LW TTRC (Thru-tubing recompletions)

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BDC # 150 Thru tubing recompletion

BDC 150 TTRC - Conclusions & Recommendation

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BDC # 150 has produced 376 MBO from sand 7500’ and still holds expected 8 MBO worth 746 M$

Most BDC 7700’ sand wells have resulted in cumulative oil ranging from 175 BO to 1.25 MMBO with an average 399 MBO.

A potentially productive 7700’ sand has been ID’ed in 150 A TT Recompletion with HO thru tubing premium screen will ensure

sand control enhancing commingle completion reliability. At the well, sands 7500’ and 7700’ show similar basic petrophysics

and formation volume factor. A post-recompletion production operations strategy plan to mitigate

sand production risk in the well has been anticipated. Economics show a recompletion opportunity at BDC 150. We recommend to implement this recompletion to recover expected

risked 3 MBO with a NPV @ 10% of 150 M$

BDC 150 TTRC – Operational Recommendation & Team Comments

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The team recommends adding perfs into the remaining pay zones below the current producing zone with an e-line thru-tubing operation and setting a TT premium screen assembly hang-off type for sand control.

Team’s Points of Consideration: Resin job for water shut-off in the current 7500 sand perfs. Produce the newly perforated zones without sand control – reduced

choke size. Produce the newly perforated zones with an E-line/Pump TT squeeze

gravel pack for sand control ( higher cost). If the new zones have a higher GOR; We will have improved vertical lift

performance. The TT screen assembly can be used as a base to perform the resin job

in the existing 7500 zone and isolate the new zones should they produce to much water.

Proposed BDC # 150 TTRC - AFE Cost: $ 120M

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BDC 150 and BDC 152 ST1 wells

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BDC VUB # 150 Thru tubing perforations workover

BDC # 150 Recompletion Risk Analysis

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Proposed re-completion drainage area downside, expected and upside volumetrics and EUR

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BDC # 150 Recompletion Economics

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BDC # 150 Recompletion Economics

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Description Well EconomicsPs 0.5%Net reserves oil (MBO) 3.0Estimated AFE Capital (M$) 120 ROI (Dec) 2.46 PI @ 10% 2.35 ROR (%) 1,000Payout (Months) 4.40 F&D Cost ($/Boe) 33.75 NPV @ 10% (m$) 150 Breakeven (Mboe) 1

Proposed re-completion volumetrics and EUR

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Proposed re-completion downside, expected and upside volumetrics and EUR

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BDC 152 ST1 (63 MBO) perforations at sand 7500’

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BDC 150 well performance graph: Cumoil 376 MBO, oil rate 43 bopd, GOR 2900 cf/bo, water cut 94%, THP=300 psi

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Axis 1OIL ( bbl/d )WATER ( bbl/d )GAS ( Mcf/d )Gas / Oil Ratio ( cf/bbl )TBG_PRESS

Axis 2Water Cut ( % )CHOKE

BDC UB 150Cumulativ e Gas Produced : 169.77 MMcf

Cumulativ e Oil Produced : 377.87 Mbbl

Lower Perforations: 8458Upper Perforations: 8428

7500Reservoir Name:First Production: 05/11/2008Last Production: 10/20/2013Cumulativ e Water Produced : 1205.87 Mbbl

BDC 150 forecast: EUR 388 MBO, 11.4 MBO remaining in 7500’ sand, NPV@10% = 746 M$

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OIL ( bbl/d ) BDC UB 150

Working Forecast ParametersPhase : OilCase Name : Case1b : 0Di : 0.489035 A.e.qi : 22.9168 bbl/dti : 09/30/2013te : 05/31/2017Final Rate : 1.95488 bbl/dCum. Prod. : 376.767 MbblCum. Date : 09/30/2013Reserves : 11.4026 MbblReserves Date : 05/31/2017EUR : 388.169 MbblForecast Ended By : RateDB Forecast Date : Not SavedReserve Type : None

BDC VUB # 150 current at sand 7500 and projected perforations in sands: 7500 & 7700

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BDC 7700 sand wells have produced around 8 MMBO, with Cumoil per well ranging from 197 BO to 1.25 MMBO

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Proposed re-completion volumetrics and EUR

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BDC # 150 TTRC - AFE Cost: $ 120M

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