Filing pursuant to Rule 425 under the Securities Act of 1933, as amended Deemed filed under Rule 14a-12 under the Securities Exchange Act of 1934, as amended Filer: Halliburton Company The following is a quarterly update presentation for Halliburton Subject Company: Baker Hughes Incorporated Company. Commission File No.: 001-09397

Dividend:$0.18Quarter Update: inSecond Second Quarter Quarter 2015 2015 Investor Shares RelationsOutstanding: Contacts: 855 Million Kelly Yasoungblood, of 7/17/2015 Vice www President.halliburton.com Scott Danby, Manager 281.871.2688 or [email protected] NYSE Stock Symbol: HAL Common

Safe Harbor The statements in this presentation that are not historical statements, including statements regarding future financial performance, the expected closing of the pending Baker Hughes transaction, and numerousthe growth risks potential and uncertainties, and other expected many benefitsof which and are synerbeyondgies the of company’ the Bakers Hughescontrol, transaction,which could are cause forward-looking actual results statementsto differ materially within the from meaning the results of the expressed federal securities or implied laws. by theThese statements. statements These are subjectrisks and to conditionsuncertainties to include,closing ofbut the are proposed not limited transaction to: with mayrespect not to be the satisfied pending or acquisition the closing ofof Bakerthe proposed Hughes, transaction the terms andotherwise timing does of any not divestitures occur, the riskundertaken that a regulatory in order to approval obtain required that may regulatory be required approvals, for the proposed the operationstransaction ofis Halliburtonnot obtained and or isBaker obtained Hughes subject and tothe conditions ultimate outcome that are notof Halliburton’ anticipated,s the operating diversion efficiencies of management applied time to Baker on transaction-related Hughes’ products issues, and services, the ultimate the ef timing,fects of outcome the business and resultscombination of integrating of the abilityHalliburton of Halliburton and Baker to Hughes, realize suchincluding syner thegies combined and other company’ benefits, sand future expectations financial regardingcondition, regulatoryresults of operations,approval of strategy the transaction; and plans, changes expected in the syner demandgies and for other or price benefits of oil from and/or the natural proposed gas transactioncan be and the Decembersignificantly 31, impacted 2014, Halliburton’ by weaknesss Form in the 10-Q worldwide for the quartereconomy; ended changes June in30, capital 2015, spendingrecent Current by customers; Reports onand Form structural 8-K, andchanges other in Securities the oil and and natural Exchange gas industry Commission. Halliburton’ filings discusss Form some10-K offor the the important year ended risk reason.factors identified2 that may affect Halliburton’s business, results of operations, and financial condition. Halliburton undertakes no obligation to revise or update publicly any forward-looking statements for any communicationSafe Harbor Additional relates to information a proposed This business communication combination does between not constitute Halliburton an ofandfer Bakerto buy Hughes. or sell or In the connection solicitation with of thisan of proposedfer to buy business or sell any combination, securities orHalliburton a solicitation has offiled any with vote the or Securitiesapproval. andThis otherExchange documents Commission related (the to the “SEC”) proposed a registration transaction. statement The registration on Form statementS-4, including was declaredAmendments effective No. 1by and the 2 SEC thereto, on February and a definitive 17, 2015 joint and proxy the definitive statement/prospectus proxy statement/prospectus of Halliburton hasand beenBaker mailed Hughes to and STstockholdersATEMENT/PROSPECTUS, of Halliburton and REGISTRABaker Hughes.TION INVEST STATEMENTORS AND AND SECURITY OTHER DOCUMENTSHOLDERS OF FILEDHALLIBUR OR THATONT ANDMAY BAKERBE FILED HUGHES WITH THE ARE SEC URGED CAREFULL TO READY AND THE IN JOINT THEIR PROXY ENTIRETY BECAUSE BakerTHEY Hughes CONTAIN through OR WILLthe website CONT maintainedAIN IMPOR byT theANT SEC INFORMA at http://wwwTION..sec.gov Investors. Copies and securityof the documents holders may filed obtain with freethe SECcopies by of Halliburton these documents are available and other free documents of charge on filed Halliburton’ with the SECs internet by Halliburton website at and/or byhttp://www Baker Hughes.halliburton.com are available or byfree contacting of charge Halliburton’on Baker Hughes’s Investor internet Relations website Department at http://www by email.bakerhughes.com at [email protected] or by contacting Bakeror by phone Hughes’ at +1-281-871-2688.Investor Relations CopiesDepartment of the by documents email at filed with the SEC [email protected] participants in the solicitation or by phone of proxies at +1-713-439-8822. in connection with Participants the proposed in Solicitation transaction. Halliburton, Information Baker about Hughes,the directors their andrespective executive directors officers and of certainHalliburton of their is setrespective forth in executiveits Annual of Reportficers mayon Form be and10-K its for Quarterly the year Reportended Decemberon Form 10-Q 31, 2014, for the which quarter was ended filed Junewith 30,the 2015,SEC on which February was filed 24, 2015, with theits proxySEC on statement April 23, for 2015. its 2015 Information annual meeting about the of directors stockholders, and executive which was of filedficers with of Baker the SEC Hughes on April is set 7, forth 2015, in withits Annual the SEC Report on March on Form 27, 10-K2015, for and the its year Quarterly ended ReportDecember on Form 31, 2014, 10-Q which for the was quarter filed endedwith the June SEC 30, on 2015, February which 26, was 2015, filed its with proxy the statementSEC on July for 24,its 20152015. annual These meetingdocuments of stockholders,can be obtained which free was of char filedge containedfrom the sources in the proxy indicated statement/prospectus above. Additional and information other relevant regarding materials the participants filed with the in theSEC. proxy 3 solicitations and a description of their direct and indirect interests, by security holdings or otherwise, are

Agenda ? Company Overview ? Market Outlook ? Acquisition Update ? Unconventionals ? Deepwater ? Mature Fields ? Financials 4

ServicesService Of Sperryferings T estingDrilling and and W irelineEvaluation and Multi-ChemCompletion andProduction Production Production Baroid ConsultingDrilling Subsea & Drill Perforating Bits Landmark Enhancement Artificial Solutions Cementing 5 Completion Project and Services Software and Lift Tools Management

ResearchHalliburton Corporate Global Franchise Founded EmployeesNorth America Countries H H Middle Centers East/Asia Headquarters Pacific Customers Europe/Africa/CIS FAST FACTS Latin 1919 America Over Halliburton 80 16 Houston Locations National, H Halliburton International Headquarters and 70,000 DubaiHalliburton Independent Research entities Centers worldwide 2015 Operational 6

19Comparing 25 31 37 North 43 49 America55 61 67 Cycles73 79 85Index 91 97 of 103the US109 Rig 115 Count 121 127 during 133 Last139 1453 Major 151 WCycleseeks Source:1.20 1.00 Baker Count Hughes Rig 0.80 US IndexedRig Count 0.60 – through1997-2001 7/24/15 -43% 7 2001-2008 2008-2011 -53% 2014-Curr -56% 0.40 -57% 1 7 13

Growth in Key Segments 5-Year Market 2009 2014 Share Change Market HAL Market HAL Peer HAL Size Position Size Position Average Hydraulic Fracturing 1 1 (5.9%) (1.2%) Directional (4.2%)Drilling/L SpecialtyWD/SDL Chemicals 2 2 (1.9%) N/A (5.2%) 4 1.7% W ireline(5.8%) 2Drill 2 1.2%—Artificial Bits 4 3 1.4% (5.5%) Lift N/A Source: 10 0.9% Spears (3.7%) & Associates Drilling & – Completion 2014 Oilfield Fluids Market 2 2 Report(1.4%) (Apr(1.2%) 2015 Completion Update) Primary Equipment Peers: 2 1 SLB,0.1% BHI(3.4%) 8 Cementing 1 1 1.5%

Halliburton and Baker Hughes Creating a Leading Oilfield Services Company A Compelling …with Nearly $2 billion of Strategic Combination… Annual Cost Synergies Unsurpassed breadth and depth of companyproducts andwell-positioned R&D Corporate for continued services Optimization Efficiencies 18%Accelerates superior Halliburton growth, mar Strategygins and in returns 11% 9% 23% Real Accretive Estate Unconventionals, to cash flow by end Deepwater of year oneand afterMature close; Fields accretive Administration/ to earnings 8% per Or shareganizational by end of Combined North andAmerican its drilling 31% servicesInternational business year (Directional two after close Drilling, Operational Logging-While-Drilling Operational Efficiencies and Measurement-While-Drilling) Efficiencies Deal Updates... in Halliburton the second began quarter marketing During the for first sale round, its drill received bits business nearly (Fixed 25 indications Cutter and of Rollerinterest Cone for each bits), Commissionbusiness Halliburton in the third and quarterBaker HughesWe are fullyentered committed into a timing to our agreement target of closingwith the the Antitrust acquisition Division late inof 2015 the U.S. 9 Department of Justice in the third quarter Halliburton submitted its filing with the European

Key Strategic Markets 2014 Revenue $32.9B Over 60% of 2014 Revenue came from our 3 Key Strategic Markets 10

MethaneGlobal Unconventional 58 802 707 665 Opportunity 545 573 32 Unconventional 437 27 26 390 285 Challenges 245 13 13 ? Geology9 9 8 Russia ? Infrastructure U.S. China Ar? Regulatorygentina Libya Environment Venezuela ? Mexico Economic Pakistan Viability Canada Unconventional Indonesia Brazil Basins Russia 75 T ightSouth Gas Australia 1,115 Shale Mexico Gas Canada Coal Bed U.S. OilAlgeria and ShaleArgentina Gas ChinaResources”, Africa June, Shale 2013 Oil—T 11echnically Recoverable Resources Shale Gas—Technically Recoverable Resources (billion barrels) (trillion cubic feet) Source: EIA, “Technically Recoverable Shale

Surface Efficiency FRAC 20% LESS OF THE CAPITAL FUTURE 35% LESS PERSONNEL 40% LESS COMPLETION TIME SandCastle™ Vertical Sand Logistics Q10™ Pump Mobile Technologies supplyStorage processes Bins Command and increase Center and Reduce maintenance footprint costs at wellsite, and capital Allows costs procurement and deliveries and in logistics real time Streamline back office well ef ficienciessite Significantly 12 lowers downtime significantly lowers operational specialists to monitor sand completionsMaking Better during Wells plug – Custom and perf Chemistry operations SM Old Conventional Fractures Dynamic AccessFrac Diversion Chemistry OilPerm™ Combines FMM leading enables unconventional deeper fluid movement hydraulic fracturingRestored Fracturetechniques Conductivity with proprietary RockPermSM diversion A chemistry laboratory to testing enhance process multi-zone to fromselect shale the optimum reservoirs. OilPerm Fluid Mobility Modifiers (FMM) for a stimulation treatment. New Stimulated OilPerm FMMs are designed to improve flow and enhance Volume Analysis hydrocarbon production productionMaking Better and Wminimizeells – Sub cost Surface integrating Insight geological FracInsightSM data with Service well DecisionSpace®construction ? Evaluates Earth Modeling rock properties Select perforationto identify optimalclusters entryand frac points stage ? Fulllocations field 3-DHelping visualization design more tools cost-ef ? Worksfective with wells horizontal by to maximizeopen-hole unnecessarylogs, horizontal treatments cased-hole for Eaglelogs, ? Ford Accelerates customer seismic, well construction data analysis plan by upreducing to 80% stimulation or vertical open-holecosts by 35% logs 14 + LWD data ? Saved 15 drilling days for deepwater NOC customer by optimizing ? Eliminated

Outgrowing the Deep Water Market ? Delivering the Safest, Lowest Cost Finding Market per Foot Drilled Leadership ? Leveraging leadership positions in Geoscience and Completions Drilling ? Providing a Leadership“Compelling 15 Choice” in Formation Evaluation Evaluating ? Leading in High Pressure/High Temperature (HP/HT) Solutions ? Positioning through Global Deepwater Infrastructure Completing Market

Real-TDeepwaterime ESTMZ™Technology Helps Reducing reduce Uncertainty Industry’s IncreasingLeading Downhole, Reliability Collects SM Enhanced and Identifies Single-T Monitoringrip Multi-ICE and CoreDrilling Service completion GeoTap® cost IDS in multiple Sensor DrillingXpert™ Real-Time, Laboratory-Grade Software zone FluidFracPac™ Samples System during Consolidates Drilling accuracyModeling, resolutionInto Single ? PlatformCollect multiple zone completions samples within Fluid ? ID High-volume Platform Operations fracturing ? ?Improved Increased planning drilling ef? ficiencySimultaneous ? Solid-state perforations device ? Overhours, 1 10not patents days ? andReduces filings costly ? Improved rig time sample ? Real-time integrity optimization capabilities 16 ? Higher

Impacting the Decline Curve ? Collaborate with our customers ? Grow through consulting-led mature field projects ? Deploy multi-lateral and infill drilling technologies ? Penetrate intervention segment by Horizontalfocusing on W keyells markets 20 CO2 and Injection acquisitions Thousand ? Mature 10 Economic fields a technicallyLimit 1950 underserved 1960 1970 1980 market 1990 50 2000Mature 2010 Field 2020 day 2030 40 Original 17 Vertical Wells Final (?) per Decline Curve 30 Infill Vertical Wells barrels Infill horizontalConsulting-Led ? Re-developing Mature Fields Bayan Projects oil and Mexico—Humapa gas field off techniques ? Contracted and technology to manage as asset well block as East and Malaysia to deliver experience services from in nearby asset planningRemolino to project Malaysia—Bayan ? Project includes production seismic operations analysis, ? workover Leveraging of existingunconventional wells, forand a new 5-year well extension drilling Ecuador—Igapo18 ? Multi-billion dollar opportunity over 9 mature fields ? Contracted to provide consulting, drilling, and completions services ? Total project term is 15 years, with potential

Pacific2Q15 Revenue North America Breakdown rig count. North Lower America activity Middle levels East/Asia were of Pacificfset by Revenue customer declined budgets 25% translated sequentially into improvements, Modest sequential in Iraq, improvement Kuwait and thein relativeadditional to areductions 40% reduction in activity in the levels operating UAE. income. Iraq mar Lowergins reached Asia improvementsdouble- 23% throughout in Eurasia theand second Norway quarter, along, digits with higherduring Latinthe second America quarter stimulation. accompanied activity by and further completion significant tools price sales reductions in both Algeria across and all Angolaproduct Double-digitlines. 45% 19% sequential Europe/Africa/CIS declines in revenue 13% Seasonal drove theactivity rate.sequential This was improvement partially of forfset and by operatingimproved incomeprofitability were indriven Brazil by resulting the quarter from, of thefsetting recently weaker retendered activity directional Venezuela, drilling primarily contract. due to 19the negative levels in the UK and Egypt. currency impact of the new exchange

13%Financial 13% Goals180 12% Total 12% Revenue 160 10% (Indexed) 10% 140 Return 120 1on18 A 100verage Q1 2010Capital = 100Employed*† 80 1Q10 1Q11Q101 1Q12to 2Q15 1Q13 2010 1Q14 to 2015Q2 1Q15 2010 TTM** 201 1HAL 2012 Peer 2013 Group 2014 HAL 2Q15** Peer * GroupExcludes 260 certain 240 19% char 220ges. 16% See 16%page 17%26 for 200 reconciliation 15% 157 13% of termadjusted debt return plus shareholders’on capital employed. equity (average ** TTM—T valuesrailing from T thewelve beginning Months and † Return end of on the A period)verage Capital20 Employed is defined as net income attributable to company plus after tax interest expense divided by long-

120Global 110 Revenue 100 Q1 2010North = America 100 Q1 2010Revenue = 100 (Indexed) 50 80 1Q10 International 1Q11 1Q12 Revenue 1Q13 (Indexed)1Q14 1Q15 1Q10 1Q10 to 1Q12Q151 1Q121Q10 1Q13to 2Q15 1Q14 HAL 1Q15 Peer 21 Group HAL Peer Group 300 220 200 250 180 158 200 157 160 140 150 120 100 Geographic Results ($ millions) 1Q13 2Q13 3Q13 4Q13 1Q14 2Q14 3Q14 4Q14 1Q15 2Q15 2013 2014 2015 YTD Revenue North America $ 3,706 $ 3,802 $ 3,881 $ 3,823 $3,901 $ 4,344 $ 4,724 $ 4,729 $ 5,2253,542 5,490$ 2,671 $ 2,192$ 15,212 Middle $ 17,698 East $/ Asia6,213 1,136 Latin 1,272 America 1,249 945 1,399 944 1,2891,002 1,4291,018 1,468859 897 1,621 1,045 1,462 1,074 1,386 949 5,056 767 3,909 5,807 3,875 2,848 1,716 Total Europe$ 6,974 / $Africa 7,317 /$ CIS 7,472 1,187 $ 7,639 1,299 $ 1,3407,348 1,399$ 8,051 1,299 $ 8,701 1,381 $ 8,7701,464 $1,346 7,050 1,097 $ 5,919 1,095 $ 51829,402 431 $ 234 32,870 Europe $ 12,969 / Africa Operating / CIS 121 Income/(Loss) 161 201 207 North146 186 America 216 141 $ 60586 164 $ 666 690 $ 689657 250$ 644 Middle $ 602 East$ 790 / Asia$ 906 187 $ 918 219 $ 200 279 259 $ 130 21 1$ 2642,572 262 $ 3,216337 281 $ 409 307 Latin 865 1,074America 588 109 Corporate 101 155 and 153 Other 100 61 138 132 122 112 (17)(1,120) (122) (163) related (105) costs (119) Total (89) $ (107) (98) $1 12984 (83) $ 1,108 (69) (70)$ 1,144 (1,507) $ 970 (167) $ 1,194 (139) $ 1,634Impairments $ 1,299 and $ (548) other $ char254ges $ 3,138 — — $ ——(129)5,097 $ (294) (1,208) 22 (306)—(129) (1,514) Baker Hughes acquisition— — — — (17) (39) (83)—

Items included in Geographic Results ($ millions) 1Q13 2Q13 3Q13 4Q13 1Q14 2Q14 3Q14 4Q14 1Q15 2Q15 2013 2014 2015 YTD Operating Income/(Loss) North America Restructuring charges — (7)(34) (5) (7) — — — — — — (12) (41) — — Corporate Latin America and other: Restructuring Macondo-related charges —activity (4) (4) (1,000) — — — ——195(8) — Europe ——(1,000) / Africa 195—Restructuring / CIS Restructuring charges — (3)(6) (20)(2) — — — — — — (8) (23) — — Middle Charitable East /contributions—(55) Asia Restructuring char— —ges — — — (17)(55) costs:— Patent (122) infringement Total $ (1,000) case $ settlement (55) $ (54) — $ —(38) — $—$—$ — — ——Impairments 195 $ (146) $ (1,247) and other $ (389) char $ges: (1,147) — — $ ——(129)49 $ (1,636) (1,208) 23 (306)—(129) (1,514) Baker Hughes acquisition-related — — ——(17) (39) (83)—

5,471Segment $ 4,246 Results $ 3,444 ($ millions) $ 17,506 1Q13 $ 20,253 2Q13 $ 3Q13 7,690 4Q13 Drilling 1Q14 and 2Q14 Evaluation 3Q14 4Q142,874 1Q15 2,954 2Q15 2,971 2013 3,097 2014 2,928 2015 3,109 YTD 3,281 Revenue 3,299 Completion2,804 2,475 and11,896 Production 12,617 5,279 $ 4,100 Total $ 4,363 $ 6,974 $ 4,501 $ 7,317 $ 4,542 $ 7,472 $ 4,420 $ 7,639 $ 4,942 $7,348 $ 5,420$ 8,051 $ Drilling$ 8,701 $and 8,770 Evaluation $ 7,050 407$ 5,919 415 $450 29,402 498 398$ 32,870 414 451 $ 12,969 477 306 Operating 400 1,770 Income/(Loss) 1,740 706 Corporate Completion and and other Production (1,120) (163) $ 615 (105) $ 732 (1 $19) 763 (89) $ 765 (107) $ 661 112 $(83) 887 (69) $ 1,071 (70) $(1,507) 1,051 $(167) 462 $(139) 313 Impairments$ 2,875 $ 3,670 and $ other 775 254char ges$ 3,138 — — $ 5,097——(129) $ (294) (1,208) CAPEX (306)—(129) 685 711 679 (1,514) 859 643Baker 732 Hughes 909 999 acquisition— 704 519 2,934 — 3,283— — 1,223(17) (39) DDA (83)—(17) 448 474 481(122) 497 related 510 524costs 535 Total 557 $ 560(98) 456 $ 984 1,900 $1,108 2,126 $ 1,1441,016 $24 970 $ 1,194 $ 1,634 $ 1,299 $ (548) $

—Items (40) included (10) — in— Segment — (50) —Results Drilling ($ millions)and Evaluation: 1Q13 2Q13 Restructuring 3Q13 4Q13 char 1Q14ges — 2Q14 (11) 3Q14(8) — 4Q14 — — 1Q15 (19) —2Q15 Corporate 2013 2014 and 2015other: YTD Macondo-related Operating Income/(Loss) activity (1,000) Completion — ——195 and ——(1,000) Production: 195—RestructuringRestructuring charges —char ——(17)ges — (3) (39) (20) (83)—(17) — — — (23)(122) — T otalCharitable $ (1,000) contributions—(55) $ (55) $ (54) $ (38) — $—$—$ — — — 195 (55) $ —(146) Impairments $ (1,247) $and (389) other $ (1,147)charges $— 49 — $ ——(129)(1,636) 25 (1,208) (306)—(129) (1,514) Baker Hughes acquisition-related costs —

Reconciliation of As Reported ROACE to Adjusted ROACE ($ millions) 2011 2012 2013 2014 2Q15 TTM As reported net income attributable to company $2,839 $2,635 $2,125 $3,500 $1,515 Interest expense, 3,774after-tax 3,001 181 A 206verage 260 capital 289 318 employed As reported (b) 16,124operating 19,323 profit, 21,021 after -tax22,785 3,020 22,978 2,841 As 2,385 reported 3,789 ROACE 1,833 Adjustments, (c) 19% 15% after 11%-tax 17% 88 8% 208 Adjusted 738 (15) ROACE1,168 Adjusted (c) 19% operating 16% 15% profit, 17% 13%after-tax (a) Management(a) $3,108 $3,049 believes $3,123 that performanceoperating income for future adjusted periods, for certain primarily char becauseges is useful management to investors views to assessthe char andges understand to be outside operating of the company’ performance,s normal especially operating when results. comparing Management results with analyzes previous operating and subsequent income without periods the or impact forecasting of these employedcharges as isan a indicatorstatistical of mean performance, of the combined to identify values underlying of long-term trends debt in the and business, shareholders’ and to equity establish for operationalthe beginning goals. and Seeend slidesof the 23period. and 25(c) for As furtherreported details return on on these average adjustments, capital employed pre-tax. (b)(ROACE) Average is capital 26calculated as: “As reported operating profit, after-tax” divided by “Average capital employed.” Adjusted ROACE is calculated as: “Adjusted operating profit, after-tax” divided by “Average capital employed.” Recap Best-in-Class Robust Comprehensive Expanded Platform Unconventional Deep Water Mature Fields for Superior Solutions Technology Capabilities Growth, Margins & Portfolio Returns 27

MillionQuarter asUpdate: of 7/17/2015 Second ScottQuarter Danby 2015, Manager NYSE Stock www Symbol:.halliburton.com HAL Investor 28 281.871.2688 Relations Contacts: or [email protected] Common Dividend:$0.18 in Second Quarter 2015 Kelly Youngblood, Vice President Shares Outstanding: 855