) of oil per day in September 2019.[21]

Chiya Khere-12 (CK-12) Well

Chiya Khere-12 (CK-12) is a 2,400 metre deviated infill production well, located on the Chamanke-E pad[22] that was spud in 2019, the well was brought on production in Q3 2019.[23]
CK-12 was drilled to its final depth at the end of May 19, 2019, where the reservoir was found to be 25 metres deeper than the prognosis indicated. CK-12 well was left cased and suspended until a workover rig was used to complete CK-12 in July 2019. Production commenced on August 10, 2019. CK-12 is currently producing at a rate of 2,000 barrels (320 m3) of oil per day from the Mus Formation.[24]

Chiya Khere-13 (CK-13) Well

Chiya Khere-13 (CK-13) located on Chamanke-E, is a 2,340m deviated infill production well that was spud in June 2019,[25] drilled to TD by August 19, 2019 and brought on production on September 18, 2019 at a rate of 6,000 barrels (950 m3) of oil per day. This well also encounted the target formation at a lower than expected depth, 23 metres lower to be exact.[26] The failure by TAQA's development geologist, well operation geologist and the geological manager to accurately forecast formation depths is rumoured to be a sore point within the partnership.

Chiya Khere-14 (CK-14) Well

No mention of CK-14 has ever been publicly announced.

Chiya Khere-15 (CK-15) Well

Chiya Khere-15 (CK-15) is a deviated infill production well at the Chamanke-G drilling location. The well was spudded on October 5, 2019 and is targeted to come online in December 2019.[27]

Heavy Oil Extended Well Test (HOEWT)

During 2018 the operator installed heavy oil well testing equipment. The equipment will provide 5,000 barrels (790 m3) of oil per day additional processing capacity at the Chamanke C pad, where AT-3 is located. Heavy oil production to should begin in February 2019.[9]
In fact, the HOEWT was delayed until mid-April.,[28] the well was brought on production in Q3 2019.[23]

Future wells

Drill and Complete three to four more production wells (including CK-11, CK-12, CK-13 and CK-15) during 2019.[29]

Producing Wells

The five producing wells: Atrush-2, (“AT-2”) Chiya Khere-5 (“CK-5”), Chiya Khere-7 (“CK-7”), Chiya Khere-8 (“CK-8”) and Chiya Khere-10 (“CK-10”).[30] In 2019, Chiya Khere-6 (“CK-6”), Chiya Khere-11 (“CK-11”), Chiya Khere-12 ("CK-12"), and Chiya Khere-13 ("CK-13") have also been added as production wells.[23] In December 2019, Chiya Khere-15 ("CK-15") was also listed as a production well.[31]

Wells Pads
  • Chamanke A[9] Construction completed, AT-1, AT-4, CK-5 and CK-8 were drilled here.
  • Chamanke B[9] Construction completed, AT-2 was drilled here, the pad is commonly referred to as PF-1 as it is the home of the Production Facility.
  • Chamanke C[9] Construction completed, AT-3 and CK-6 were drilled here. This is where the heavy oil extended well test will occur.
  • Chamanke D[4] Proposed location is 2 km west of Chamanke A
  • Chamanke E[9] Construction completed, the location is 2 km east of Chamanke B and is the site of CK-7, CK-10, CK-12 and CK-13
  • Chamanke F[4] Proposed location is east of Chamanke C
  • Chamanke G[9] Construction completed, the location is northeast of Chamanke B and CK-9, CK-11 and CK-15 were drilled from here.

Facilities

A 30,000 barrels (4,800 m3) of oil per day Phase 1 facilities has been completed.[32] As of September 29, 2017 the facility has achieved a regular daily export of more than 22,000 barrels (3,500 m3) of oil equivalent.[10] Facility production is expected to increase to 30,000 barrels (4,800 m3) of oil equivalent per day during 2017.[10]
In June 2018 Shamaran Petroleum reported a partial blockage of the production facility's heat exchanger. Sediment samples were analyzed and it was determined that the blockage was caused by salt. The most probable source of the salt might be drilling fluid losses from the drilling of CK-5 and AT-2. The heat exchanger was cleaned. A trial process of injecting freshwater at the CK-5 wellhead and separating saltwater out at the production facility's separator have significantly reduced the quantity of salt in the crude to be processed for export.
As of June 2018, approximately 20,000 barrels (3,200 m3) of oil per day of processed oil is being exported. Water injection at the wellhead will continue while gradually increasing production as the field personnel closely monitor the facility. Water injection is limited due to the small daily disposal capacity, once the CK-9 water disposal well is completed in the second half of 2018, the capacity will increase.[33] The average daily production for 2018 was about 22,200 barrels (3,530 m3) of oil per day, the rate at the end of December 2018, was 27,500 barrels (4,370 m3) of oil per day.[9]
During 2019, debottlenecking the 30,000 barrels (4,800 m3) of oil per day facility will occur.[9]

Average production for the month of November was 43,360 barrels (6,894 m3) of oil per day[34]

Pipeline
  • Pipeline project has been completed[32]
  • The pipeline is made up of 4 sections.[32]
    • A 25 centimetres (10 in) Spur line from the Phase 1 facility to the Intermediate pigging and pressure reduction station
    • A 30 centimetres (12 in) Spur line from the Intermediate pigging and pressure reduction station to the southern Atrush block boundary
    • A 30 centimetres (12 in) Feeder line from the southern Atrush block boundary to the Shaikan block's south boundary
    • A 91 centimetres (36 in) Feeder line from the Shaikan block's south boundary to the Kurdish Export Pipeline.

Monthly Production Data
Date Volume (bbl/d) Volume (m3/d) Comment
July 20174,800 760
August 201718,300 2,910
September 201721,400 3,400
October 201713,300 2,110Facility shut down to address production constraints
November 201725,400 4,040
December 201726,300 4,180
January 201826,600 4,230
February 201823,900 3,800
March 201820,200 3,210Back-produced salt plugs facilities
April 201811,900 1,890
May 201815,100 2,400
June 201820,100 3,200
July 201819,100 3,040Shut down to tie-in CK-7, CK-10
August 201821,400 3,400Frequent pipeline outages
September 201824,500 3,900Flushed stripper column
October 201826,800 4,260
November 201828,200 4,480
December 201827,500 4,370CK-10 ESP failure
January 201926,900 4,280
February 201923,500 3,7407day Export Pipeline Shutdown
March 201928,100 4,470
April 201929,000 4,600
May 201928,600 4,550Reboiler Flushing and CK-8 ESP Failure
June 201927,100 4,310CK-8 ESP Replacement
July 201933,900 5,390[35]CK-8 ESP Online
August 201935,300 5,610[36]CK-12 Online
September 201930,285 4,815
October 201938,040 6,048 [37]
November 201943,360 6,894[38]
December 2019

[9]

Pre-2019 numbers for barrels are rounded down to the nearest 100 barrels per day.[39]
2019 data without specific citations were generated using software to evaluate published charts. These numbers are estimates and could be subject to change.[40]

Estimated Reserves (December 31, 2017)
PROVED PROVED TOTAL PROBABLE TOTAL PROVED POSSIBLE TOTAL PROVED,
DEVELOPEDUNDEVELOPEDPROVED& PROBABLEPROBABLE & POSSIBLE
Light/Medium Oil (Mbbl)(1)
Gross(2)4,2113,0267,23712,38519,62212,02031,641
Net(3)2,9751,6734,6486,34710,9963,99914,995
Heavy Oil (Mbbl)(1)
Gross(2)-2822827451,0266851,711
Net(3)-181181394575236811

[41]

(1)The Atrush Field contains crude oil of variable density even within a single reservoir unit and as such the actual split between Light/Medium Oil and Heavy Oil is uncertain.[41]

(2)Shamaran gross reserves are based on the Shamaran’s 20.1 percent working interest share of the property gross reserves.[41]

(3)Shamaran net reserves are based on Shmaran's share of total Cost and Profit Revenues.[41]

Estimated Contingent Resources (December 31, 2017)
Contingent Resources
Light & Medium Oil (MBBL)(3) Heavy Oil (MBBL)(3) Naural Gas (MMCF)
Contingent Resources(1)(2)GrossShamaran Interest GrossShamaran Interest GrossShamaran Interest
100%Gross(4)Net(5) 100%Gross(4)Net(5) 100%Gross(4)Net(5)
Low Estimate (1C)67,79613,627N/A106,68021,479N/A25,4775,121N/A
Best Estimate (2C)68,75613,820N/A227,41245,710N/A46,8959,426N/A
High Estimate (3C)76,60615,398N/A372,87574,948N/A73,47714,769N/A
Risked Best Estimate55,00411,056N/A181,93036,568N/A2,343471N/A

[41]

Notes:

(1)There is no certainty that it will be commercially viable to produce any portion of the contingent resources.[41]

(2)The risked contingent resources take into account the chance of development which is defined as the probability of a project being commercially viable. Quantifying the chance of development requires consideration of both economic contingencies and other contingencies, such as legal, regulatory, market access, political, social license, internal and external approvals and commitment to project finance and development timing. As many of these factors are extremely difficult to quantify, the chance of development is uncertain and must be used with caution. The chance of development was estimated to be 80 percent for both Crude Oil types and 5 percent for the Natural Gas.[41]

(3)The Atrush Field contains crude oil of variable density even within a single reservoir unit and as such the actual split between Light/Medium Oil and Heavy Oil is uncertain.[41]

(4)Shamaran gross reserves are based on the Shamaran’s 20.1 percent working interest share of the property gross reserves.[41]

(5)Shamaran net reserves are based on Shmaran's share of total Cost and Profit Revenues.[41]

Atrush Map
Atrush Map

Atrush Field from space with the block boundary in red, taken September 4, 2018 by the European Space Agency - ESA produced from ESA remote sensing data image processed by SNAP Desktop 6.0.3

References
  1. http://www.shamaranpetroleum.com/i/pdf/CorporatePresentation_Sept2012.pdf
  2. "Archived copy". Archived from the original on 2013-10-01. Retrieved 2013-02-03.CS1 maint: archived copy as title (link)
  3. "Archived copy". Archived from the original on 2017-08-07. Retrieved 2017-07-25.CS1 maint: archived copy as title (link)
  4. https://www.shamaranpetroleum.com/site/assets/files/3675/2017-05-15-cp.pdf
  5. "Archived copy". Archived from the original on 2013-03-31. Retrieved 2013-03-29.CS1 maint: archived copy as title (link)
  6. "TAQA buys stake in Iraqi Kurdistan oil block for $600 mln". Reuters. 2013-01-02.
  7. "ShaMaran acquires Larger Stake in Atrush".
  8. https://shamaranpetroleum.com/site/assets/files/32005/2018-06-04-nr-snm.pdf
  9. https://www.shamaranpetroleum.com/site/assets/files/72240/190114_corporate_presentation_january_2019.pdf
  10. "Archived copy". Archived from the original on 2017-10-02. Retrieved 2017-10-03.CS1 maint: archived copy as title (link)
  11. http://www.shamaranpetroleum.com/i/pdf/2014-Sep-Pareto-Securities-Oil-Gas-Conference.pdf
  12. "Archived copy". Archived from the original on 2013-03-03. Retrieved 2013-02-04.CS1 maint: archived copy as title (link)
  13. https://www.reuters.com/article/2012/09/13/idUS200698+13-Sep-2012+PRN20120913
  14. "ShaMaran strikes it rich at Atrush block". Oil & Gas Middle East.
  15. "Taqa flows oil at CK-6 well in Kurdistan | Oil and Gas Technology".
  16. "ShaMaran Second Quarter 2019 Update". ShaMaran Petroleum. Retrieved 12 December 2019.
  17. "Archived copy". Archived from the original on 2017-09-20. Retrieved 2017-09-20.CS1 maint: archived copy as title (link)
  18. https://www.shamaranpetroleum.com/site/assets/files/32011/2018-06-cp-snm.pdf
  19. https://www.shamaranpetroleum.com/site/assets/files/49436/180902-corporate-presentation-september-2018.pdf
  20. "Shamaran Second Quarter 2019 Update". ShaMaran Petroleum. Retrieved 12 December 2019.
  21. "Q3 ShaMaran petroleum corp. Financial Report" (PDF). ShaMaran petroleum corp. Retrieved 12 December 2019.
  22. "Q3 ShaMaran petroleum corp. Financial Report" (PDF). ShaMaran petroleum corp. Retrieved 12 December 2019.
  23. "Welcome to ShaMaran Petroleum Corp. Website". ShaMaran Petroleum Corp.
  24. "Q3 ShaMaran petroleum corp. Financial Report" (PDF). ShaMaran petroleum corp. Retrieved 12 December 2019.
  25. "Shamaran Second Quarter 2019 Update". ShaMaran Petroleum. Retrieved 12 December 2019.
  26. "Q3 ShaMaran petroleum corp. Financial Report" (PDF). ShaMaran petroleum corp. Retrieved 12 December 2019.
  27. "Q3 ShaMaran petroleum corp. Financial Report" (PDF). ShaMaran petroleum corp. Retrieved 12 December 2019.
  28. "Shamaran Second Quarter 2019 Update". ShaMaran Petroleum. Retrieved 12 December 2019.
  29. "Q3 ShaMaran petroleum corp. Financial Report" (PDF). ShaMaran petroleum corp. Retrieved 12 December 2019.
  30. "Welcome to ShaMaran Petroleum Corp. Website". ShaMaran Petroleum Corp.
  31. "ShaMaran Atrush Update. Website". ShaMaran Petroleum Corp.
  32. http://www.shamaranpetroleum.com/i/pdf/2017-09-11-CP.pdf
  33. https://shamaranpetroleum.com/site/assets/files/32941/2018-06-08-nr-snm.pdf
  34. https://shamaranpetroleum.com/site/assets/files/5156/shamaran_petroleum_corp__shamaran_atrush_update.pdf
  35. "ShaMaran Petroleum Q2 results" (PDF). ShaMaran Petroleum. Retrieved 12 December 2019.
  36. "ShaMaran Corporate Presentation September 2019" (PDF). ShaMaran Petroleum. Retrieved 12 December 2019.
  37. "ShaMaran Petroleum Q3 results" (PDF). ShaMaran Petroleum. Retrieved 12 December 2019.
  38. "SHAMARAN ATRUSH UPDATE" (PDF). ShaMaran Petroleum. Retrieved 12 December 2019.
  39. "BOPD - Schlumberger Oilfield Glossary".
  40. "ShaMaran Corporate Presentation September 2019" (PDF). ShaMaran Petroleum. Retrieved 12 December 2019.
  41. "Shamaran Announces 25% Increase in Atrush Reserves Estimates". 2018-02-15.
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